GO2-02-036, Annual Operating Report 2001
| ML020780461 | |
| Person / Time | |
|---|---|
| Site: | Columbia  |
| Issue date: | 02/28/2002 |
| From: | Galen Smith Energy Northwest |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| GO2-02-036 | |
| Download: ML020780461 (48) | |
Text
ENERGY NORTHWEST RO. Box 968 0 Richland, Washington 99352-0968 February 28, 2002 G02-02-036 Docket No. 50-397 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, D.C. 20555 Gentlemen:
Subject:
COLUMBIA GENERATING STATION, OPERATING LICENSE NPF-21 ANNUAL OPERATING REPORT 2001 The annual operating report for calendar year 2001 is attached. If you have any questions or desire additional information pertaining to this report, please contact Ms. CL Perino at (509) 377 2075.
Respectfully, Vice President, Generation Mail Drop PE04 Attachment cc: EW Merschoff - NRC RIV JB Hickman - NRC NRR REIRS Project Manager NRC - NRR NRC Resident Inspector - 988C DL Williams - BPA / 1399 TC Poindexter - Winston & Strawn
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COLUMBIA GENERATING STATION ANNUAL OPERATING REPORT 2001 DOCKET NO. 50-397 FACILITY OPERATING LICENSE NO. NPF-21 Energy Northwest P.O. Box 968 Richland, Washington 99352
Columbia Generating Station 2001 Annual Operating Report Table of Contents
- 1 1.0 Introduction--------------------------
2.0 Reports--
4 2.1 Summary of Plant Operations Equipment ------ 7 2.2 Significant Maintenance Performed on Safety-Related
............. . 9 2.3 Radiation Exposure ---------------------------------............
10 2.4 Fuel Performance ---------------------------..........-----------.----------
11 2.5 10 CFR 50.46, Changes or Errors in ECCS LOCA Analysis Models---
12 2.6 10 CFR 50.59, Changes, Tests and Experiments ----------------------------
13 2.6.1 Plant Modifications ----------------------------------------------------.
29 2.6.2 Licensing Document Changes -------------- ---------------..--------
34 2.6.3 Miscellaneous Changes --------------------------------------------------
41 2.7 Regulatory Commitment Changes (NEI Process) --------------------........
3.0 Appendix A Annual Personnel Radiation Exposure Work and Job Function Report
Columbia Generating Station 2001 Annual Operating Report 1.0 Introduction Columbia Generating The 2001 Annual Operating Report for Energy Northwest's Operating License Station is submitted pursuant to Federal Regulations and Facility (BWR-5) that began NPF-21. The plant is a 3486 MWt, boiling water reactor commercial operation on December 13, 1984.
plant was taken off On May 18, 2001, following an operational run of 238 days, the ended on July 2, line for a maintenance and refueling outage. The station's outage power operation was 2001, with final synchronization to the electrical grid. Full reached on July 6, 2001.
the plant was taken The plant remained on-line for 24 days until July 26, 2001, when to replace a seal in off line for a planned forced outage. The scope of this outage was in the main condenser reactor recirculation system pump RRC-P-lB, repair a tube leak Following repair water box B, and identify and repair a leak in the steam tunnel.
2, 2001. The plant efforts, the plant was synchronized to the electrical grid on August and remained on was returned to 100 percent full power operation on August 3, 2001 line for the rest of the year.
which was During 2001 the station produced 8,250,429 megawatt-hours of generation, and the forced its second highest year of production. An extended refueling outage outage in July prevented it from being a record year.
of 2001 was the The generation of 2,497,758 megawatt-hours during the fourth quarter consecutive month highest quarter in station history. December 2001 was the fourth this had that the station generated more than 99 percent of its capability. Previously, only been accomplished approximately one month out of every nine.
less than During 2001, the Radiation Protection organization achieved its goal of having one percent of recoverable floor space that is contaminated.
in June of 2001 Construction of an Independent Spent Fuel Storage Installation began system will and is scheduled for completion by April 2002. This dry cask storage time as it can be allow for safe and efficient storage of the station's spent fuel until such transported to a national repository.
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Columbia Generating Station 2001 Annual Operating Report 2.0 Reports the requirements of Technical The reports in this section are provided pursuant to: 1)
Report," 2) the requirements of 10 Specification 5.6.1, "Occupational Radiation Exposure Cooling Systems for Light Water CFR 50.46, "Acceptance Criteria for Emergency Core CFR 50.59, "Changes, Tests, and Nuclear Power Reactors," 3) the requirements of 10 Guide 1.16, "Reporting of Experiments," 4) the guidance contained in Regulatory
- 5) the guidance contained in the Operating Information," Revision 4 - August 1975, and Changes," Revision 0, July NEI 99-04, "Guidelines for Managing NRC Commitment 1999.
report be submitted in accordance Technical Specification 5.6.1 requires that the following with 10 CFR 50.4 by April 30 of each year:
station, utility, and other personnel A tabulation on an annual basis of the number of receiving an annual deep (including contractors) for whom monitoring was performed, associated collective deep dose dose equivalent of greater than 100 mrems and the and job functions [e.g., reactor equivalent (reported in man-rem) according to work maintenance, special maintenance operations surveillance, inservice inspection, routine This tabulation supplements the (describe maintenance), waste processing, and refueling].
to various duty functions may be requirements of 10 CFR 20.2206. The dose assessments dosimeter (TLD),
estimated based on electronic or pocket dosimeter, thermoluminescent less than 20 percent of the or film badge measurements. Small exposures totaling at least 80 percent of the individual total dose need not be accounted for. In aggregate, be assigned to specific major work whole body dose received from external sources should functions.
change to or error Regulation 10 CFR 50.46 requires that, for each (non-significant)
System (ECCS) cooling discovered in an acceptable Emergency Core Cooling such a model that affects the performance evaluation model or in the application of the nature of the change or temperature calculation, the applicant or licensee shall report to the Commission at least error and its estimated effect on the limiting ECCS analysis annually as specified in 10 CFR 50.4.
as specified in 10 CFR 50.4, a Regulation 10 CFR 50.59 requires that licensees submit, or experiments, including a report containing a brief description of any changes, tests, at intervals not to summary of the evaluation of each. The report must be submitted exceed 24 months.
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Columbia Generating Station 2001 Annual Operating Report covering the operation of the Regulatory Guide 1.16 states that routine operating reports prior to March 1 of each year.
unit during the previous calendar year should be submitted Each annual operating report should include:
the report period relating to the
"* A narrative summary of operating experience during maintenance not covered safe operation of the facility, including safety-related elsewhere.
over 20 percent of design power level
"* For each outage or forced reduction in power of where the reduction extends for more than four hours:
involved (if the (a) The proximate cause and the system and major component malfunction).
outage or forced reduction in power involved equipment reportable occurrences (b) A brief discussion (or reference to reports) of any pertaining to the outage or reduction.
if appropriate.
(c) Corrective action taken to reduce the probability of recurrence, reduction.
(d) Operating time lost as a result of the outage or power performed during (e) A description of major safety-related corrective maintenance component involved and the outage or power reduction, including system and length of the outage or identification of the critical path activity dictating the power reduction.
exposure specifically (f) A report of any single release of radioactivity or single than ten percent of the associated with the outage which accounts for more allowable annual values.
other personnel
" A tabulation on an annual basis of the number of station, utility and than 100 mrem/year and their (including contractors) receiving exposures greater job functions.
associated man-rem exposure according to work and fuel examinations, including eddy
"* Indications of failed fuel resulting from irradiated completed during the report current tests, ultrasonic tests, or visual examinations period.
is a commission-endorsed The NEI Guidelinesfor Managing NRC Commitment Changes commitments. As part of method for licensees to follow for managing or changing NRC decision criteria, the guidance this process and for commitments that satisfy the NEI along with the FSAR updates as specifies periodic staff notification, either annually or required by 10 CFR 50.71(e).
Page 3
Columbia Generating Station 2001 Annual Operating Report 2.1 Summary of Plant Operations experience and is included This section contains a narrative summary of operating and C.1.b.(2).
pursuant to Regulatory Guide 1.16, Sections C.1.b.(1)
January 2001 at full power. On January At the beginning of the month the station was operating for turbine front standard 12, 2001, a downpower to about 80% was initiated day. Other than down testing. The station returned to full power the following rod pattern changes, the station powers of less than 20% for scheduled testing and remained at full power for the remainder of the month.
February 2001 at full power. On February At the beginning of the month the station was operating initiated for a rod sequence 2, 2001, a downpower to approximately 70% was to full power the following exchange and scheduled testing. The station returned testing and rod pattern day. Other than downpowers of less than 20% for scheduled of the month.
changes, the station remained at full power for the remainder March 2001 On March 9, At the beginning of the month the station was operating at full power.
for rod pattern adjustment 2001, a downpower to approximately 72% was initiated returned to full power the and scheduled turbine valve testing. The station 20% for scheduled testing and following day. Other than downpowers of less than for the remainder of the rod pattern changes, the station remained at full power month.
April 2001 On April 8, At the beginning of the month the station was operating at full power. Other of coast down.
