IR 05000245/1982012
| ML20058C825 | |
| Person / Time | |
|---|---|
| Site: | Millstone, 05002458  |
| Issue date: | 07/09/1982 |
| From: | Briggs L, Elsasser T, Lipinski D, Shedlosky J NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I) |
| To: | |
| Shared Package | |
| ML20058C758 | List: |
| References | |
| 50-245-82-12, 50-336-82-12, NUDOCS 8207260453 | |
| Download: ML20058C825 (15) | |
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U.S. NUCLEAR REGULATORY COMMISSION Region I 50-245/82-12 Report No. 50-336/82-12 50-245 Docket No. 50-336
[PR-21 License No. DPR-65 Priority Category C
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Licensee:
Northeast Nuclear Energy Company P.O. Box 270 Hartford, Connecticut 06101 Facility Name: Millstone Nuclear Power Station, Units 1 & 2 Inspection at: Waterford, Connecticut 06385 Inspection conducted:
May 9 thru June 26, 1982
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Inspectors:
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//$ der T. Shedlosky, S Resident Inspector cfate ' signed ne.8:s
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D. R. Lipinski, Resident Inspector date signed YA AE
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d 1. E. Briggsp 7roject Inspector date signed
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Approved by:
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T. C. El r, Chief date signed Reactor ojects Section 1B, Division of Project & Resident Programs Inspection Summary:
Unit 1: Routine facility safety inspections, May 9 thru June 26, 1982 (Report Number 50-245/82-12) including: evaluations of plant operations, equipment alignments and readiness, radiation protection, physical security, fire protection, plant operating records, maintenance and modifications, surveillance testing and calibrations, and reporting to the NRC.
The inspection involved 118 hours0.00137 days <br />0.0328 hours <br />1.951058e-4 weeks <br />4.4899e-5 months <br /> of onsite, regular, and backshift inspection effort by two resident inspectors.
8207260453 820709 PDR ADOCK 05000245 G
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Resul ts:
No Violations were identified.
Unit 2:
Routine facility safety inspections, May 9 thru June 26, 1982 (Report Number 50-336/82-12) including: evaluations of plant operations, equipment alignments and readiness, radiation protection, physical security, fire protection, plant operating records, maintenance and modifications surveillance testing and calibrations, and reporting to the NRC. The inspection involved 184 hours0.00213 days <br />0.0511 hours <br />3.042328e-4 weeks <br />7.0012e-5 months <br /> of onsite, regular, and backshift effort by two resident inspectors.
Resul ts:
No Violations were identified, a
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DCS Identification Numbers NRC Inspection No. 50-245/82-12 50-336/82-12 DCS Numbers Report Paragraph 50245-820412
50245-820413
50245-820508
50336-820401
50336-820405
50336-820417
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50336-820417
50336-820506
50336-820513
50336-820607
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DETAILS 1.
Persons Contacted The below listed technical and supervisory level personnel were among those contacted:
A. Cheatham, Radiological Services Supervisor J. Crockett, Unit 3 Superintendent F. Dacimo, Quality Services Supervisor E. C. Farrell, Station Services Superintendent B. Granados, Health Physics Supervisor H. Haynes, Unit 2 Instrumentation and Control Supervisor R. J. Herbert, Unit 1 Superintendent J. Kangley, Chemistry Supervisor J. Keenan, Unit 2 Engineering Supervisor J. J. Kelley, Unit 2 Superintendent E. J. Mroczka, Station Superintendent V. Papadopoli, Quality Assurance Supervisor R. Place, Unit 2 Engineering Supervisor R. Palmieri, Unit 1 Engineering Supervisor W. Romberg, Unit 1 Operations Supervisor S. Scace, Unit 2 Operations Supervisor F. Teeple, Unit 1 Instrumentation and Control Supervisor W. Varney, Unit 1 Maintenance Supervisor P. Weekley, Security Supervisor 2.
Status of Open Items New items.
Unit 1 245/82-12-01, Review of status of Piping and Instrument Diagrams (Report Paragraph 6.)
