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| {{Adams | | {{Adams |
| | number = ML20151B498 | | | number = ML20235P335 |
| | issue date = 03/30/1988 | | | issue date = 02/16/1989 |
| | title = Insp Repts 50-338/88-01 & 50-339/88-01 on 880116-0223. Violations Noted.Major Areas Inspected:Plant Status, Unresolved Items,Licensee Action on Previous Enforcement Matters,Ler Followup & Review of Inspector Followup Items | | | title = Forwards Enforcement Conference Summary Re Insp Repts 50-338/88-01 & 50-339/88-31.Related Info Encl |
| | author name = Caldwell J, Cantrell F, King L | | | author name = Ernst M |
| | author affiliation = NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) | | | author affiliation = NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| | addressee name = | | | addressee name = Cartwright W |
| | addressee affiliation = | | | addressee affiliation = VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.) |
| | docket = 05000338, 05000339 | | | docket = 05000338, 05000339 |
| | license number = | | | license number = |
| | contact person = | | | contact person = |
| | document report number = 50-338-88-01, 50-338-88-1, 50-339-88-01, 50-339-88-1, NUDOCS 8804080259 | | | document report number = NUDOCS 8903020181 |
| | package number = ML20151B480
| | | document type = CORRESPONDENCE-LETTERS, NRC TO UTILITY, OUTGOING CORRESPONDENCE |
| | document type = INSPECTION REPORT, NRC-GENERATED, INSPECTION REPORT, UTILITY, TEXT-INSPECTION & AUDIT & I&E CIRCULARS | | | page count = 27 |
| | page count = 14 | |
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| A8 #80uf UNITED STATES
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| Do NUCLEAR REGULATORY COMMISSION
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| [\ c REGION il
| | FEB 161959 Virginia' Electric and Power Company ATTN: Mr. W. R. Cartwright, Vice President, Nuclear Operations 5000 Dominion Boulevard Glen Allen, VA 23060 , |
| $ g j 1o1 MARIETTA STREET. *' 2 ATLANTA, GEORGI A 30323
| | Gentlemen: |
| \+...+/
| | SUBJECT: ENFORCEMENT CONFERENCE SUMMARY NRC INSPECTION REPORT N05. 50-338,339/88-31 This letter refers to the Enforcement Conference held at our request on January 18, 198 This meeting concerned activities authorized for your North Anna facilit The issues discussed at this conference related to your corrective action on several control room habitability deficiencies identified during an NRC review. A list of attendees, a summary, and a copy of your handout are enclosed. We are continuing our review of these issues to deter-mine the appropriate enforcement actio In accordance with E.790 of the NRC's " Rules of Practice," Part 2, Title 10, Code of Federal Regulations, a copy of thit letter and its enclosures will be placed in the NRC Public Document Roo Should you have any questions concerning this matter, please contact u |
| Report Nos.: 50-338/88-01 and 50-339/88-01 Licensee: Virginia Electric and Power Company Richmond, VA 23261 Docket Nos.: 50-338 and 50-339 License Nos.: NPF-4 and NPF-7 Facility Name: North Anna 1 and 2 Inspection Conducted: January 16 - February 23, 1988 Inspectors: Y #ceI d eqt"Inspector A- Mf/
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| Date Signed J. t.7 Caldwell, wb Senior bi ig{e Y)f/f$
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| L. P M ing, Resident 171 'o r f Date Signed Approved by: ,n I 8k 3 3MF9_
