ML040700910
| ML040700910 | |
| Person / Time | |
|---|---|
| Site: | Cook  |
| Issue date: | 03/01/2004 |
| From: | Zwolinski J Indiana Michigan Power Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| AEP:NRC:4691 | |
| Download: ML040700910 (11) | |
Text
\ A Power Company 500 Circle Drive Buchanan, MI 49107 1373 INDIANA MICHIGAN POWER March 1,2004 AEP:NRC:4691 Docket Nos: 50-315 50-316 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Mail Stop O-P 1- 17 Washington, DC 20555-0001 Donald C. Cook Nuclear Plant Units 1 and 2 2003 ANNUAL OPERATING REPORT Technical Specifications 6.9.1.4 and 6.9.1.5 of Appendix A to the Donald C.
Cook Nuclear Plant Unit 1 and Unit 2 Operating Licenses require that an annual report be submitted to address personnel exposure, steam generator in-service inspection results, challenges to power-operated relief and safety valves, and information regarding any instances when the 1-131 specific activity limit was exceeded. Consistent with these requirements, a copy of the 2003 annual operating report is attached.
There are no new commitments in this submittal. Should you have any questions, please contact Mr. Michael K. Scarpello, Supervisor of Nuclear Licensing, at (269) 697-5020.
Sincerely, John . Zwvolinski Director of Design Engineering and Regulatory Affairs DB/rdw Attachments:
- 1. 2003 Annual Operating Report
- 2. Figure 1 - Steam Generator Support Structure Numbering Scheme Figure 2 - Steam Generator Tube Bundle Arrangement
U. S. Nuclear Regulatory Commission AEP:NRC:4691 Page 2 c: Director, Office of Nuclear Reactor Regulation J. L. Caldwvell, NRC Region III K. D. Curry, Ft. Wayne AEP, wv/o attachments J. T. King, MPSC, ,v/o attachments MDEQ - WHMD/HNVRPS, w/o attachments NRC Resident Inspector J. F. Stang, Jr., NRC Washington DC
ATTACHMENT 1 TO AEP:NRC:4691 2003 Annual Operating Report
1.0 INTRODUCTION
Plant Description Indiana Michigan Power Company is the licensee for Donald C. Cook Nuclear Plant. The plant is located north of Bridgman, Michigan. The plant consists of two nuclear units employing a Westinghouse pressurized water reactor nuclear steam supply system. Each reactor unit employs an ice condenser reactor containment system. The American Electric Power Service Corporation is the architect-engineer and constructor.
Unit 1 and 2 reactor licensed power levels are 3304 Mwt and 3468 Mwt, respectively.
The main condenser cooling method is open cycle using Lake Michigan water as the cooling source for each unit.
2.0 PERSONNEL RADIATION EXPOSURE
SUMMARY
Page 2 of this attachment provides the number of station, utility, and contractor/other personnel receiving exposures greater than 100 millirem (mrem) in 2003. This estimated dose is based on electronic dosimetry and reported in the format specified by Regulatory Guide 1.16.
The values shown in the individual categories (routine maintenance, etc.) represent the number of people who received greater than 100 mrem in that particular category. The grand total figure represents the total number of people who received 100 mrem, whether in one of the categories or multiple categories. A specific person could receive doses in two or more categories, but they would be counted only once in the grand total. Also, a specific person could receive less than 100 mrem in several categories, but have a total dose greater than 100 mrem. As a result, the sum of the individual category totals does not necessarily equal the grand total.