2001, reactor power began decreasing marking the beginning pattern changes, than downpowers of less than 20% for scheduled testing and rod could sustain for the remainder the station remained at as high a power as the fuel of the month.
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Columbia Generating Station 2001 Annual Operating Report May 2001 at 88% power. Coast down At the beginning of the month the station was operating shutdown for refueling. Power to approximately 82% power was achieved prior to on the May 18, 2001, and reduction for the scheduled refueling outage was initiated part of the normal procedure for on May 19, 2001, a manual scram was inserted as shutdown.
June 2001 outage for the entire month.
- The station was in a maintenance and refueling July 2001 for restart following the
" At the beginning of the month the station was preparing achieved and the station reached refueling outage. On July 1, 2001, criticality was 88 % power on July 5, 2001.
to recover a tripped adjustable
"* On July 5, 2001 a downpower to 29% was initiated Full power operation was speed drive for recirculation system pump RRC-P-1B.
reached on July 6, 2001.
system pump RRC-P
" Power reduction for a forced outage to repair a recirculation a manual scram was inserted as 1B pump seal was initiated on July 26, 2001, and part of the normal procedure for shutdown.
August 2001 for restart following the At the beginning of the month the station was preparing and the station resumed forced outage. On August 1, 2001, criticality was achieved of less than 20% for full power on August 3, 2001. Other than downpowers remained at full power for the scheduled testing and rod pattern changes, the station remainder of the month.
September 2001 at full power. On
" At the beginning of the month the station was operating initiated for a rod pattern September 28, 2001, a downpower to 73% was resumed the following day.
adjustment and scheduled testing. Full power operation to test main steam
"* On September 30, 2001, a downpower to 76% was initiated later the same day.
valve MS-V-164B. Full power operation was resumed Page 5
Columbia Generating Station 2001 Annual Operating Report October 2001 operating at full power. On October At the beginning of the month the station was for a rod sequence exchange. The 12, 2001, a downpower to 70% was initiated day. Other than downpowers of less station returned to full power the following changes, the station remained at full than 20 % for scheduled testing and rod pattern power for the remainder of the month.
November 2001 station was operating at full power. On
"* At the beginning of the month the 80% was initiated for scheduled testing.
November 24, 2001, a downpower to about day.
Full power operation was resumed later the same to 77% was initiated for a rod sequence
"* On November 29, 2001, a downpower the following day.
exchange. Full power operation was resumed December 2001 was operating at full power. On At the beginning of the month the station for bypass valve and turbine front December 20, 2001, a downpower was initiated power on December 21, 2001.
standard tests. The station commenced raising system heater level controls, the However, due to problems with reactor feedwater lowered back to 80%. After recovery power ascension was halted at 90% and later was returned to full power on of the reactor feedwater heaters, the reactor at full power for the remainder of the December 22, 2001. The station remained month.
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Columbia Generating Station 2001 Annual Operating Report Equipment 2.2 Significant Maintenance Performed on Safety-Related safety-related equipment maintenance This section contains brief descriptions of major, and is included pursuant to Regulatory performed during outages or power reductions Guide 1.16, Section C.l.b.(2)(e).
DG-2]
Emergency Diesel Generator [DG-1 and plates on diesel cooling water heat exchanger Weld repairs of the channel head divider performed as part of preventive maintenance DCW-HX-1A2 and DCW-HX-1B1 were activities.
water heat exchangers DCW-HX-IAl and A tube bundle was rotated on diesel cooling mis had shown that the two bundles were DCW-HX-1B2. Eddy current testing oriented.
Emergency Diesel Generator [DG-31 and performed. This included disassembly A six-year maintenance overhaul was head gaskets on all 20 cylinders, reassembly of the top deck for replacing the cleaning and rebuilding of the pneumatic replacement of miscellaneous flex hoses, operation of the engine turbocharger.
governor booster and confirmation of proper Reactor Core Isolation Cooling System valve RCIC-V-63 was completely rebuilt Reactor core isolation cooling system torque switch replacement and repair including valve refurbishment, stem replacement, to correct a packing leak problem.
Reactor Recirculation System was replaced due to wear. The seal The seal on recirculation system pump RRC-P-1A a scheduled change during the refueling on pump RRC-P-lB was also replaced as degraded to the point where it was outage. However, upon startup, seal performance a forced outage.
necessary to replace it for a second time during was replaced on recirculation system Leaks were repaired and the reed switch assembly valve RRC-V-19 following indications of leakage.
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Columbia Generating Station 2001 Annual Operating Report Residual Heat Removal System heat exchanger Inspection and tube plugging were performed on residual heat removal RHR-HX-1A as part of preventive maintenance activities.
Standby Service Water System with standby service Weld repairs were performed on downstream piping associated activities.
water valves SW-V-2A and SW-V-2B as part of preventative maintenance Page 8
Columbia Generating Station 2001 Annual Operating Report 2.3 Radiation Exposure A and contains The annual work and job function report is included as Appendix information is included information pertaining to personnel radiation exposure. This 1.16, Section C. 1.b.(3).
pursuant to Technical Specifications 5.6.1 and Regulatory Guide are based on direct reading The values are estimated doses for the listed activities and dosimeter data. No correction factor was applied to the readings.
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Columbia Generating Station 2001 Annual Operating Report 2.4 Fuel Performance This section contains information relative to fuel integrity. A fuel defect was identified during the calendar year 2001 portion of Cycle 15. This defect was initially identified as a suspected defect and reported during calendar year 2000.
Analysis of fission gas isotopes indicated a small fission gas leak occurred between November 21, 2000 and November 28, 2000. A full-core sipping was performed during the maintenance and refueling outage in May 2001. Sipping efforts located the leak as coming from Bundle WQE106, which was a once-burned bundle.
The bundle was removed from the core and a detailed examination in November 2001 identified the leaking fuel rod (Rod B7). The failure was determined to be debris fretting under the second spacer location. There were indications of secondary hydriding, but no secondary failure occurred.
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Columbia Generating Station 2001 Annual Operating Report 2.5 10CFR50.46, Changes or Errors in ECCS LOCA Analysis Models This section contains information relative to changes and errors in Emergency Core Cooling System (ECCS) cooling performance models.
and Included in this section is a description of the impact of any non-significant changes or in the errors discovered in the ECCS cooling performance evaluation models to be non application of such a model where the change or error was determined those that are less significant. For the purposes of this report, non-significant errors are pursuant to 10 than or equal to 50 degrees Fahrenheit. (Significant errors are reported CFR 50.72 and 10 CFR 50.73 and are not included in this report.)
Boveri - ABB)
Both General Electric (GE) and Westinghouse (previously Asea Brown core. The GE methodologies were applied to the Columbia Generating Station This is the methodology was used to license Siemens Power Corporation (SPC) fuel.
LOCA analysis of record for Columbia Generating Station.' The Westinghouse 2
methodology was used to license Westinghouse SVEA-96 fuel.
which For the SPC fuel, there was an error in the GE ECCS LOCA analysis model being resulted in the accumulated licensing basis upper-bound peak cladding temperature outage, all increased by 5' Fahrenheit (1478°F to 1483 F). During the 2001 refueling 0
remaining SPC fuel was discharged from the core.
analysis model or For the Westinghouse fuel, there were no errors in the ECCS LOCA application of the model for 2001.
' General Electric Report NEDC-32115P, Revision 2, "Washington Public Power Supply System Nuclear Project 2 SAFER/GESTR-LOCA Loss-of-Coolant Accident Analysis," GE Nuclear Energy, July 1993 2 Westinghouse Report CE NPSD-801-P, Revision 5, "Columbia LOCA Analysis Report,"
Westinghouse Electric Company, February 2001 Page 11
Columbia Generating Station 2001 Annual Operating Report 2.6 10CFR50.59, "Changes, Tests and Experiments" Columbia Generating Station implemented the revised 10 CFR 50.59 rule in August 2001.
In 2001, there were no evaluations performed under the new rule. There were several evaluations performed under the old rule.
This section contains summaries of safety evaluations (SE) for activities implemented during 2001 that were assessed pursuant to the previous 10 CFR 50.59 reporting requirements. Accordingly, the term unreviewed safety question still applies in the evaluation of those changes.
Each change summarized in the following sections was evaluated and determined not to represent an unreviewed safety question or require a change to the Technical Specifications.
In certain instances, a single safety evaluation was used for several implementing activities which were within the scope of the proposed change. This is allowed by procedure only where an existing evaluation adequately covers the specific change being considered. A separate evaluation is also required if out-of-service equipment, equipment lineups, modifications, or temporary alterations are in place that invalidate the existing evaluation.
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Columbia Generating Station 2001 Annual Operating Report 2.6.1 Plant Modifications This section contains information pertaining to implemented Plant Design Changes (PDCs), Plant Modification Records (PMRs), Technical Evaluation Requests (TERs), and Temporary Modification Requests (TMRs) and is included pursuant to 10 CFR 50.59.