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| F. 'Cfntrell, Section Utgy'V Da(e Si%ned Division of Reactor Projects SUMMARY Scope: This routine inspection by the resident inspectors involved the following areas: plant status, unresolved items, licensee action on previous enforcement matters, licensee event report (LER) followup, review of inspector follow-up items, monthly maintenance observation, monthly surveillance observation, ESF walkdown, and operator safety verificatio During the performance of this inspection, the resident inspcetors conducted reviews of the licensee's backshift operations on the following days - January 18, 24, 28, 29, 31, February 1, 2, 3, 5, 6, 9, 11, 12, 15 and 1 Results: One violation with two examples for failure to follow procedure and failure to have an adequate procedur PDR ADOCK0500g8
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| . . | | Sincerely, Original signed by J. Philip Stohr (for) |
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| | Malcolm L. Ernst Acting Regional Administrator l Enclosures: List of Attendees Meeting Summary |
| REPORT DETAILS Licensee Employees Contacted
| | ' Handouts ; |
| *E. W. Harrell, Station Manager
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| *R. C. Driscoll, Quality Control (QC) Manager
| | G. E. Kane, Station Manager R. F. Saunders, Manager - Nuclear Programs and Licensing Commonwealth of Virginia bcc w/encls: 1 A. F. Gibson ! |
| * E. Kane, Assistant Station Manager
| | G. R. Jenkins l NRC Resident inspector / |
| * L. Bowling, Assistant Station Manager J. A. Still, Superintendent, Operations M. R. Kansler, Superintendent, Maintenance
| | l DRS Technical Assistant . |
| *A. H. Stafford, Superintendent, Health Physics
| | Document Control Desk 3Gvw h R I I, Ril Ril Ril y (N k, U |
| * A. Heacock, Superintendent, Technical Services (Acting)
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| *J. L. Downs, Superintendent, Administrative Services J. R. Hayes, Operations Coordinator E. S. Hendrixson, Engineering Supervisor ( Acting)
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| D. E. Thomas, Mechanical Maintenance Supervisor G. D. Gordon, Electrical Supervisor L. N. Hartz, Instrument Supervisor F. T. Terminella, QA Superviror J. P. Smith, Superintendent, Engineering D. B. Roth, Nuclear Specialist J. H. Leberstein, Engineer
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| * G. Harkness, licensing Coordinator
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| *D. B. Roth, Nuclear Specialist
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| *T. R. Maddy, Superintendent, Security
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| * D. Miller, Licensing Coordinator (Surry) | |
| Other licensee employees contacted include technicians, operators, mechanics, security force members, and office personne * Attended exit interview NRC Regional Management Site Visit: B. Wilson and F. S. Cantrell conducted a visit of the North Anna Power Station on February 3, 198 . Exit Interview (30703)
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| The inspection scope and findings were summarized on February 23, 1988, with those persons indicated in paragraph 1 above. The licensee acknowledged the inspectors findings. The licensee did not identify as proprietary any of the material provided to or reviewed by the inspectors during this inspectio (0 pen) Violation 338/88-01-01: Failure to follow procedure and failure to have ar. adequate procedure resulting in a 1000 gallon leak from the RCS (see paragraph 8).