to AEP:NRC:4691 Page 2 Reg Guide 1.16 Report INDIANA MICHIGAN POWER / COOK NUCLEAR PLANT Prepared for Year 2003 Number of Personnel and Person-Rem By Work and Job Function Number of Personnel > 100 mrem Total Person-Rem Station Utility Contractors Station Utility Contractors Employees Employees and Others Emplorves Employees and Others Reactor Operation & Surveillance
-Maintenance 7 0 3 2.307 0.296 1.750
-Operations I 0 0 1.759 0.000 0.297
-Health Physics 0 0 0 0.006 0.001 0.027
-Supervisory 0 0 0 0.008 0.000 0.001
-Engineering 0 0 1 0.208 0.003 0.272 Routine Maintenance
-Maintenance 8 0 1 4.023 0.033 2.197
-Operations 0 0 0 2.349 0.000 0.161
-Health Physics 18 0 0 4.114 0.002 0.915
-Supervisory 0 0 0 0.046 0.000 0.083
-Engineering 1 0 0 0.500 0.048 0.710 Inservice Inspection
-Maintenance 2 0 4 0.821 0.000 1.736
-Operations 0 0 0 0.115 0.000 0.163
-Health Physics 0 0 0 0.000 0.000 0.044
-Supervisory 0 0 0 0.000 0.000 0.000
-Engineering 0 0 2 0.003 0.000 1.128 Special Maintenance
-Maintenance 2 0 86 0.795 0.000 46.777
-Operations 1 0 0 0.161 0.000 0.009
-Health Physics 0 0 0 0.009 0.000 0.034
-Supervisory 0 0 0 0.004 0.000 0.072
-Engineering 0 0 0 0.068 0.000 0.442 Waste Processing
-Maintenance 0 0 0 0.085 0.001 0.159
-Operations 0 0 1 0.039 0.000 0.211
-Health Physics 4 0 0 1.258 0.000 0.217
-Supervisory 0 0 0 0.000 0.000 0.006
-Engineering 0 0 0 0.082 0.000 0.001 Refueling
-Maintenance 35 0 190 10.756 0.181 69.785
-Operations 33 0 30 11.684 0.000 10.565
-Health Physics 24 0 61 9.860 0.054 22.136
-Supervisory 1 0 0 0.361 0.000 0.453
-Engineering 6 0 34 2.419 0.041 8.815 Totals
-Maintenance 65 1 308 18.787 0.512 122.403
-Operations 41 0 31 16.107 0.000 11.406
-Health Physics 44 0 63 15.246 0.057 23.374
-Supervisory 1 0 1 0.419 0.000 0.614
-Engineering 8 0 41 3.280 0.092 11.367 Grand Totals 159 1 444 53.839 0.660 169.164 to AEP:NRC:4691 Page 3 3.0 STEAM GENERATOR INSPECTIONS Acronym Listing CL Cold Leg DNG Ding FSH Free Span History FSI Free Span Indication I-Code Indication code referring to distorted or non-quantifiable indications MBH Manufacturing Burnish Mark History MBI Manufacturing Burnish Mark Indication NDF No Degradation Found PLP Possible Loose Part Rxx/Cyy Tube location coordinate corresponding to Row xx and Column yy SG Steam Generator TT Thermally Treated TW Thru-NVall Figures 1 and 2 in Attachment 2 are included to aid in understanding the support structure numbering scheme and tube bundle configuration of the Unit 1 SGs.
3.1. 2003 SG In-Service Inspection During October/November of 2003, a SG in-service inspection was conducted on the Unit 1 SGs as detailed below. This inspection constituted the second in-service inspection of the replacement SGs with the initial inspection having been performed in May 2002.
The Unit 2 SGs 'were last inspected in January/February of 2002 as detailed in submittal AEP:NRC:3691-01, dated February 28, 2003. These SGs remain under the provisions of Technical Specification 4.4.5.3a which allow an inspection interval of 40 calendar months once two consecutive inspections have yielded degradation category C-1 results. As such, the next Unit 2 SG inspections will be in the Fall of 2004.
3.2 Unit 1 SG Description (See Attachment 2, Figures 1 and 2)
The four replacement Babcock & Wilcox Model 5IR SGs were initially placed in service in December of 2000.