Unit i None Old items:
Unit 1 245/80-02,(Closed). This item initially involved In Service Testing (IST)
of three valves 1-IC-12, 301-138, and 1-RC-6.
Corrective action for 1-IC-12 involved document and procedure control and is discussed under item 245/80-21-01 in this report. Corrective action for valve 301-138 was docu-mented in Inspection Report 245/80-08. Valve 1-RC-6 is a check valve, the
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testing of which is not practicable during plant operation. The licensee has specifically designated this valve as not testable during operation in accordance with ASME Boiler Pressure Vessel Code Section IX, Article IWV-3522 and has requested relief from the requirement to test this valve during each cold shutdown. The licensee is preparing procedures for the testing of 1-RC-6 during periods when it is accessible. The valve was last tested on March 11, 1981.
The licensee has long-range plans to replace check valve 1-RC-6, which serves as a containment isolation valve for the portion of the Reactor Building Closed Cooling Water System extending into containment, with motor-operated valves. The containment isolation function of 1-RC-6 is being addressed in the application for a Full Term Operating License.
The inspector has no further questions regarding the inservice inspection of these valves.
245/80-22-01(Closed). This item was opened to follow the results of non-destructive testing of five jet pump beam blocks replaced during.
the 1980-81 refueling outage. Two of the five beams had in'dications wfien evaluated by the dye penetrant method. The licensee is plannin all twenty jet pump beam blocks with BWR-4 design beam blocks (g to repla~ce generally thicker in high stress areas) of an improved material less susceptible to stress corrosion cracking. This item is closed. The replacement of all existing beam blocks and their subsequent performance will be addressed as follow-up to Bulletin 80-07, 245/80-21-01 (Closed). This item reflects difficulties experienced in maintaining current copies of valve line-up check lists and controlled operations data foms. The inspectors observed that a program of monthly auditsof the stowage areas for blank forms and checklists has been imple-mented and that, based on a spot check of blank forms, the problem has not recurred. This item is closed.
245/80-21-02 (Closed). This item reflects difficulties experienced in distributing procedure changes by their effective date. The inspectors observed that document flow has improved since the licensee increased office staffing, filled the position of Unit 1 Operations Technical Aide, and installed additional high-speed copy equipment.
This item is closed.
245/80-21-06 (Closed). Valve line-up control following maintenance and outages was followed by this item. The licensee has approved and implemented revision 1 to Administrative Control Procedure ACP 2.12 " System Valve Alignment Control." This procedure includes guidance for selecting the scope of valve lineups following maintenance and major outages. The procedure j
also provides fer a sceand review of valve line-up selections following an outage. Documentation requirements for lineups prior to unit startup and following maintenance are detailed. The inspectors reviewed valve line-ups, particularly those conducted following maintenance on a sampling basis to verify implementation of this program. This item is closed.
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245/80-21-05 (Closed). This item was opended to follow licensee efforts to standardize annunciator alam response procedures. Operating Procedure
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OP230, Revision 0," Annunciator Alams and Response" became effective on April 15, 1982. This procedure is a compendium of response procedures T
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for each annunciator window on each control board in the Control Room.
The inspector verified that the fomat of the response listing is standard,
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consisting of:
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Annunciator Location (by. panel and window)
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Alam Title /
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Automatic. Action
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Immediate" Action h
Subsequent Action
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References (including proceduru,' drawings,,and
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Tech. Specs.)
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s The inspector reviewed a sample of the alam, responses and found them to be consistent with references and coqmon practice. The inspector nas no j.
further questions in this matter.
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245/81-05-03 (Closed). This item'was opened to follow the licensce'sj
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engineering evaluation of potentiel modifications to the fuel;nandling
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equipment. The licensee and the equipment ma'nufacturer, Ge3eral El'ectric,
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have concluded that the fuel handling mechanism desigS s not sadily i
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adaptable to alternative load call and slack cable Sensor i0stalTations.
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Refueling procedures have been revised to include measurt:s JCcompensate for the fuel grapple instrument'ation schemd. 'The inspector has no further
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questions on this item.
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3.