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| (0 pen) Inspection Follow-up Item 338,339/88-01-02: Disc separated from stem on RTD loop isolation valve __
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| | SShaeffer PFredrickson B ilson DCo ins eyes AGi on 02/. /89 02/p/89 ,> 02/g /89 ff/ 9 2/f d/89 42/ 89 RI T '{ |
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| (0 pen) Unresolved Item 339/88-01-01: Potential for failure to perform a post maintenance test (see paragraph 9). Plant Status Unit 1 Unit 1 began the inspection period in Mode 5, day 4, of an unscheduled 27-day outage. Unit 1 entered the outage due to resin being discovered in the secondary systems and the steam generators. On January 23, a 35 gpm '
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| leak developed on the "B" Reactor Coolant System (RCS) loop RTD bypass line. The unit was still in Mode 5 with the RCS level being maintained at approximately 10 inches above nozzle centerline. The cause of the leak was the performance of maintenance on the wrong flange in the RTD bypass line (see section 8 for details). 1he leak was identified and isolated without any affect on the unit or the operating Residual Heat Removal (RHR) punp. As a result, the station manager stopped all work inside ,
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| containment until the work in containment could be reviewed to ensure that personnel performing the work had conducted proper pre-job planning. Work in centainment was allowed to recommence on January 2 On February 2, a pressurizer Power Operated Relief Va?;u (PORV) lifted at its low pressure setpoint of 345 psig while starting the "A" Reactor Coolant Pump (RCP) (see section 11 for details). On February 8, day 27 of the resin intrusion outage, the licensee restarted Unit 1. The reactor ,
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| was taken critical at 0323 on February 8 and achieved 100% power on February 12. The unit is operating at approximately 100% power as of the end of the inspection perio ,
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| Unit 2 i
| | ENCLOSURE 1 l |
| I Unit 2 commenced the inspection period operating at approximately 100% i power. On February 12, the licensee voluntarily shutdown Unit 2 based on l
| | l ENFORCEMENT CONFERENCE ATTENDEES i |
| NRC concerns relating to the ASME Code Section XI compliance with several containment isolation valves (see Inspection Report 338, 339/88-02). The unit was in Mode 3 by 0135, the valves in question were tested and repaired as necessary to ensure compliance with ASME Code Section XI, and the unit was restarted on February 1 As of the end of the inspection '
| | Virginia Electric and Power Company W. Cartwright, Vice President-Nuclear Operations G. Kane, Station Manager R. Saunders, Nuclear Programs and Licensing Manager M. Bowling, Assistant Station Manager J. Hegner, Licensing Supervisor R. Boehling, Project Engineer Nuclear Regulatory Commission, Region II M. Ernst, Acting Regional Administrator, RII , |
| period, Unit 2 is operating at approximately 100% powe Both Units On January 21, 1988, the NRC conducted an enforcement conference with the
| | L. Reyes, Director, Division of Reactor Projects (DRP) ,. |
| | D. Collins, Acting Director, Division of Radiation Safety and Safeguards (DRSS),RII B. Wilson, Branch Chief, DRP F. Cantrell, Section Chief, DRP P. Fredrickson, Section Chief, DRP l G. Jenkins, Director, Enforcement and Investigation Coordination Staff - |
| | t J. Kahle, Section Chief, DRSS L. King, Resident inspector, DRP |
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| licensee i n the Region II Atlanta of fic The enforcement conference j involved a discussion on environmental qualification type violations (see i Inspection Report 338,339/87-32) and the violations cssociated with l
| | M. Lewis, Project Engineer, DRP l R. Marston, Reactor Inspector, DRSS B. Uryc, Senior Enforcement Coordinator S. Shaeffer, Project Engineer, DRP Nuclear Regulatory Commission, Headquarters L. Engle, Project Manager, Nuclear Reactor Regulation (NRR) |
| inoperable steam flow instruments discovered during the Unit 2 start-up on
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| November 4 (see Inspection Report 338,339/87-38).