Each replacement SG contains 3496 TT alloy 690 tubes with an outside diameter of 0.875 inches and a nominal wall thickness of 0.049 inches. The tubes are arranged in a triangular pitch pattern of 107 rows and 85 columns. The U-bend of all tubes having up to a 12 inch centerline bend radius (Rows 1-13) are stress relieved.
to AEP:NRC:4691 Page 4 The tube support structure consists of eight stainless steel (SA-240-410S-modified) lattice grid assemblies and four sets of flat bar (also called fan bar) restraints. Each lattice grid consists of interlocking high and low bars that form a lattice pattern to provide lateral restraint in the straight portion of the tubes. The flat bar restraints are made of the same stainless steel material and offer support in the U-bend area.
The tubesheet is a nominal 21.25 inches thick and is made of SA-508 Class 3a low alloy steel forging material with Inconel cladding on the primary side. All tubes are hydraulically expanded into the tubesheet holes and flush seal welded at the primary face. The expansion includes the entire depth of the tubesheet for both the hot and cold leg sides.
3.3 Inspection Scope SG eddy current inspections were performed during October/November 2003. The inspection scope consisted of a 20 percent full-length bobbin coil examination of the tubes in SG 14. In addition, special examinations were performed in areas of interest using rotating probes to better characterize select bobbin coil signals.
SG 14 was selected for examination to support continued monitoring of a fan bar wear indication detected during the initial (2002) inspection. The remaining SGs did not have any indications of this type and, as permitted by Technical Specification Table 4.4.1, were not included in the examination scope.
The following tables provide a breakdown of the inspections performed.
Base Examination SG 11 SG 2' SG 13 SG 14
.... .... -. Te - .. : .. .. ... . :.~ :T .;....--.
Tubes -T - --eub x--nube :
Examined E xaminedEE Bobbin - Full Length 701 Special Interestn-Rotating Coil"!S '1 "'4' Diagnostics:
I- Codes 0 of 0 Percent TW 1 of 1 Expansion around new DNG 3 of 3 Sample Inspections:
DNG 4 of 4 FSH 1 of I MBH 13 of 19*
- Note: Remaining 6 MBH indications were not accessible from CL.
to AEP:NRC:4691 Page 5 3.4 Inspection Results The following table and associated discussion summarize all reported indications:
.. .: ..Indication
- T.stes SG 14 DNG Bobbin 4 FSH Bobbin 1 MBH Bobbin 19
< 20 percent TW Wear Bobbin 1 DNG:
Four DNG signals were reported using a 2-volt criterion during the bobbin coil examination.
The details of the indications are discussed below:
.... Lc ion b .. . .Vge R49/C57 FB2 + 12.63" 2.51 R56/C38 FB5 + 14.50" 3.23 R61/C33 2C + 19.43" 2.29 R85/C57 TSC + 1.71" 4.88
- Note: The convention used to locate indications is to reference from the center of the tube supports, top-of-tubeslieet or tube end as appropriate. All indication locations are measured in a positive direction from the closest lower structure (including tube end), except as follows:
. Indications located within 2.0 inches of the top of tubesheet or the center of a support shall be reported from the centerline in a positive or negative direction, as applicable.
. A tubesheet minus measurement (i.e. tubesheet hot - 5.50') may be reported in cases where no tube end was recorded.
Each location was examined with a rotating coil with no degradation detected. With the exception of the indication at R851C57, all other ding indications were present on the baseline examination. As a result of the new ding indication on tube R85/C57, three surrounding tubes were examined in the area of interest by a rotating coil. No additional indications of this type or evidence of tube damage was found during the expanded examination or the remaining examinations that was conducted as part of the base bobbin coil inspection.
During the operational baseline inspection performed in May 2002, a DNG indication was identified in the U-bend region of tube R34/26. Upon re-inspection in 2003, the indication was not found. Indiana Michigan Power Company concludes that the May 2002 finding was a false indication.
Attachment I to AEP:NRC:4691 Page 6 FSI. FSH. MB. MBH:
Freespan bobbin coil indications are indications on the interior/exterior surface of a tube that are not associated with the tubesheet sludge pile region or any support structure. The production analyst reports all free span indications initially detected by the bobbin coil as FSI.