This modification provided the justification for the use of a new mode of reactor core isolation cooling system operation to be used for increased control of reactor vessel water level when the system is in use. Increased reactor pressure vessel water level control is accomplished by allowing the reactor core isolation cooling system to enter a batch flow process that will direct all RCIC flow either to the vessel by means of injection valve RCIC-V-13 (RPV injection mode) or to the condensate storage tanks through series valves RCIC-V-22 and RCIC-V-59 (the normal path for the RCIC full flow test, CST-to-CST).
Flow control to the CSTs will be provided by throttling RCIC-V-22. This method of operation will reduce the number of system starts and stops due to vessel level tracking.
Safety Evaluation Summary The safety evaluation concluded that the change does not affect reactor core isolation cooling system/component design or safety function, including system equipment required for high energy line break event mitigation or containment isolation functions during a design basis accident, nor does it affect the automatic response of the system to accidents, transients or special events.
This change adds a new mode of system operation to be used to provide increased control of reactor pressure vessel water level when the system is in operation. This method of operation will reduce the number of reactor core isolation cooling system starts and stops as vessel water level varies between reactor vessel Level 2 and Level 8. This change requires no physical plant modifications.
The change does not increase the probability or consequences of previously-analyzed accidents, transients or special events, or malfunctions of equipment important to safety nor create the possibility of a new or different type of accident, transient or malfunction of equipment important to safety. Safety margins defined in Technical Specifications are maintained. The proposed change does not alter the ability of the operator to monitor system conditions, detect component failures, and to act upon them. This change does not affect the operation of any other important-to-safety system.
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Columbia Generating Station 2001 Annual Operating Report PDC 00126701 (SE 00-0068)
This modification provided for the installation of a check valve, related instrumentation and changes in the configuration of the keep fill suction piping in the reactor core isolation cooling system to reduce the probability of water hammer. The proposed changes are necessary to prevent water hammer due to drain down of pump discharge piping during the period when the reactor core isolation cooling system is tripped between reactor vessel Level 8 and Level 2. Water hammer may result in loss of RCIC piping integrity, loss of primary containment integrity, flooding, and other potential effects.
Safety Evaluation Summary The safety evaluation concluded that, by preventing water hammer and its consequent potential for piping failure, the modification ensures the system and other important-to safety systems potentially affected by water hammer in the reactor core isolation cooling system will continue to respond to and mitigate the effects of associated design basis events.
These design changes enhance the system's capability to serve as backup to the high pressure core spray system for the control rod drop accident and anticipated transient without scram, and as the preferred source of reactor vessel inventory for a station blackout event. They also ensure that the reactor core isolation cooling system will not fail in such a manner as to affect safety related systems during other design basis events.
The proposed modifications do not affect postulated pipe breaks/cracks generated within the reactor core isolation cooling system. No existing or new types of accidents, transients or equipment malfunctions are affected or will result, from these modifications.
The modification will improve system reliability during its response to reactor Level 2 and Level 8 signals by ensuring that water hammer conditions do not occur in the event a single failure of either valve RCIC-V-46 and/or RCIC-V-19 to close.
PMR 85-0528 (SE 94-0142)
This modification provided for the replacement and recalibration of overcurrent relays to allow for increased precision of inverse time-current settings and coordination with upstream and downstream overcurrent devices. These overcurrent relays provide overcurrent protection for the 4.16KV and 6.9KV buses and feeders and station service auxiliary transformers TR-S, TR-N1, TR-N2 and TR-B. This design change also provided for revised overcurrent relay and low voltage circuit breaker setpoints.
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Columbia Generating Station 2001 Annual Operating Report Safety Evaluation Summary the The safety evaluation concluded that this change would not impact the ability of electrical distribution system to function and monitor overcurrent transients and accidents.
of The modification also does not change the functional design, logic or control scheme of existing relays any component or system. The proposed activity consisted of resetting in and replacement of additional relays which are of the same electromechanical type order to provide proper overcurrent coordination of the medium voltage switchgears.
been No new system failure modes have been added and no existing failure modes have changed since the new relays are of the same electromechanical induction disk design. All other changes consist of recalibrations of existing equipment.
PMR 89-0234 (SE 00-0025)
This modification provided for the replacement of the two vital, Division 1 and Division 2, safety related, 120 VAC inverters with four new inverters (one active and one installed spare in each division). It also replaces the two vital, safety related, Division 1 and Division 2, 125 VDC battery chargers with four new safety related chargers (one active and one installed spare in each division). The vendor no longer manufactures replacement parts for our existing inverters and chargers and there was no backup inverter or charger available to carry the load if one of these inverters or chargers fails.
Safety Evaluation Summary The safety evaluation concluded that the replacement equipment performs the same functions as the obsolete equipment it is replacing. The reliability of the system is being improved by installing redundant units in place of single units, thus, providing built-in spares. In each case, one inverter or charger will be in operation and the other will act as an installed spare.
The two inverters in each division will provide a built in spare inverter. If the on-line inverter fails, power will be transferred to the alternate power source. The off-line inverter will be placed in service and the load will be transferred back to this inverter.
This change will provide redundant chargers for each of the 125 VDC batteries. These chargers will both be full capacity chargers so a single charger will be capable of supplying all the DC loads for its division. One charger will be floating on the bus and the other charger will be shut down.
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Columbia Generating Station 2001 Annual Operating Report PMR 93-0037 (SE 99-0024)
This design change provided for the installation of a permanent platform in the reactor building to provide access to high pressure core spray system valve HPCS-V-4. The to platform replaced a long standing scaffold which has been required by plant personnel perform testing and surveillances on HPCS-V-4.
Safety Evaluation Summary The platform performs a passive function of providing access to HPCS-V-4. Thus, the proposed platform will not have any adverse impacts or interactions with important to safety systems or components.
Temporary members or restraints were provided during the installation phase as required by plant procedures to ensure that interim configurations of the platform were in acceptable seismic configurations. This ensured that there were no adverse impacts between the permanent platform and important to safety systems or components during the installation phase. The activity did not directly or indirectly affect the capability of any important to safety structures, systems or components to perform their intended safety function as described in the safety analysis report.
PMR 94-0274-03 (SE 00-0067)
This modification provided for the installation and testing of a mitigation monitoring data acquisition system for the reactor water cleanup system in support of NobleChem application. The new system will be used to help determine when a NobleChem re application is required. The system also provides the capability to determine and monitor reactor coolant electrochemical corrosion potential which provides a measure of susceptibility of the wetted reactor internals and reactor recirculation system piping to intergranular stress corrosion cracking. The electrochemical corrosion potential data will be used to help determine the required hydrogen injection rate for the hydrogen generation system.
Safety Evaluation Summary The safety evaluation concluded that the addition of the mitigation monitoring data acquisition system to the reactor water cleanup system will comply with all applicable standards and codes. There will be no increased probability of occurrence or increased consequences for any accident or malfunction of equipment previously evaluated in the safety analysis report. Further, there are no new accident scenarios or equipment malfunctions introduced by the proposed change. All plant systems and components required to mitigate the consequences of previously evaluated accidents are not impacted by the proposed change.
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Columbia Generating Station 2001 Annual Operating Report PMR 94-0274-04 (SE 00-0074)
This modification provided for the addition of an electro-chemical corrosion potential is a measurement system for in-core measurement. The main component in this system a
GE-designed assembly that contains four local power range monitor detector strings, The calibration tube and three electro-chemical corrosion potential electrode strings.
hydrogen in-core system provides primary measurements which are used to adjust injection rate.
Safety Evaluation Summary potential The safety evaluation concluded that the in-core electro-chemical corrosion any other plant measurement system is non-safety and has no direct or indirect effect on this modification that system. There are no important to safety effects resulting from margin in the change the operation or function of any system or change any safety occurrence of Technical Specifications. This activity does not increase the probability of previously in any accident/transient or consequences of any accident/transient evaluated occurrence of or the safety analysis report. It also does not increase the probability of change the consequences of important to safety equipment malfunctions.
PMR 94-0274-05 (SE 00-0039) sensor and This modification provided for the removal of the existing dissolved oxygen of the installation of a new hydrogen/oxygen sample panel in support of implementation for long-term the hydrogen generation system in order to monitor water chemistry protection of reactor internals.
Safety Evaluation Summary and The safety evaluation concluded that removal of the existing oxygen sensors system will replacement with a new, more reliable, oxygen and hydrogen monitoring previously not increase the possibility or consequences of any accidents or transients function as the existing evaluated. The new sample rack will perform the same basic system, but will enhance the system function and provide, in addition to the dissolved level as oxygen saturation level already monitored, the dissolved hydrogen saturation well. With this new system, the time required to calibrate both hydrogen and oxygen is increased monitoring systems is greatly reduced and the span between calibrations which, in turn, reduces out-of-service time.