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| l On January 26, Station Management conducted a meeting with all the station i j supervisors to discuss the significance of the recent problems and ,
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| | ENCLOSURE 2 ENFORCEMENT CONFERENCE SUMMARY An Enforcement Conference was held at the Region 11 Office with Virginia Electric and Power Company (VEPCO) on January 18, 1989, to discuss control room habitability issues at the North Anna Power Statio The Regional Administrator opened the meeting by expressing the NRC's concerns regarding control room habitability problems and corrective actions taken to dat The licensee's Vice President of Nuclear Operations then gave a brief discussion about the subject enforcement issues and their understanding of the NRC's concerns in this area. Also mentioned were some of the corrective actions taken to date. Subsequent discussions consisted of: general system design review, including Updated Final Safety Analysis Report (UFSAR) basis and Technical Specification (TS) 3.7.7.1 applicability; control room habitability chronology of events; cause of potential safety concerns; corrective action for both specific and root causes of potential safety concerns and their safety significanc VEPC0 recognized that potential problems exist with control room habitability due to the marginal design of the air supply systems. They further stated that the habitability systems were designed just to meet the criteria, and their intent is to correct any design deficiencies. During the discussions, the NRC expressed concerns about the timeliness of corrective actions. VEPC0 responded by commenting on the limited available physical space for modifications, the seismic design constraints, and the fact that both units were operating during the modification process. Also addressed in detail by both NRC and VEPC0 representatives was the operability of the Bottled Air Pressurization System with respect to control room pressure boundary inleakage. An inleakage rate of 10 CFM was used to estimate the effect of individual control room door openings which may be necessary during the first hour of an accident. Bottled air is used for the first hour's ventilation and then suction is switched to the turbine building for the next 31 days. The NRC questioned the inleakage rate and discussed the possibility of a bottled air test to provide an actual test of the control room's physical configuratio VEPC0 is considering performance of this tes VEPC0's position is that the makeup air from the i bottles is controlled by a pressure control valve and not by flow rate and with the 10 CFM inleakage estimate, the bottled air will maintain the control room at a positive pressure as required by TS 3.7.7.1. Discussions were also conducted relative to design deficiencies, questionable control of air dampers, and the failure to conduct surveillance in appropriate ways. |
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| | l One change was noted in the licensee's handout regarding completed corrective actions for potential safety concerns. Revised operating procedures for fuel handling reflects placing the emergency control room ventilation in service during fuel movement and not the control room ventilation as indicated in the presentation handou _ _ _ _ _ - . |
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| violations that had been identified in the last several month The meeting was conducted to ensure that station supervision was aware that problems have occurred, that they understood their significance, and finally that they understood the necessity to prevent their recurrenc <
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| The resident inspector attended the meetin . Unresolved Items
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| An Unresolved Item is a matter about which more information is required to 4 determine whether it is acceptable or may involve a violation or deviatio One unresolved item was identified during this inspection and is discussed in paragraph ,
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| 5. Licensee Action on Previous Enforcement Matters (92702)
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| (Closed) Violation 338/87-24-01: Failure to have a Safety Evaluation for i
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| Leaking Steam Generator Plugs and Foreign Objects. Maintenance procedures have been revised to include criteria for requiring a deviation report to
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| ; be submitted for any abnormal occurrenc Administrative Procedure includes a step in the list of review criteria to instruct the reviewer that a station deviation report be submitted when unexpected activities are encountered,
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| l Licensee Event Report (LER) Follow-Up (90712 & 92700) !
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| ' The following LERs were reviewed and closed. The inspector verified that | |
| ; reporting requirements had been met, that causes had been identified, that
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| corrective actions appeared appropriate, that generic applicability had l been considered, and that the LER forms were complete. Additionally, the i inspectors confirmed that no unreviewed safety questions were involved and t l that violations of regulations or Technical Specification (TS) conditions j
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| | Enclosure 2 2 i |
| | During the course of the meeting, VEPC0 made the following commitments: ; |
| | - Submit GDC 19 reanalysis for NRC review, which will include administrative control Add requirement for health physics survey of control room and place in procedure All engineering modifications are to be completed by the 1990 refueling outages with administrative controls in plac Analyze control room habitability for all modes of operation (other than those required by TS). |
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| (Closed) LER 338/87-17: Steam Generator Tube Rupture. Responses will be tracked under AIT report 338/87-24 dated August 28, 198 ,
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| 7. Review of Inspector Follow-up Items (92701)
| | Add auto-start for emergency fan in recirculation mode upon receipt of bottled air system actuatio Add auto-isolation of normal supply and exhaust on receipt of fuel ! |
| ! | | building high high radiation alar Correct inconsistency between design basis and actual design and operation by expanding current Design Basis Documentation Action Plan to include reconciliation with physical configuration and station document Reevaluate UFSAR assumptions for multiple control room envelope entrie Revise TS regarding interpretation of the 0.05 inch positive pressure requirements for control room envelope during the first hou ! |
| (Closed) IFI 338/87-24-08: Review Securing of LHSI Pump Early. The i licensee has received concurrence from Westinghouse that the pump was secured in the proper sequence as directed in the Emergency Response ;
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| Guidelines. The licensee has determined that overheating of the pumps on r recirculation is not a valid concern for North Ann Therefore, the !