Review of Plant Operation - Plant Inspectio'n (Units:,1 and 2)
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The inspectors reviewed plant operations through direct inspection and
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i observation of Units 1 and 2 throughout the reporting period.. Both units operated at full power during the period with exception of minor power reductions for surveillance testing.
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Instrumentation
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Control room process instruments werE observed for correlation between
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channels and for conformanc'e with Technical Specification. requirements.
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No unacceptable conditions were identified.
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The inspector observed various alam,conditiods which had been received and acknowledged. These.~conditifons were discussed with shif t personnel who were knowledgeable of'the alarms and a~ctions required.
During plant inspections, the inspector'observ,cd the condition'of equipment associated with various alarms.
No unaccgptable conditions were identified.
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Shift Manning r
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The operating shifts were observed to be staffed to meet the
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operating requirements of Technical Specifications, Section 6, both
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~j-f to the number and type of licenses. Control room and shift manning
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was observed to be in conformance with Technical Specifications and
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site adninistrative procedures.
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Radiation' Protection ~ Controls IN
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Radiation protection control areas were inspected.
Radiation Work
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r Pennits in use were reviewed and compliance with those documents as
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to protective clothing and required monitoring instruments was s
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inspected.
Proper posting of radiation and high radiation areas was
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reviewed in addition-to verifying requirements for wearing of appropri-ate personal monitoring devices. There were no unacceptable conditions identified.
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Plant Housekeeping Controls
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'v Storage of material and components was observed with respect to
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prevention of fire and safety hazards. Plant housekeeping was evaluated
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with respect to controlling the spread of surface and airborne contamina-tion. There were no unacceptable conditions identified.
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Fire Protection / Prevention
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Th'e inspector examined the condition of selected pieces of fire
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fighting equipment. Combustible materials were being controlled and p',
were not found near vital areas. Selected cable penetrations were
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examined and fire barriers were found intact.
Cable trays were clear
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Control of Equipment During plant ivpections, selected equipment under safety tag control
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Equipment conditions were consistent with information
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Instrument channel checks recorded on routine logs were reviewed. An independent comparison was made of selected instruments. No unacceptable conditions were identified.
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j i. Equipment Lineups
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The inspector exa ained the breaker position on switchgear and motor
control centers in accessible portions of the plant. Equipment conditions, incicding valve lineups, were reviewed for conformance with
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' Technical Specifications and operating requirements. No unacceptable conditions were identified.
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4.
Review of' Plant' Operations - Logs ~and' Records' '(Units ~1 & 2)
During the inspection period, the inspector reviewed operating logs and records covering the inspection time period against Technical Specifications and Aministrative Procedure Requirements.
Included in the review were:
Shift Supervisor's Log daily during control room
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surveillance Plant Incident Reports 5/9/82 through 6/26/82
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Jumper and Lifted Leads Log all active entries
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Maintenance Requests and Job Orders all active entries
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Construction Work Permits all active entries
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Safety Tag Log all active entries
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Plant Recorder Traces daily during control room
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Plant Process Computer Printed
- daily during control room Output surveillance Night Orders daily during control room
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surveillance i
The logs and records were reviewed to verify that entries are properly made; entries involving abnormal conditions provide sufficient detail to connunicate equipment status, deficiencies, corrective action restoration and testing; records are being reviewed by management; operating orders do not conflict with the Technical Specifications; logs and incident reports detail no violations of Technical Specification or reporting requirements; and logs and records are maintained in accordance with Technical Specification and Administrative Control Procedure requirements.
There were no unacceptable conditions identified.
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5.
Safety Related Maintenance - Annual Review (Unit 2)
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Scope: This inspection was conducted as an annual review of maintenance activity to ascertain whether maintenance on safety related l
systems and components were conducted in accordance with approved procedures, industry codes and standards and Technical Specifications.