01 PMR 94-0274-06 (SE 01-0012; SE 01-0014; SE 01-0015R0; SE 01-0015R1; SE 0017R0; SE 01-0017R1)
This modification provided for the injection of noble metal compounds into the reactor the vessel to create a catalytic layering of noble metals (platinum/rhodium) to reduce Page 17
Columbia Generating Station 2001 Annual Operating Report corrosion hydrogen addition injection rate thereby achieving intergranular stress regular cracking protection while minimizing the effects of high dose rates attributed to process.
hydrogen injection rates. This process is commonly called the NobleChem Safety Evaluation Summary create any The safety evaluations concluded that the NobleChem process does not important to adverse equipment interaction. No new malfunction of any equipment application is safety is created during NobleChem application. After the noble metal primary completed, the reactor vessel, the reactor internals and some of the associated pressure boundary piping and equipment becomes better protected from intergranular and/or stress corrosion cracking and, therefore, have reduced probabilities of failures malfunctions.
will lead to NobleChem experience and testing to-date indicates that NobleChem expected to lead increased cladding corrosion. However, this increased corrosion is not component to adverse effect on the thermal or mechanical properties of any fuel bundle to be if the noble metal loading on fuel is at a low to moderate range. This is expected The specified true for all normal operating conditions over the design life of the fuel.
Standard acceptable fuel design limits as specified in 10CFR50, GDC-10 and NRC Review Plan will be met under NobleChem application conditions.
ineffective.
The noble metal layer will eventually wear and eventually become reduce the Reapplication will be required at periodic intervals to maintain the ability to electro-chemical corrosion potential to a beneficial level with moderate hydrogen addition rates.
PMR 96-0010 (SE 00-0031)
This modification provided for an increase in the slope and line size of the seal drain lines for reactor feedwater system pumps RFW-P-1A and RFW-P-1B to minimize oil and water contamination.
Safety Evaluation Summary The safety evaluation concluded that the purpose and function of all equipment associated with the piping is not impacted by the proposed modification. All impacted components will continue to meet the applicable ANSI/ASME Code and Columbia Generating Station requirements. There will be no increased probability of occurrence or increased consequences of any accident or malfunction of equipment previously evaluated. Further, there will be no new accident scenarios or equipment malfunctions introduced by the change.
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Columbia Generating Station 2001 Annual Operating Report PMR 96-0157 (SE 00-0049)
This modification provided for the installation of the plant process computer replacement system (PPCRS) upgrade to replicate and integrate with the recently-upgraded transient project).
data acquisition system (TDAS) computer (previously upgraded under the Y2K This will provide redundant process computer systems. In its final configuration, either TDAS and system will be able to provide complete and independent operation of both PPCRS functions.
Safety Evaluation Summary previously The safety evaluation concluded that the change does not impact any of the do not evaluated accident analyses. Components and circuits installed by this modification installation create significant new sources of electronic interference, nor is the new New control affected by any electronic interference impacts from existing equipment.
room.
power circuits are installed in grounded flex conduits within the main control cables routed between control panels are fiber optic, which can not induce electromagnetic low signal fields on adjacent cables or components. New computer equipment operates at to levels. The main control room has instrument and equipment grounding systems minimize electronic fields, with most equipment located within grounded metallic enclosures (panels).
for any There will be no increased probability of occurrence or increased consequences as accident or malfunction of equipment previously evaluated in the safety analysis report to mitigate the a result of this change. All plant systems and components required the consequences of previously evaluated accidents will not be unacceptably impacted by proposed change.
PMR 97-0040-03 (SE 01-0022)
In This modification provided for implementation of the Cycle 16 core design.
addition, the ultimate heat sink (UHS) analysis was revised to incorporate a 24-month of fuel cycle, a full spent fuel pool, and a greater siphon differential (22 inches instead 18 inches).
Safety Evaluation Summary It was concluded from the safety evaluation that assumptions and bounding conditions were identified and accounted for relevant to the Cycle 16 safety analysis. The COLR limits are established to maintain the probabilities and consequences in the safety analysis and maintain margin of safety. The enrichment change in the reload fuel is within the approved scope of NRC approved methodology. In addition, the design change does not affect the safety function of the UHS or standby service water (SSW) systems. The safety function of these systems is to provide cooling water for up to 30 Page 19
Columbia Generating Station 2001 Annual Operating Report The UHS days without makeup water to help mitigate the consequence of a transient.
and SSW systems continue to meet their basic design requirements.
PMR 97-0137 (SE 00-0015) reheater steam This modification provided for the elimination of two moisture separator The trap trap stations to eliminate energy that was being lost to the main condenser.
frequent servicing or stations had also been cycling at frequent intervals, which required replacement of the associated valves.
Safety Evaluation Summary separator reheater The safety evaluation concluded that the basic operation of the moisture because there will not change. The change in the system will result in simpler operation also no equipment or will be less equipment to test, monitor and maintain. There are impacted by this components that are important to plant safety that will be adversely change.
PMR 98-0082-0 (SE 99-0017) for the main steam This modification provided for an improved seating configuration Valve and Gage safety relief valves (MSRVs) utilizing a redesigned disc insert. Crosby seating Company, the original designer and manufacturer, developed the improved the MSRVs had configuration. This new seating configuration is necessary because excessive seat leakage during plant operation.
to incorporate the This design change provided for the modification of four MSRVs MSRVs vendor's improved seat design to reduce seat leakage. Modified and improved were installed in the plant in accordance with approved procedures.
Safety Evaluation Summary the evaluation The safety evaluation concluded that, based on the prototype testing and Station of the changes by Crosby Valve and Gage Company and Columbia Generating or Engineering, the modification does not impact MSRV operation, performance, maintain their function, except for seat leakage reduction. The MSRVs continue to setpoints as rated capacity, setpoint and blowdown requirements. All MSRV safety the proposed listed in the Technical Specifications remain unchanged; therefore, for any modification does not reduce the margin of safety as defined in the basis new accident or Technical Specification. The proposed modification does not create a any new malfunction of important to safety equipment.
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Columbia Generating Station 2001 Annual Operating Report PMR 98-0117 (SE 00-0010)
This modification allowed for the replacement of low pressure turbine seal steam pressure transmitters/transducers SS-PT-5B/PTD-5B and SS-PT-7A/PTD-7A (obsolete-no longer available), and replaces them with Rosemount 1153 single unit transmitters with improved functional capabilities.
Safety Evaluation Summary The safety evaluation concluded that the implementing activity is the replacement of obsolete non-safety related turbine seal steam pressure transmitters. The replacement transmitters are radiation resistant, have the same or improved performance capability and will serve the same functional requirements as the original devices. The previously evaluated accident analyses are not affected by this change.
PMR 99-0051 (SE 00-0007)
This modification provided for removal of the mechanical components (position indicator rod assembly and sensor arms) used for disk position indication from within the inside of the residual heat removal system check valves RHR-V-41B, RHR-V-41C, RHR-V-50B, and RHR-V-89. The disk indication feature of these testable check valves has proven to be prone to malfunctions, and in some instances may actually interfere with the required surveillance testing requirements (INPO SOER 86-03). Therefore, the removal of these internal components eliminated the possibility of invalidating test results.
Safety Evaluation Summary The safety evaluation concluded that this change does not affect the original safety-related design functions of the RHR system or the check valves. These valves are normally closed, and while in the closed position, function as containment isolation valves and high low pressure interface valves between the reactor coolant and portions of the emergency core cooling system (ECCS). These valves must open to facilitate operation of part of the ECCS. They are also designed to fail closed and isolate to provide containment isolation, and the fail-safe mode will not be impacted by this change.
PMR 99-0103 (SE 99-0062)
This modification provided for a second set of undervoltage relay contacts in the automatic pump start logic for low pressure core spray system pump LPCS-P-1 and residual heat removal system pump RHR-P-2C to prevent breaker tripping caused by overlap of the undervoltage trip and the automatic start signals. This modification also inserted a set of contacts from the bus undervoltage trip relay into the logic of the automatic pump start circuit for pumps LPCS-P-1 and RHR-P-2C.
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Columbia Generating Station 2001 Annual Operating Report Safety Evaluation Summary The safety evaluation concluded that there is no safety significance associated with this modification. The change had no impact on system function, operation, alarms, or operating procedures. The only change is that the automatic start circuit on pumps LPCS P-1 and RHR-P-2C will not initiate until the trip circuit undervoltage relay has reset when the undervoltage condition clears.
PMR 99-0107 (SE 00-0055)
This modification provided for a change to the sealing mechanism for RCIC-V-31 to provide for venting of pressure between the wedge disc to the high pressure side (containment side) of the valve. A bypass line was installed from the valve body cavity to the containment side of the valve weld end (containment side).
Safety Evaluation Summary It was concluded from the safety evaluation that the bypass line would not interfere with the performance of the valve or system. This change enhances the reliability of the opening function of the valves through the elimination of pressure locking as a potential failure mode. The change will provide a passive form of pressure equalization. The reactor isolation function is not affected. The non-containment-side disc continues to perform the containment isolation function.
PMR 99-0108 (SE 00-0059)
This modification provided for a change to the sealing mechanism for HPCS-V-4 to provide for venting of pressure between the wedge disc to the high pressure side (containment side) of the valve. A hole was drilled in the containment side disc.
Safety Evaluation Summary It was concluded from the safety evaluation that the bypass line would not interfere with the performance of the valve or system. This change enhances the reliability of the opening function of the valves through the elimination of pressure locking as a potential failure mode. The change will provide a passive form of pressure equalization. The reactor isolation function is not affected. The non-containment-side disc continues to perform the containment isolation function.