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| I licensee has changed their Emergency Operating Procedure to secure the ! | |
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| , Monthly Maintenance (62703)
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| Station maintenance activities affecting safety related systems and ,
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| components were observed / reviewed, to ascertain that the activities were conducted in accordance with approved procedures, regulatory guides and !
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| industry codes or standards, and in conformance with Technical i Specification Unit 1 outage commenced on January 13 to flush and drain the steam
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| . ' generators due to resin intrusio "
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| The most significant work accomplished during the outage was:
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| 4 Replacement of "A" reactor coolant pump seal; i "C" main steam trip valve overhaul; I Motor changeout of "A" recirculation fan;
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| , Overhaul of 1-SI-P-1B (LP I pump B);
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| I Flush and fill of steam generators to remove resin fines, i
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| i The inspector made containment entries to observe work on items (a) and (c) above. No problems were identifie '
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| ! The Low Head Safety Injection Pump,1-SI-P-1B, was overhauled due to its [
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| ; marginal acceptance of the differential pressure criteria during previous !'
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| periodic test (See Inspection Report 338, 339/87-34)
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| ; Following the pump overhaul, the inspector observed the installation of i 1-SI-P-1B (Low Pressure Injection Pump) and reviewed the purchasing of the
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| spare parts that were replaced on 1-SI-P-18. It was determined from i discussion with the licensee's Engineering and Quality Assurance
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| Departments that several of the parts were purchased from another
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| facility as non-safety related. This included three shaft sleeves and "0"
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| : ring The inspector had a concern that these were purchased as l
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| non-safety related parts instead of safety related. The licensee had written a risk release document which was dispositioned by Engineering l saying that the non-safety related parts could be used until the next outage. The risk release document is a licensee internal docurnent which allows parts which do not meet all of the requirements to be released for installation pending further engineering review. This review must be l completed before the piece of equb.aent for which the parts were t; sed is
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| The licensee has written a Technical Report No. ME 0011, Rev. 1, which
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| accepts the journal sleeves as meeting the three criterial for commercial l
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| grade as described in 10 CFR 21. The licensee then dedicated these sleeves for use as a base component in the LdSI pump based on the dimensional requirements being verified by recefst inspection and receipt of a letter from the pump vendor stating that the material is the some for commercial
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| as for nuclear grad The licensee's intention, based on a letter from the vendor verifying the parts as acceptable and Revision 1 of Technical Report ME-0?ll, is not to replace the journal sleeves, but to accept them as is. This process was discussed with the NRC staff in Region 11 and determine ' to be acceptabl On Jant 23, with Unit 1 in Mode 5 and vessel level being maintained at approximately 10 inches above nozzle centerline, the operator noticed an increasing reactor sump level. The vessel level which was being monitored by a standpipe located in the containment with a television monitor in the control room also indicated a decreasing leve The operators secured letdown, increased makeup to the vessel and entered 1-AP-16, Excessive Primary Leakage. Shortly af ter discovering the loss of water from the primary, the operators were contacted by mechanics in the containment and informed of a leak from a loop B RTD bypass line flange which the mechanics could not isolate. The operators maintained vessel level well above that necessary to provide Net Positive Suction Head (NPSH) to the operating RHR pump, continued to monitor the operation of the RHR pump and dispatched four operators into the containment to isolate the lea The leak was isolated approximately 30 minutes after discovery by an operator shutting one of the RTD bypass line isolation valves (1-RC-59)