Maintenance Activities Reviewed:
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J.0, 282-32
" Replacement of Channel A Wide Range Detector"*
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I J.0. 282-343 & 343A
"Rx Coolant Pump 40D Seal Investigation and
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Repairs" i
J.0. 282-95
" Installation of Qualified Transmitters /E.S.A.S. Mods"*
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"2-RC-100F Pressurizer Spray Valve"
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"H.F.A. Relay Replacement"
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J.0. 282-35
" Replacement of Channel D Wide Range Detectors"
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J.0. 282-232 & 232A " Charging Pump A"*
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J.0, 282-92
" Installation of Qualified Transmitters /ESAS Mods"*
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Findings A.
The licensee's program of maintaining corrective maintenace work packages including the original maintenance request, job orders, work procedures, inspection plans and results, material control data, and procedures serves to provide a consolidated record from which activities may be reconstructed.
B.
Based upon review of logs and records, work and retest activities were approved by operating personnel in conformance with Limiting Conditions for Operations.
C.
Consideration during procedure preparation appears to have been given to Quality Assurance (QA) " hold points," housekeeping and cleanliness, fire protection, acceptance testing, procedure format, and occupational safety.
D.
The quality of field documentation was found to be generally com-plete and detailed; however, several weaknesses were identified, as follows:
(1)
Inspection results were not recorded for 20 attributes on the QA Inspection Plans for J,0. 282-92 and J.0. 282-95.
Satisfactory results must be inferred from the "N/A" or
"none" recorded under "open items" and from the inspection item completion signatures for each of the 20 items.
(2)
A leak test was specified as a retest following welding in J.0. 282-232 & 232A. Appropriate data was recorded in hand-drawn blanks on a form used for hydrostatic tests rather than on the form specified for leak rate results in the test proce-dure.
(3)
Results of a cleanliness inspection of pump seals required by the work procedure (MP2703 E6B Revision 3 "RCP Seal Removal
& Installation") are recorded as "NA".
The Job Order was not annotated to specify the applicable portions of the pro-cedure as only the vapor seal was to be replaced.
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A large number of completed work packages dating to late 1981 are in temporary storage in maintenance and quality assurance offices pending review and transfer to the per-manent record repository.
The above items will receive additional attention during routine monthly RRI maintenance inspection...
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Safety System Drawing Review (Unit 1)
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Scope: This independent inspection effort involved obtaining copies of the Piping & Instrument Diagrams (P&ID's) for several safety systems from the nuclear records vault, comparing these P&ID's to the copies of the P&ID's in use in the unit control room and a detailed walk-down of the systems to verify that i
the as-built conditions of the systems are accurately reflected on the P&ID.
Systems verified included:
Core Spray ("B" loop and common suctions)
Isolation Condenser Standby Liquid Control Findings:
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Core Spray System
--- A drain line of what appears to be 3/4" carbon steel isolated by a single manually operated valve exists in the suction lines to each core spray pump (2 valves, 2 drains.) These drains appear neither in the P&ID nor on the valve line-up sheet provided with procedure OP336 Rev. 7 dated 1-15-81 " Core Spray System."
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--- Discharge header drains,1-CS-16B and 1-CS-178, do not appear on the P&ID but are included on the valve line-up list.
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--- Discharge check valve above seat drains are not shown on the P&ID i
but are included on the valve line-up list.
--- Pump motor bearing cooling supply system (consisting of a "Y"-strainer pressure regulator, relief valve, and 5 manual and 1 solenoid valves)
is not shown on the P&ID, but valves are included on the valve line-up list.
--- Pressure instrument PI403 3/4" and 3/8" stop valves appear neither
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on the P&ID nor in the valve line-up list.
--- A sample and/or drain line from the minimum flow path to the torus appears neither on the P&ID nor the valve line-up list. This line includes a 3/4" valve, several 3/8" valves, a pressure gauge, and what appears to.be a pressure regulating valve.
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--- Sensing line stop valves (3/4" and 1/4") to instrument rack 2201 are not shown on the P&ID. The P&ID does not detail the pressure &
flow instrumentation. The valves do appear in the instrument rack valve line-up of procedure SP440.
--- Pump bearing lubricating / cooling water line and fixed orifice are not shown on the P&ID.