PMR 99-0109 (SE 00-0052)
This modification provided for a change to the sealing mechanism for HPCS-V-12 to provide for venting of pressure between the wedge disc to the high pressure side Page 22
Columbia Generating Station 2001 Annual Operating Report cavity to (containment side) of the valve. A bypass line was installed from the valve body the containment side of the valve weld end (containment side).
Safety Evaluation Summary interfere with It was concluded from the safety evaluation that the bypass line would not reliability of the the performance of the valve or system. This change enhances the as a potential opening function of the valves through the elimination of pressure locking equalization. The failure mode. The change will provide a passive form of pressure disc continues to reactor isolation function is not affected. The non-containment-side perform the containment isolation function.
PMR 99-0140 (SE 00-0046)
Division 1 and This modification provided for the replacement of all safety related breakers to enhance Division 2, 4160-volt circuit breakers with new vacuum circuit auxiliary power system reliability.
Safety Evaluation Summary are direct roll-in The safety evaluation concluded that the replacement circuit breakers assemblies and are replacement breakers for use in the existing metal-clad switchgear switchgear. The supplied by the original equipment manufacturer of the original with the same replacement circuit breakers are designed, rated, and tested to comply circuit breakers ANSI/IEEE standards as the original circuit breakers. The replacement requirements as the are also qualified by test to the same seismic and environmental heat load and their DC original circuit breakers. The replacement breakers generate less power capacity. No control power is well within the capabilities of the plant DC control there will be no change in the DC battery emergency load profile is required. Therefore, adverse effect on the 125 V DC Class 1E battery loading.
PMR 00-0120 (SE 99-0068) during the first This change provided for the reduction in the HPCS battery peak loading, margin. Battery thirteen seconds of HPCS operation to restore the battery's lost aging operation for the peak load was reduced by changing the timing of the changing motor addition, the duty HPCS pump motor and HPCS diesel generator output breakers. In were revised to cycle values for field flashing for diesel lube oil system pump DLO-P-10 match the values used in the battery sizing calculation.
Safety Evaluation Summary diesel generator The safety evaluation concluded that the change did not affect the HPCS sized and or HPCS pump motor safety-related functions. The HPCS battery is adequately Page 23
Columbia Generating Station 2001 Annual Operating Report the margin in the battery sizing calculation was reduced from 125% to 116% to avoid exceeding the battery duty cycle peak currently referenced in the Technical Specifications.
The change reduced the HPCS battery duty cycle peak current, which also lowers the surveillance test acceptance values, and restored the battery's lost aging margin.
The operation of the charging motor breaker was changed to prevent the breaker from being re-closed for one-to-two seconds after the trip; the time it takes to recharge the closing spring. This design is acceptable since none of the HPCS system accident or transient response scenarios require the re-closure of the HPCS emergency diesel generator (DG3) output breaker or the HPCS pump breaker (HPCS-CB-P1) after trip.
When a LOCA signal is received with the diesel generator in the test mode and paralleled with the offsite power source, the DG will auto-return from the test mode and the output breaker will trip and the loads will be applied to the off site source.
In addition, as an unrelated change to this design modification, the duty cycle values for field flashing and DLO-P-10 were revised to match the values used in battery sizing calculation. This calculation was revised to use device resistance data and nominal system voltage to conservatively determine the duty cycle value for field flashing.
This change provided for the replacement of threaded pipe caps with quick-disconnects on control rod drive scram discharge volume vents. The quick-disconnects will facilitate venting air when filling the scram discharge volume with water to calibrate scram discharge volume level transmitters and level switches. Installation of the quick disconnects will reduce labor time, which will result in less radiation exposure and also minimize the potential for contamination.
Safety Evaluation Summary The safety evaluation concluded that the new quick-disconnects function is equivalent to or better than the original pipe caps. The pipe caps and the replacement quick-disconnects are neither safety-related nor are they pressure-retaining components. This activity does not result in a change to the plant that will adversely impact any safety-related systems, structures or components.
This change provided for the replacement of existing containment instrument air system valves CIA-RV-5A and CIA-RV-5B Lonergan Model LCT-30 relief valves with Crosby 800 Omni-Trim valves. The Lonergan models are no longer available. The replacement Crosby valves meet the CIA design criteria for Code Group C (ASME III, Section 3). In addition, a test port was provided in the discharge path of each relief valve at a location prior to the junction of the discharge paths into a common pipe.
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Columbia Generating Station 2001 Annual Operating Report Safety Evaluation Summary The safety evaluation concluded that the replacement of original equipment valves with Crosby items, and the addition of test ports in the discharge piping, did not increase the probability or consequence of any accident or equipment malfunction.
Changing CIA-RV-5A and 5B to Crosby components does not affect the capability of any system, structure or component to perform its intended safety function. The Crosby replacement valves are designed and manufactured to ASME III Class 3 specifications.
Since Crosby is now the owner of the Lonergan line of valves, this portion of the change is considered a component replacement with an acceptable substitute. Installation of the test ports will allow for relief valve testing without removing any portion of the CIA system from service. Installation and materials for the test connections meet Quality Class 1 (QC1) and ASME Code Group D piping requirements.
This change provided for the replacement of a hose with a hard pipe vent line from the reactor core isolation cooling system head spray area. This will allow plant operators to vent the piping without having to go into a high radiation zone.
Safety Evaluation Summary The safety evaluation concluded that the new piping was designed and analyzed in accordance with the ASME III, Class 2 piping requirements. The new pipe supports were designed in accordance with Seismic Category 1 criteria. The new material is ASME III material which meets the code specifications for the piping. The new design will meet the code requirements for this application and will not affect the safety function of the vent line (which is to maintain pressure integrity). The new vent line piping has been designed and will be constructed to maintain the passive safety function of pressure integrity.
This change provided for the removal of the pressure reducing valves associated with main turbine hood spray controllers COND-PC-30A, COND-PC-30B and COND-PC-30C to allow more stable pressure control of the condensate water sprayed into the turbine exhaust steam entering the top of the main condenser when hood spray is in operation.
Safety Evaluation Summary The safety evaluation concluded that the modification will not change or effect any operating or design characteristics. The change allows for the hood sprays to function properly and as originally intended and will not adversely impact any system, structure, component or safety analysis.
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Columbia Generating Station 2001 Annual Operating Report TER 99-0182 (SE 00-0053)
This change provided for the replacement of turbine service water supply and return piping to correct a pinhole leak and enhance the existing piping configuration by removing dead legs which accumulate debris and rust.
Safety Evaluation Summary The safety evaluation concluded that the new piping and pipe fitting material meets the piping design specifications for the turbine service water system. The new configuration could not cause a different accident than those described in the safety analysis report because the piping and pipe supports are designed and constructed to the same specifications as the existing configuration.
This change provided for the replacement of high pressure core spray system valve HPCS V-102 with a welded pipe plug to minimize or eliminate the occurrence of vibration fatigue failure in the weld connection.
Safety Evaluation Summary The safety evaluation concluded that the modification will actually reduce the weld and pipe stresses at the critical location and will not impact operation of the instrument line or of the various in-line equipment. The modification will not result in a degradation of nuclear safety or in an unsafe configuration. The system will also continue to meet the design requirements of the ASME Code.
This change provided for the replacement of low pressure core spray system valve LPCS V-83 with a welded pipe plug to minimize or eliminate the occurrence of vibration fatigue failure in the weld connection.
Safety Evaluation Summary The safety evaluation concluded that the modification will actually reduce the weld and pipe stresses at the critical location and will not impact operation of the instrument line or of the various in-line equipment. The modification will not result in a degradation of nuclear safety or in an unsafe configuration. It system will also continue to meet the design requirements of ASME Code.
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Columbia Generating Station 2001 Annual Operating Report TMR 01-008 (SE 01-0020)
This change provided for the deactivation of the loose parts detection system (LPDS) by electrically isolating the system from the input power sources, and removing interconnections with the rod drive control system.
Safety Evaluation Summary The safety evaluation concluded that deactivation of the LPDS does not yield an unreviewed safety question. The LPDS is neither an initiator nor mitigator of any previously analyzed accident or equipment malfunction. Furthermore, deactivation of LPDS is an industry initiative documented in BWROG Owners Group Topical Report NEDC 32975P, "Regulatory Relaxation for BWR Loose parts Monitoring Systems."
The topical report was approved by the NRC on January 25, 2001.
TMR 01-025 (SE 01-0031)
This change provided for deactivation of electro-hydraulic operators (EHOs) for reactor closed cooling system valves RCC-TCV-71A, RCC-TCV-71B, RCC-TCV-71C, and RCC-TCV-72B to provide continuous full flow to the containment air system cooling units.