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| inside containment. The leak was determined to be approximately 35 gpm and a little over a 1000 gallons had leaked into the containment sum The Health Physics (HP) Staff conducted sampling activities and determined that an airborne condition did not occur and that there was no indication of any radioactive releas Following the leak isolation, the operators vented the operating RHR pump and determined that no air or gases had entered the pump. Also the Shift Supervisor had entered containment and determined that the standpipe level scale (ruler) had been installed approximately six inches above where it should have been, therefore, actual vessel level was being maintained at approximately 16 inches instead of 10 inches above nozzle centerlin Based on the above and the fact that the elevation of the flange which caused the leak was actually above the top of the nozzle there did not exist a potential for a loss of all RH The inspector reviewed the licensee's procedures for installation of the standpipe and the level scale (ruler). The instructions for installation of the standpipe were contained in 1-0P-5.4, Draining the Reactor Coolant System, which stated, "Request the planning dept, to generate repetitive work orders to remove blank flanges and install the desired spool pieces and level hose." There were no other instructions for installation with the exception of a signoff in 1-0P-5.4 for the level hose installed between 1-RC-104 and pressurizer vacuum breaker te The inspector determined, based on discussion with the operators, that the ruler is installed by the operators without any procedure. The standpipe, a tygon hose, is connected to valve 1-RC-104 which penetrates the Reactor Coolant System (RCS) at an elevation approximately nozzle centerlin Conse-quently, the operators locate the ruler next to the tygon hose so that the bottom of the ruler is located approximately the same elevation as the
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| ?. t valve's,1-RC-104, penetration into the loop. Since there is no formal method or procedure to install the standpipe and level scale, then there are no checks, signoffs or second verification to ensure that the standpipe and level scale is installed properly. The failure to have an !
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| adequate procedure to ensure proper installation of the RCS level i standpipe and reference level scale will be identified as the first ;
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| example of Violation (338/88-01-01). ,
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| The licensee determined the cause of the leak to be the failure of the
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| mechanics to perform maintenance on the right flange inside containmen The mechanics were requested to repair a leak on flow element flange 1-RC-FE-1491 per work order 5900070293. The mechanics were to perform 4 their repair per Mechanical Maintenance Procedure, K9-C-P-4, Oisassembling, Inspection, Repairing, Reassembling Safety-Related Piping System Bolted Flanges in General.
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| There were two flanges located in the same general area on the loop B RTO bypass line, one to the flow element 1-RC-FE-1491 which was the flange that was supposed to be worked and the other to flow ori fice 1-RC-R0-1.
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| ; Both flanges had their lagging removed, neither had identification tags i installed and the wrong flange 1-RC-RD-1 was the only one with boric acid
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| ! on it because the other flange had been cleaned in preptration for wor Consequently, the mechanics choose the flange to wrrk, liased on the boric acid buildup and the fact that they found several loose bolts, instead of leaving the containment to make sure which was the right flange. The licensee also determined that the locatior of the item to be worked or whether it would be identified was not discussed during the mechanics a pre-work briefin The inspector questioned why maintenance on a loop RTD bypass line flange 1 had not had isolation set prior to the start of wor The licensee
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| informed the inspector that isolation had been considered but based on the
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| elevation of the flange and the fact that vessel water level was being maintained well below that elevation, the Shift Supervisor considered j isolation unnecessary. The inspector is aware of a desire on the part of j the licensee not to use the RTO bypass line isolation valves because most j of them have had their discs separated from the valve ste This
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| keep the loop RTD's operable. Consequently closing these valves may
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| : prevent them from being reopened by the RTO bypass line flow which would result ia inoperable RTO loop protection signals. During the restart
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| following the outage sufficient flow was developed in the "B" loop RTO 4 bypass line indicating that the valves did unseat and continued operation with these valves was considered acceptabl Based on the continued acceptable RTD bypass ficw through these valves and the high dose that would be encountered during their repair or replacement, t% licensee has elected not to perform permanent repairs at this time. However, the licensee informed the inspectors that they intend to make oermanent repairs in the future and are still in the process of determining the best
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| ; rae thod . The inspector reviewed the licensee justification for operation i
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| with inoperable valves, and requested regional review of this proble This is identified as laspection followup item (338,339/88-01-02).