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Isolation Condenser System
--- Unlabeled shell side sample / drain valves and line (1/4")
appear neither on P&ID nor valve line-up of procedure OP307, Revision 15 dated 4-30-82, " Isolation Condenser System."
--- Valves 1-IC-59 and 1-IC-60 do not appear on the P&ID, but do appear on the valve line-up list.
--- Piping to level transmitter LT-1341 is depicted on the P&ID as a
" closed tank" system. The actual installation is that of an "open tank" system. Thus a sensing line shown on the P&ID does not exist in the pl ant. The instrument valves appear neither on the P&ID nor on valve line-up lists.
--- Piping and valve arrangements on instrument rack 2257 including a path which could equalize (connect) the supply and return lines... high flow switches high and low head taps... are not depicted on the P&ID.
The valves are included in the valve line-up procedure.
--- The sample valve 1-IC-69 is shown as sampling from the isolation condenser side of valve 1-IC-3.
The existing piping arrangement permits sampling from both sides of 1-IC-3 as well as bypassing that valve via what appears to be 3/4" piping.
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Standby Liquid Control System
--- Pressure instrument stop valves and instrument valves (3/4" and 3/8")
for PI 1157 and PT 1150 are not shown on the P&ID nor included in the valve line-up of procedure OP304, Revision 10, dated 12-16-80 " Standby Liquid Control System."
--- Piping sizes indicated on the P&ID for the test return line are different than those existing in the plant.
--- Chemical neutron poison level instrumentation piping and valving is not accurately depicted on the P&ID nor included on the valve line-up.
A figure is included in procedure OP304 to aid operators.
In the absence of definitive and established standards for P& ids and valve line-up lists, the licensee is currently developing a policy governing these documents.
This study includes evaluating alternative methods of system status control and display. The licensee is currently determining the scope of additional system walk-downs to be conducted of safety systems. An open item (245/82-12-01) is identified to follow the resolution of the status of plant P& ids.
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7.
Review of Periodic and Special Reports Upon receipt, periodic and special reports submitted by the licensee pursuant to Technical Specification 6.9.1 and 6.9.2 and Environmental Technical Specification 5.6.1 were reviewed by the inspector. This review included the following considerations:
the report includes the information required to be reported by NRC requirements; test results and/or supporting information are consistent with design,predic-tions and performance specifications; planned corrective action is adequate for resolution of identified problems; detemination of whether any information in the report should be classified as an abnormal occurrence; and the validity of reported infomation. Within the scope of the above, the following periodic reports were reviewed by the inspector:
Monthly Operating Report, Units 1 & 2, April 1982.
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Monthly Operating Report, Units 1 & 2, May 1982.
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Inspector Witnessing of Surveillance Tests The inspector witnessed the performance of surveillance testing of selected components to verify that:
the surveillance test procedure was properly approved and in use; test instrumentation required by the procedure was calibrated and in use; technical specifications were satisfied prior to removal of the system from service; the test was performed by qualified personnel; the procedure was adequately detailed to assure performance of a satisfactory surveillance; and test results satisfied the procedural -
acceptance criteria or were properly dispositioned. The inspector witnessed the perfomance of:
Unit 1
--- " Power Available Relays Functional Test" per SP412F, Revision 1,
on May 18.
" Emergency Service Water Operational Readiness Test" per SP623.19,
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Revision 4, on June 14.
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--- " Emergency Service Water Vibration and Hydraulic Test" per SP1060.9, Revision 1, on June 14.
" Standby Liquid Control Operational Readiness Test" per SP 661.4,
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Revision 4, on May 18.
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Unit 2
--- " Boric Acid Pump ' A' Operational Readiness Test" per EN 21125, Revision 2, on May 19.
--- " Boric Acid Pump 'B' Operational Readiness Test" per EN 21126, Revision 2, on May 19.
--- " Charging Pump 'B' Operational Readiness Test" per EN21129, Revision 2, Change 3, on May 19.
--- " Charging Pump ' A' Operational Readiness Test" per EN21128, Revision 2, Change 3, on May 19.
"H.P.S.I. Pump 'C' Operational Readiness Test" per EN 21113
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Revision 1, Change 1, on May 19.