Safety Evaluation Summary It was concluded from the safety evaluation that the change has no impact on any previously analyzed accident or transient. Operation with RCC-TCV-71A, RCC-TCV 71B, RCC-TCV-71C, and RCC-TCV-72B in the full-open position is within the design capacity of the reactor closed cooling water system. All the temperature control valves are normally full-open during power operation. The flow of cooling water through the cooling coils of CRA-FC-2A and CRA-FC-2C will be maximized when the temperature control valves are completely open. This configuration will not affect the containment isolation function of the reactor closed cooling water system or its ability to remove heat from nonessential systems. Drywell temperatures will continue to be maintained within Technical Specification limits.
TMR 01-026 (SE 01-0035)
This change provided for the removal of thermocouple TG-TE-SMTIC2 and its associated mounting bracket from the Low Pressure (LP) No. 2 turbine inner cylinder of the main turbine generator. The mounting bracket was found broken loose and lodged in the LP No. 2 stationary blading when the turbine was disassembled during the 2001 maintenance and refueling outage. The thermocouple was not replaced when the LP No. 2 turbine was reassembled.
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Columbia Generating Station 2001 Annual Operating Report Safety Evaluation Summary The safety evaluation concluded that the thermocouple is used only for monitoring and provides post-failure information for the main turbine generator. The turbine generator is not required for safe shutdown nor does it perform any safety function.
Furthermore, the thermocouple provided no protective function for the turbine generator.
TMR 01-034 (SE 01-0042)
This change provided the temporarily disabling of the position indication of reactor of a feedwater system valves RFW-V-32A and RFW-V-32B to allow the installation around the valve welded cover onto the stuffing box and correct a recurring leak position indication shaft packing gland area.
Safety Evaluation Summary or The safety evaluation concluded that this will have no impact on plant system safety operability. The installation of the welded cover on the stuffing box will enhance pressure integrity function of the valve. Removal of the position indication switches assembly will affect control room reading and valve exercising requirements.
no However, there is no impact on the safety related function of the valve. There are control room operator actions that rely upon valve position indication during accident scenarios.
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Columbia Generating Station 2001 Annual Operating Report 2.6.2 Licensing Document Changes Notices This section contains information pertaining to Licensing Document Change (LDCNs) and is included pursuant to 10 CFR 50.59.
LDCN-FSAR-99-098 (SE 99-0069) 13 of the This LDCN changed the position of Shift Technical Advisor (STA) in Section (licensed or non FSAR to a "function" that can be staffed by either a dedicated individual Supervisor (CRS),
licensed) or by an individual filling a dual role as the Control Room individual is Shift Manager (SM) or Shift Support Supervisor. When the STA qualified is required filling a dual role as the CRS or SM, another Senior Reactor Operator (SRO) response support to the to be on-shift to provide independent oversight and emergency SM.
Safety Evaluation Summary way of The safety evaluation concluded that the NRC has determined this is an acceptable methods for meeting STA requirements. NRC Generic Letter 86-04 provides two for elimination licensees to satisfy the requirements of NUREG 0737. Option I provides required (SRO) of the separate STA position by allowing licensees to combine one of the 2 states that positions with the STA position into a dual-role (SRO/STA) position. Option licensed a licensee may continue to use an NRC-approved STA program while meeting Option operator staffing requirements. Columbia Generating Station has previously used
- 2. These changes would allow the use of either Option 1 or 2.
LDCN-FSAR-00-043 (SE 01-0016) that the This LDCN changed Section 9.1.1.3.2 of the FSAR by removing the statement the yield bail handle yields at less than 1000 lb force. This statement implied that racks.
strength was a design feature to protect the integrity of the new fuel storage With the yield strength of the bail handles somewhat higher for the current fuel designs this feature no longer can be credited. In order to limit the force on the rack, the change was made to state that the jib crane is used to handle new fuel in the new fuel handling vault. In conjunction with this statement, any reference to the auxiliary hoist fuel in the vault was removed.
Safety Evaluation Summary new The safety evaluation concluded that these changes preserved the design feature of the is no fuel vault by limiting the forces that could be applied to the rack and, therefore, there unreviewed safety question.
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Columbia Generating Station 2001 Annual Operating Report LDCN-FSAR-00-099 (SE 01-0002)
This LDCN corrected or added information to Sections 3.9.2.2 and 3.10 of the FSAR to improve the integrity of this data, which demonstrates seismic/dynamic qualification of safety related equipment.
Safety Evaluation Summary The safety evaluation concluded that these changes did not result in an unreviewed safety question. While some reported allowable or resultant stress values changed, the components addressed remained seismically/dynamically qualified based on required stresses meeting allowable values.
LDCN-FSAR-00-101 (SE 00-0070)
This LDCN revised the wording describing the jockey fire pumps in Section F.2.4.1 of the FSAR and added additional NFPA code deviations to Table F.2-1.
Safety Evaluation Summary The safety evaluation concluded that the changes do not constitute an unreviewed safety question. They do not adversely affect the ability to achieve and maintain post-fire safe shutdown or adversely impact associated plant systems or design/license bases.
LDCN-FSAR-01-002 (SE 01-0003)
This LDCN changed Section 12.5.2.d.2 of the FSAR to clarify that electronic dosimeters will be allowed for use when their alarm may not be heard except when they are used to fulfill the alarming dosimeter function described in Technical Specification 5.7. When used in accordance with the Technical Specifications, alternative methods of warning are required when the audible alarm may not be heard.
Safety Evaluation Summary The safety evaluation concluded that this change did not constitute an unreviewed safety question, as it is only clarifying the use of alarm and alternative alarm devices.
LDCN-FSAR-01-016 (SE 01-0011)
LDCN-LCS-01-017 These LDCNs changed the FSAR and the Licensee Controlled Specifications (LCS) to reflect the use of the Westinghouse Multi Lift Tool (MTL) on the refuel bridge monorail hoist.
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Columbia Generating Station 2001 Annual Operating Report Safety Evaluation Summary The safety evaluation concluded that the implementation of increased monorail hoist load set points for MTL operation, plus the installation and use of the MTL and temporary control rod blade exchange racks does not create an unreviewed safety question. The installation and use of these tools does not create conditions adverse to safety, nor do they create new accident scenarios, nor do they increase the probability or consequences of previously evaluated accidents in the FSAR.
LDCN-FSAR-01-042 (SE 01-0024)
This LDCN deleted the detailed description of the testing methods and the testing requirements for the containment atmosphere and suppression pool level excess flow check valves (EFCVs). It established the component's importance to safety designation and that the plant maintenance program is the proper program for controlling testing.
Safety Evaluation Summary The safety evaluation concluded that the deletion of specific requirements to test and perform testing at a specified interval does not increase the probability of a malfunction of a component important to safety because these EFCVs do not have an active safety function to close. The periodic exercising of the EFCV does not improve, degrade, or affect its passive integrity ability in any way. Likewise, the periodic cycling at least once every 30 months of the EFCV does not improve, degrade, or effect its ability to remain open to provide accident mitigating sensors the ability to sense changing containment atmosphere or suppression pool parameters. Therefore, there is no increase in the probability of failure or consequence of a component important to safety as a result of this change.
LDCN-FSAR-01-049 (SE 01-0032)
This LDCN amended and revised detail from the FSAR description of the dryer and separator slings and the reactor pressure vessel head detensioning/tensioning process.
These changes will allow future changes to the reactor pressure vessel head detensioning/tensioning processes and replacement of the wire rope slings with equivalent or higher rated Kevlar slings.
Safety Evaluation Summary The safety evaluation concluded that the changes have no impact upon any Columbia Generating Station or FSAR requirement. There is no impact upon the probability of occurrence or the consequences associated with any accident or malfunction evaluated previously. The possibility of an accident or malfunction of a different type than any Page 31
Columbia Generating Station 2001 Annual Operating Report of safety as evaluated previously is not created. There is no impact upon the margin defined in the basis of any Technical Specification.
requirements for The change does not alter the design, safe working load or safe load path Heavy Loads at Nuclear any lifting device. All applicable NUREG-0612, "Control of and separator sling Power Plants," requirements will continue to be met for the dryer lifting device assemblies and reactor building crane MT-CRA-2.
LDCN-LCS-01-030 (SE 01-0019) for RCIC-V-63 located This LDCN relaxed the maximum isolation time value specified containment in LCS Table 1.6.1.3-1. RCIC-V-63 functions as an inboard primary of facilitate backseating isolation valve for the RCIC steam supply line. This will RCIC-V-63 RCIC-V-63 if required due to packing degradation while maintaining operable in support of RCIC system operability.
Safety Evaluation Summary question identified The safety evaluation concluded that there was no unreviewed safety requirement due to for the proposed increase in RCIC-V-63 maximum isolation time is being electrically back seating the valve to full open position. Valve RCIC-V-63 increasing its closing backseated, thus positioning its wedge further open, and as such, time.
LDCN-ODCM-98-041 (SE 98-0024) to: 1) replace This LDCN revised the Offsite Dose Calculation Manual (ODCM)
System with Energy references to Washington Public Power Supply System or Supply to RFO 6.2.1.1; 3)
Northwest; 2) replace a quotation from RFO 6.2.1.1 with a reference statements of the add a statement to the introduction which references the applicability
- 4) add a technical specifications as applicable to the ODCM requirements for operability; the definitions for definition section which replaces the frequency notation and some of statement consistency with the improved technical specifications; and 5) remove a footnote eliminates the need because driving regulation 10 CFR 50.36 was revised in a manner that for the statement.