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| i The failure of the licensee to properly isolate and perform work on the correct comoonent per Maintenance Work Order 5900070293 and MMP-C-P-4 resulting in approximately a 1000 gallon leak from the. RCS constitut's a | | l C e r a |
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| failure to follow procedur This failure to follow procedure will .e identified as the second example of Violation (338/88-01-01).
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| As a result of the event, the Station Manager stopped all work inside containment until the event could be fully evaluated and until all othar work could be reviewed to ensure that proper pre-job planning had been performed. Work was allowed to recommence on January 24. It should also be noted that this event occurred just prior to the scheduled licensee management meetings with all station personnel to discuss the importance of attention to detail and proper adherence to procedure This particular event was used as one of the examples of the problems that had occurred stressing the importance of following procedures. The meetings i commenced on January 26, two days after the flange leak inciden l All three steam generators were flushed and drained to remove any
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| : intrusion of powdex resins. The feedwater and condensate lines were also i flushed and sampled. An inspection of the condensate polishers indicated that several internal candles had come loose at the bottom allowing resin
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| fines to escape. The licensee has had a manufacturer's representative in
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| to look at the proble Procedures and tests are being developed to i prevent recurrence. The licensee is writing a voluntary LE '
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| The "C" Main Steam Trip Valve (MSTV),1-MS-TV-101C, was investigated to determine possible problems due to unusual nois After the
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| ! investigation, wMch was inconclusive, the valve failed to pass the
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| , periodic test procedure 1-PT-212.9 for valve strok The closing time t took greater than six seconds on several attempts to perform 1-PT-212 9.
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| l This is greater than the maximum five seconds allowed by Technicil l Specifications requiring the valve to remain inoperabl , | | y e u t n c c a n y y g p u a e e u l |
| ; The inspector reviewed work request 530643 to overhaul the C MST The
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| ! licensee replaced the springs in both actuators for the valve and the
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| , valve still faile An engineering work request was written which i increased the size of the bleed-off line from the actuators from a
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| ! one-half inch line to a one inch line and an additional solenoid valve was installed (via an approved modification). Retest of the valves then ;
| | . |
| j indicated a 3.9 second closure which was acceptabl l
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| I The inspector reviewed work request 371640 and observed the work on main
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| steam non-return valve (1-NRV-102C) on Unit 1 steam generator "C" outle *
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| l The non-safety related valve had been previously Furmanited to stop a leak i and the Furmanite was being removed to allow repacking the valve for the l l permanent repai '
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| The inspector also observed replugging of leaky tubes on the first stage feedwater heater 2-FW-E-1A for Unit 2.
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| f The inspector reviewed and observed work being performed per work request 238703 on Unit 2 auxiliary turbine driven feedpum The pump was being repacked, the oil was drained and replaced, and a leaky lube oil cooler was removed, plugged and reinstalled. The inspector observed the surveillance test performed after the work had completed (see Surveillance Section for 2-PT-71.1). .