The final disposition of the reported FSI indications is then made by a resolution analyst according to the results of a required indication history review. All indications that indicate insignificant change as compared to the original baseline data are subsequently reported as FSH or MBH. Those FSI indications that indicate significant change are reported as non-quantifiable indications or MBI and undergo additional diagnostic testing using a rotating coil.
All of the reported indications were found to have insignificant change since the baseline examination and therefore were coded FSH or MBH as directed by the Data Analysis Guidelines. A sample of the accessible indications (i.e. no manipulator moves were made in order to gain access to the hot leg indications) were examined with a rotating coil. The one FSH indication was inspected with no degradation found. Thirteen of the nineteen MBH indications were examined, the remaining six MBH indications were not accessible from CL.
No degradation was detected during this examination.
Tube Indication- Loction Voltae - l Comments .
R2/C8 FSH 4C + 29.73" 0.19 No degradation on rotating coil.
R2/C58 MjBH 3H + 46.36" 0.38 Not accessible from CL R2/C84 MBH 2H + 5.21" 0.42 Not accessible from CL R8/C54 MBH FB5 + 2.78" 1.66 No degradation on rotating coil.
R17/C19 MBH FB8 + 7.00" 0.51 No degradation on rotating coil.
R29/C103 MBH 7C + 27.17" 0.51 No degradation on rotating coil.
R29/C103 MBH 6C + 19.64" 0.61 No degradation on rotating coil.
R29/C103 MBH 6C + 6.53" 0.75 No degradation on rotating coil.
R29/C103 MBH 5C + 34.55" 0.58 No degradation on rotating coil.
R29/C103 MBH 4C + 33.90" 0.60 No degradation on rotating coil.
R29/C103 MBH 4C + 4.90" 0.59 No degradation on rotating coil.
R34/C82 MBH 2C + 19.04" 0.37 No degradation on rotating coil.
R46/CIO MBH 3H + 3.50" 0.49 Not accessible from CL R56/C40 MBH 5C + 26.51" 0.42 No degradation on rotating coil.
R58/C16 MBH 5H + 21.20" 0.65 Not accessible from CL R58/C16 MBH 5H + 12.51" 0.35 Not accessible from CL R65/C47 MBH 1H +18.99" 0.42 Not accessible from CL R67/C23 MBH FB2 + 3.01" 0.51 No degradation on rotating coil.
R83/C41 MBH FB6 + 9.82' 0.43 No degradation on rotating coil.
R85/C47 MBH FB4 + 3.10" 0.50 No degradation on rotating coil.
Attachment I to AEP:NRC:4691 Page 7 Tube Wear (<20 percent):
Tube R53/C53 was identified during the original inservice inspection (May 2002) as having low level wear at the fan bar 5 + 0.61" support location. The bobbin coil TW depth measurement for this indication was 8 percent TW. As part of a continuous monitoring program, this indication was reexamined during the October/November 2003 inspection. The indication was measured at 11 percent using the qualified bobbin coil probe. The indication was also reviewed with a rotating coil that provided no additional information. As the wear depth was well below the Technical Specification repair limit of 40 percent TW, the tube was left in service. There were no additional wear indications reported.
3.5 Plugged Tubes No defective or degraded tubes were identified during the 2003 Unit 1 SG eddy current inspection of SG 14. As a result, no tubes were plugged.
4.0 CHALLENGES TO PRESSURIZER POWER OPERATED RELIEF VALVES (PORV) AND SAFETY VALVES There were no challenges to the pressurizer PORVs or the pressurizer safety valves on either Unit 1 or Unit 2.
5.0 REACTOR COOLANT SPECIFIC ACTIVITY There were no instances in which the reactor coolant dose equivalent 1-131 specific activity exceeded Technical Specification 3.4.8 limits of 1 gCi/g in either Unit 1 or Unit 2.
Compliance was determined by routine gamma spectrometry analysis of reactor coolant.
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