Safety Evaluation Summary editorial, clarified The safety evaluation concluded that the changes were either requirements or deleted references to obsolete requirements. The definitions and and NRC frequency notation table were taken verbatim from previously-evaluated are in approved technical specification content. The applicability statements referenced maintains the the NRC-approved Standard Technical Specification NUREGs. The change CFR 190, 10 CFR level of radioactive effluent control required by 10 CFR 20, 40 Page 32
Columbia Generating Station 2001 Annual Operating Report the accuracy or 50.36(a), and 10 CFR 50, Appendix I, and does not adversely impact reliability of current effluent, dose, or setpoint calculations.
LDCN-TSB-00-104 (SE 00-0073) 3.6.1.3.8 This LDCN revised Technical Specification Bases Surveillance Requirement excess flow check to allow an increase in the pressure range for reactor instrument line valve testing.
Safety Evaluation Summary unreviewed safety The safety evaluation concluded that the change did not result in an psig to 85-1050 psig.
question. The test pressure range will be increased from 85-300 pressure allowed The range was deemed conservative in comparison to the maximum to address reactor by Technical Memorandum TM-2080, which was prepared testing. The instrument line EFCV testing during reactor pressure vessel hydrostatic of the test.
technical memorandum contains the requirements for the performance LDCN-TSB-01-038 (SE 01-0001) regarding movement of This LDCN added notes to the Technical Specifications Bases irradiated fuel in secondary containment. These notes state, "that handling a welded and leak tested, is cask/canister loaded with spent fuel, after the canister is seal not considered to be movement of irradiated fuel."
Safety Evaluation Summary pertaining to The safety evaluation concluded that Technical Specification Bases a loaded spent fuel secondary containment operability do not apply to handling of the leak test canister within the reactor building once the canister is sealed and passes requirements. This is due to the fact that once a canister is properly loaded and sealed, spent fuel canister handling of irradiated fuel ceases and handling of an NRC certified begins. This position was communicated to the NRC by separate letter.
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Columbia Generating Station 2001 Annual Operating Report 2.6.3 Miscellaneous Changes This section contains information pertaining to other plant activities and is included pursuant to 10 CFR 50.59.
Action Request 1556 (SE 01-0007)
This request provided for replacement valves for glycol system relief valves GY-RV-18A have a and GY-RV-18B (the existing models were no longer available). The new valves of the one-inch discharge port instead of a three-quarter-inch discharge port. The height discharge piping discharge port is also different between the old and new valves and required modification in order to use the new style relief valves.
heat Valves GY-RV-18A and 18B protect the tube side of the offgas dryer chiller exchangers and discharge to the Glycol Storage Tank GY-TK-2.
Safety Evaluation Summary and The safety evaluation concluded that the associated piping pressure rating will performance, as well as the function of relief valves GY-RV-18A and GY-RV-18B, be unaffected by this change. Because the change will have no impact, there are no new accident scenarios introduced by the change. All plant systems and components required this to mitigate the consequences of accidents previously evaluated will not be impacted by modification.
Action Request 1566 (SE 01-0005)
This request provided for the cutting and capping of a cross connection pipe between the tower makeup system and the potable water system. This pipe had been isolated by closed valve TMU-V-102 because production of potable water was moved from the tower makeup system to the potable water distribution system. It has been determined that the single closed valve (TMU-V-102) has not been a sufficient cross connection control device in accordance with State of Washington drinking water regulations.
Safety Evaluation Summary The safety evaluation concluded that none of the systems, equipment or components associated with the change are safety related, important to any safety function, or in direct support of any safety related function. There is no accident analysis that uses the systems, equipment or components. The change will not create the possibility of any new accident types or different malfunctions of equipment important to safety. The change also does not affect system operation or how it functions.
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Columbia Generating Station 2001 Annual Operating Report Action Request 1573 (SE 00-0071)
This request provided for revising the normal operating positions of turbine service water valves TSW-V-123A and TSW-V-123B from "open" to "closed" to isolate radwaste building automatic vent valves TSW-AV-2A and TSW-AV-2B.
Safety Evaluation Summary The safety evaluation concluded that the turbine service water system is designed to provide cooling water to remove the maximum expected heat rejected from non-essential, non-safety related auxiliary equipment during normal plant operations. Valves TSW-AV 2A and TSW-AV-2B are mechanical devices and have no electrical interfaces with plant equipment. The operation of these vent valves through manual actions, as dictated by operating procedure during system startups and shutdowns, does not adversely impact the physical integrity or functioning of the turbine service water system nor does it create any new interfaces with other plant equipment. Accordingly, the activity will not initiate any previously evaluated design basis accidents or transients, nor will the activity impact any safety system, structure, or component.
Action Request 2089 (SE 01-0047)
This request provided for a permanent method of mitigating a steam leak from the packing gland on main steam system globe valve MS-V-706A by changing the valve to a gate valve.
Safety Evaluation Summary The safety evaluation concluded that there will be no adverse impact to the integrity of the main steam system as a result of changing from a globe valve to a gate valve. All ASME Code requirements will be maintained. The change from a globe valve to a gate valve will not impact the ability of the main steam system piping to maintain its pressure integrity for accident mitigation. The manner in which the valve is operated and controlled will not change.
Clearance Order D-PMA-AC-51-001 (SE 01-0044)
This activity evaluated the acceptability of circulating water system air conditioning unit PMA-AC-51 being out of service for an extended period of time. The new replacement unit has been installed and connected except for the electrical connections. A technical evaluation request was initiated to address the difference in the current draw between the new unit and the old one.
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Columbia Generating Station 2001 Annual Operating Report Safety Evaluation Summary The safety evaluation concluded that HVAC equipment in the circulating water system pump house is not considered in any accident scenario in the safety analysis report. This equipment has no safety function. Malfunction or failure of this equipment will not impair normal or emergency plant operation. Since this equipment is inoperative, it can be considered malfunctioned or failed and inoperable and will not adversely affect plant operation.
Caution Tag C-ANN-P602/A5 001 (SE 01-0043)
This activity provided for the disabling of the offgas sample flow high/low annunciator until problems with moisture in sample lines can be resolved.
Safety Evaluation Summary The safety evaluation concluded that the offgas pretreatment radiation monitor is used to provide indication and alarm functions and initiates no protective functions. The monitor has no function which is credited in any accident analysis. The annunciator for offgas pretreatment sample flow high/low has no channel trip associated with it. Disabling the annunciator will not prevent the monitor from continuing to perform the monitoring function. During offgas system operations, pretreatment flow is established by differential pressure between steam jet air ejector outlet and main condenser pressures. This differential pressure does not vary significantly and average sample flow is relatively constant. Furthermore, Chemistry personnel perform a daily check of sample flow to ensure adequate flow.
Danger Tag 01-0784 (SE 01-00041)
This activity provided for deactivation of containment monitoring system wetwell sample valve PI-VX-269, a containment sample valve for sample rack CMS-SR-14, and closing its associated manual block valve (PI-V-X84B). Due to mounting constraints, the sample valve does not consistently close when required.
Safety Evaluation Summary The safety evaluation concluded that deactivation of sample valve PI-VX-269 does not represent an unreviewed safety question. The function for monitoring will be maintained using the remaining drywell sample points on CMS-SR-14 and the drywell and wetwell sample points on CMS-SR-13. Since the manual valve will be closed, there is no adverse impact to the containment isolation function. The purpose of the sampling is to monitor the drywell and wetwell for hydrogen and oxygen concentrations after a LOCA. This monitoring information is used to determine when to remove the containment atmosphere control system from operation. The containment atmosphere control system is started Page 36
Columbia Generating Station 2001 Annual Operating Report this valve will not manually to assure a mixing of the gasses in containment. Deactivating points to obtain a affect this function as there remains an adequate number of sample accident sampling representative sample. In addition, the grab sample function of the post system is available to supplement this sampling function.
Configuration Document Change Request 0000000857 (SE 01-0009) core isolation This request revised a plant flow diagram to indicate that, for reactor classification is the cooling system valves RCIC-V-1 and RCIC-V-2, the Code Group part of the turbine skid.
same as that of RCIC turbine RCIC-DT-1 because the valves are This change made the flow diagram consistent with FSAR Table 3.2-1.
Safety Evaluation Summary no impact on the The safety evaluation concluded that change to the flow diagram has system. It simply plant or the function and operation of the reactor core isolation cooling is in accordance makes the flow diagram consistent with the FSAR Table 3.2-1, which with the original design.