--- "C.E. A. Group Deviation Verification" per SP2620B, Revision 2, on May 21.
--- "C.E. A. Partial Movement" per SP2620A, Revision 4, on May 21.
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--- Environmental Monitoring of marine impingement on intake screens on June 8 and 11.
9.
Plant feintenance and Modifications During the inspection period, the inspector frequently observed various maintenance and problem investigation activities. The inspector reviewed these activities to verify:
compliance with regulatory requirements, including those stated in the Technical Specifications; compliance with the administrative and maintenance procedures; compliance with applicable codes and standards; required QA/QC involvement; proper use of safety tags; proper equipment alignment and use of junpers; personnel qualifica-tions; radiological controls for worker protection; fire protection; retest requirements; and, reportability as required by Technical Specifications.
In a similar manner the implementation of design changes and modifications were reviewed.
In addition to those items addressed above, the licensee's safety evaluation was reviewed.
Compliance with requirements to update procedures and drawings were verified and post modification acceptance testing was evaluated. The following activities were included in this review:
Unit 1
--- Cleaning and restoration of "1D" Emergency Service Water Pump, follcwing failure of inservice test pump and valve surveillance, on June 17-18.
Unit 2
--- Troubleshooting of "A" Diesel fire deluge system on June 9.
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Unit 2 (cont'd. )
Installation and testing of steam generator blowdown radioactive
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waste treatment system (coverage.throughout the inspection period).
(J.0. 282-487, PDCR 2-65-82.)
Modifications to Containment Atmosphere Particulate Radiation
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Monitor RM 8267A (PDCR 2-072-82).
10. Licensee Event Reports (LERs)
The inspector reviewed the following LERs to verify that the details of the event were clearly reported including the accuracy of the description of cause and adequacy of corrective action. The inspector determined whether further information was required, and whether generic implications were involved. The inspector also verified that the reporting requirements of Technical Specifications and Station Adninistrative and Operating Procedures had been met, that appropriate corrective action had been taken, that the event was reviewed by the Plant Operations Review Committee, and that the continued operation of the facility was conducted within the Technical Specification limits.
Unit 1 82-09 Setpoint drift: one of four Containment High Pressure switches.
82-10 Failure of Low Pressure Coolant Injection Subsystem "A" heat exchanger outlet valve to open due to mechanical binding.
82-11 Emergency Gas Turbine Generator inoperable due to A.C. oil pump failure and securing of the D.C. oil pump to conserve D.C. pcwer availability from batteries.
Unit 2 82-10 Service Water Header "A" removed from service to repair leak.
82-11 During reactor start-up, with reactor power at 8% rated thermal power, reactor coolant system temperature decreased below
0 515 F (to 514 F) while attempting to place the main turbine on line.
82-12 Erratic operation of Reactor Building Closed Cooling Water system temperature control valve during surveillance.
82-13 Electrical ground on motor operator for Boric Acid Emergency Suction to Charging Pumps valve 2-CH-514. This topic is discussed at length in inspection report 336/82-0.
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82-14 Personnel airlock outer door failed leak check following personnel entry into containment due to gasket seal damage.
82-15 Setpoint drift:
One of four Steam Generator Pressure Bypass removal bistables.
82-16 Decrease in fire-fighting water tank levels below minimum specification due to off-unit piping rupture.
Required levels were restored in less than one hour.
11. Review of Radioactive Material ' Shipments -(Units 1 & 2)
The inspector reviewed the activities concerning the shipment of radio-active waste to the Barnwell, S.C., burial site. Those activities included receipt inspections of the shipping cask and liner, solidification of material, radiation surveys and the completion of administrative and quality control requirements prior to shipment. These inspections concerned:
Dewatered Mixed Resins (472 curies) from Unit 2 on May 17,1982.
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Dewatered Resins (45 curies) from Unit 1 on June 9,1982.
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Dewatered Resins (13 curies) from Unit 1 on June 18, 1982.
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Exit Interview At periodic intervals during the course of the inspection, meetings were held with senior facility management to discuss the inspection scope and findings.
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