Plant Procedure 10.3.21 (SE 01-0013)
Plant Procedure 10.3.22 chute) to allow The change revised the load path for the portable fuel transfer shield (cattle location in the it to remain submerged in water while traversing from its storage The old load dryer/separator pool to its in-service location at the cavity/fuel pool channel.
was lifted from its path required the cattle chute to be out of the water from the time it reduce exposure storage location until it reached its in-service location. This change will cattle chute. The to plant personnel working on the refuel floor during transfer of the path.
procedures include the option to travel along either the old or the new load Safety Evaluation Summary lugs and MT The safety evaluation concluded that the handling system (rigging, lifting of NUREG-0612 CRA-2) used for lifting the cattle chute complies with the requirements underwater is for a single-failure-proof system. The movement of the cattle chute will not be any bounded by the movement of the steam separator which ensures that there both cattle adverse impacts with the head studs or pool curb. To the extent practical, chute load paths follow existing structural members.
Problem Evaluation Request 201-1461 (SE 01-0046) of a steam This provided for the temporary repair, by means of the Furmanite process, An attempt to leak from the packing gland on main steam system valve MS-V-706A.
holes in backseat the valve failed to stop the leak. The repair was performed by drilling Page 37
Columbia Generating Station 2001 Annual Operating Report area to mitigate the the valve bonnet and injecting Furmanite material into the packing leak.
Safety Evaluation Summary by Furmanite and The safety evaluation concluded that the process would be controlled XI, repair plan.
Columbia Generating Station procedures, and an ASME, Section All ASME code There will be no adverse impact to the pressure integrity of the valve.
affect reactor requirements will be maintained and the process will not adversely operations.
Work Order 01016880-12 (SE 01-0025) quality motor This work order provided for an alternate power source for augmented related low voltage control center E-MC-7CB which is taken from non-safety power was switchgear E-SL-31/4C (spare) during plant shutdown to ensure continuous available for refueling activities during a divisional outage.
Safety Evaluation Summary source to The safety evaluation concluded that the temporary modification of the power any other system to E-MC-7CB has no impact on the ability of the electrical system or is employed perform its credited safety function. Overcurrent and overload protection any adverse to ensure the effects of a motor control center branch circuit will not have in design basis effects on the non-safety related switchgear performance, as defined to operate safely calculations. The motor control center and switchgear will continue without affecting any other equipment.
Work Order 01016880-14 (SE 01-0026) pump This work order provided for an alternate power source for fuel pool cooling 8C (spare)
FPC-P-1B from the safety related motor control center E-MCC-7BB Cubicle below 125 during plant shutdown to assist in maintaining spent fuel pool temperature degrees Fahrenheit.
Safety Evaluation Summary source to The safety evaluation concluded that temporary modification of the power other FPC-P-1B has no effect on the ability of the fuel pool cooling system or any is system to perform its intended safety function. Overcurrent and overload protection not have employed to ensure the effects of a motor control center branch circuit will in any adverse effects on the non-safety related switchgear performance, as defined to design basis calculations. The motor control center and switchgear will continue operate safely without affecting any other equipment.
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Columbia Generating Station 2001 Annual Operating Report Work Order 01016880 (SE 01-0028) which is This work order provided for a power source for a temporary load center, divisional outage taken from the non-safety related switchgear E-SL-11/3A, to support activities.
Safety Evaluation Summary a power source to a The safety evaluation concluded that the temporary modification of system or temporary load center has no adverse impact on the ability of the electrical and overload any other system to perform its credited safety function. Overcurrent center will not protection is employed to ensure the effects of the addition of the load as defined in have any adverse effect on the non-safety related switchgear performance, safely without design basis calculations. The switchgear will continue to operate affecting any other equipment.
Work Order 01016880-12 (SE 01-0034) to non-safety This work order provided for temporary power from a weld receptacle is out of service related battery charger C1-7 during the time the normal power supply to support divisional outage activities.
Safety Evaluation Summary that is not The safety evaluation concluded that charger C1-7 is a Class 2 component power to this credited in any accident scenario or the Technical Specifications. The power supply is charger will allow battery Bl-7 to remain charged while the normal removed from service for preventive maintenance activities.
Work Order 01016880-16 (SE 01-0037) pump EDR This work order provided for temporary power to equipment drain system preventive P-14B from MC-5D while normal power supply MC-6C is de-energized for maintenance activities.
Safety Evaluation Summary mitigation of The safety evaluation concluded that EDR-P-14B plays no part in the the pump to be accidents or transients. Temporary power to EDR-P-14B will allow used during the divisional outage activities.
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Columbia Generating Station 2001 Annual Operating Report Work Order 01016880-16 (SE 01-0038)
This work order provided for temporary power to reactor water cleanup system demineralizer desiccant pump RWCU-P-27 from MC-5D while normal power supply, MC-6C, is de-energized for preventive maintenance activities.
Safety Evaluation Summary The safety evaluation concluded that RWCU-P-27 plays no part in the mitigation of accidents or transients. Temporary electrical power to RWCU-P-27 will allow liquid waste processing to continue while the normal power supply is out of service for preventive maintenance.
Work Order 01016880-42 (SE 01-0036)
This work order provided for temporary power to the radwaste building elevator from MC-3D while normal power supply MC-6B is de-energized for preventive maintenance activities.
Safety Evaluation Summary The safety evaluation concluded that the radwaste building elevator plays no part in the mitigation of accidents or transients. Temporary power to the elevator will allow the elevator to continue to be used for outage activities.
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Columbia Generating Station 2001 Annual Operating Report 2.7 Regulatory Commitment Changes (NEI Process)
This section is used for information pertaining to Regulatory Commitment Changes (RCC) pursuant to the NEI Guidelines for Managing NRC Commitment Changes. During 2001, there were no commitment changes that satisfied the NEI criteria for reporting. One commitment change was processed where the NRC staff was notified of the change under separate correspondence.
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Appendix A Annual Personnel Radiation Exposure Work and Job Function Report
Columbia Generating Station Reg. Guide 1.16 Work and Job Function Report for CY 2001 Number of Personnel Receiving >100 mrem Total Man-Rem Contract Workers and Contract Workers and Work &Job Function Station Employees Utility Employees Others Station Employees UtlIty Employees Others I T I I ________________ - - - I Reactor Operations &Surveillance Maintenance Personnel 8 2 2.966 0.125 0.937 Operating Personnel 4 0 4.078 0.000 0.000 Health Physics Personnel 18 14 3.152 0.125 1.510 Supervisory Personnel 0 0 0.206 0.000 0.000 Engineering Personnel 1 2 0.129 0.084 0.494 Routine Maintenance Maintenance Personnel 110 185 26.935 0.896 53.717 Operating Personnel 29 0 5.003 0.000 0.048 Health Physics Personnel 12 12 5.058 0.023 6.697 Supervisory Personnel 5 0 0.683 0.001 0.000 Engineering Personnel 5 26 0.577 0.336 4.539 Inservice Inspection Maintenance Personnel 1 61 0.812 0002 30.112 Operating Personnel 0 0 0.490 0.000 0.000 Health Physics Personnel 0 1 0.181 0.000 0,226 Supervisory Personnel 0 0 0.000 0.000 0.000 Engineering Personnel 3 26 0.639 0.393 13.352 Special Maintenance*
Maintenance Personnel 6 29 5.186 0.156 7.370 Operating Personnel 0 0 0.604 0.000 0.000 Health Physics Personnel 1 0 0.673 0.038 0.156 Supervisory Personnel 0 0 0.223 0.000 0.000 Engineering Personnel 0 3 0.068 0.232 0.294 Waste Processing Maintenance Personnel 1 2 1.068 0.462 0.920 Operating Personnel 0 1 0.000 0.000 0.102 Health Physics Personnel 0 0 0.134 0.010 0.013 Supervisory Personnel 0 0 0.000 0.000 0.000 Engineering Personnel 0 0 0.000 0.000 0.000 Refueling Maintenance Personnel 20 8 11.215 0.102 2.346 Operating Personnel 0 0 0.346 0.000 0.000 Health Physics Personnel 1 3 0.488 0.000 0.749 Supervisory Personnel 4 0 0.688 0.211 0 0.000 Engineering Personnel 2 0000 0.891 0.285 TOTAL Maintenance Personnel 146 6 287 48.182 1.743 95.402 Operating Personnel 34 0 1 10.521 0.000 0.150 Health Physics Personnel 32 29 9.686 0.196 9.351 Supervisory Personnel 9 0 1800 0.212 0.000 Engineering Personnel 8 12 60 1 413 1l0(IAA IGrand Total 229 20 377 60 71.602 1413 1936 4.087 123.867 Total number of personnel receiving >100 mrem = 626 Total man-rem for personnel receiving > 1O0mrem = 199.556 Report produced from electronic dosimeter data 1 of 2
Columbia Generating Station Reg. Guide 1.16 Work and Job Function Report for CY 2001
- Special Maintenance:
"* RRC-P-1B seal replacement and associated support work (forced outage)
"* MMS sample rack installation for NMC/HWC (BDC 94-0274-3D)
"* LPCS-V-83 removal & modification (TER 136801)
"* HPCS-V-102 removal & modification (TER 136701)
"* SFP cask area modifications (ISFSI)
"* ECP/LPRM replacement (BDC 94-0274-4F)
"* Replace TSW piping to/from PSR-SR-8, 9, & 11
"* SRM/IRM conduit 7SRM 13-1 & cable replacement
"* MS-V-GV/1 DEH leak repair 2 of 2