| | r me otd o ea nn R Cy l l 1 ot rp r op 3- t npu 8 ops 8 Cuf e So t |
| ' Monthly Surveillanco (61726)
| | r hl ano t |
| The inspectors observed / reviewed technical specification required testing and verified that testing was performed in accordance with adequate
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| ; procedures, that test instrumentation was calibrated, that limiting 4 conditions for operation (l.CO) were met and that any deficiencies
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| identified were properly reviewed and resolved, s The inspector observed the following surveillances: ; PT-71.1, Test of Auxiliary Turbine Driven Feedpum The test
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| . failed due to a high differential pressure which caused the relief
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| ! valve to open. The governor was readjusted and the pump was retested ,
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| satisfactoril During the course of the test, the motor driven l auxiliary feedpump room filled with steam. The licensee traced the i problem to the drain lines from the turbine driven feedpump to the motor driven feedpump room being crosstied and isolated by a foot i i valve which stuck open. This allowed drains from the turbine driven auxiliary feedpump to back up into the motor driven pump room. The licensee worked on the foot valve and the volume of steam was
| | ae eret ip pA e ne r |
| ! reduced. The licensee stated the amount of steam still leaking was ,
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| l insignificant and would be removed by the exhaust syste ,
| | n sn r en ti t u gd b r eI ads t |
| j On February 3,1988, the inspector observed Periodic Test 1-PT-212.4 4 to determine closing time of 1-MOV-FW-154C, the main feedwater isolation valve for "C" steam generator. This valve failed the
| | oC f waeTe r e t |
| : periodic test by closing in excess of the required maximum of five i seconds, A deviation report anc work request was submitted to Engineering who dispositioned them, stating under 6.5 seconds was
| | r ih |
| : acceptable 'or the safety analysis (FSAR allowed closure time is 9 i j seconds).
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| l On February 3, 1988, at 1817, the Unit I reactor coolant pump "C" was 1 secured to stroke 1-TV-CC-102A and 1-TV-CC-100C using periodic test l 1-PT-212-1. No prcblems were identified. | | t s ew s w i i |
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| i ( On February 11, 1988, as a resu; of a concern by an NRC Quality l | | n i |
| Assurance Audit Team, the lict : sue decided to stroke 2-TV-CC-203 A
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| ; and B, which are the componen cooling water from the residual heat l removal and excess letdown heat exchanger (see Inspection Report 338, ;
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| l 339/88-02).
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| The resident inspector entered the Unit 2 outside penetration area with a licensee engineer to witness the stroking of the valves using Periodic Test 2-PT-212.1, When the stroke test was performed on 203A, the valve closed limit switch light never actuated in the control roo It was observed by the inspector that the valve started to close approximately 30 seconds after the solenoid was deenergized and the valve rotated 90 degrees to the close positio A retest of the valve using a stopwatch in the penetration area indicated the valve closad in 4 second Valve 203 B was also tested and closed in 62.5 secord This was above the required 60 seconds in Technical Specification 3.6- The licensee engineer and inspector noted that one-fourth inch piping was :nstalled on the outlet port of the solenoid The inspector questioned if a modification had been made and was inf' med that the valves were modified during the Unit 2 outage. The ir.spector asked the licensee to retest the valves without the tubing and research the stroke times before and after the modification chang The research showed the times had changed significantly af ter the modificatio The licensee wrote an engineering work request and removed the tubing and the valves retested at 16.5 and 24.4 seconds, respectivel The inspector obtained copies of engineering work requests 86-498 A, B, and C, which installed the tubing on the discharge of the solenoid valves. It was determined that "ASC0" recommended to the licensee that the exhaust port of their catalog NP-1 valves should be fitted with downward pointing street elbows to prevent moisture from entering the internal areas of the valve. It stated that moisture entering the internal areas of the valve could cause degradation of internal parts, galling of piston, scale buildup and mechanical failure of the valv In addition, QDR 35.1 and ASCO qualification reports AQR-67368 and 21678 require the solenoid operated valves be ven'ad and arranged such that chemical spray will not enter the system through any vent openin A review of the licensee Engineering Work Request that installed the modifications revealed that the licensee allowed the use of tubing to fitting adapters as well as street elbows to be installed. The tubing restricted the air flow causing the valves to close more slowly. A further review iiMicated that Administrative Procedure 3.8, Attachment 1 (Design Procedure Input Checklist) indicated on page 3 that test requirements inu'uding in plant tests was marked not applicable for all three engineerins work requests 86-498 A, B and The inspector was concerned that modifications had been made to the valves without testing. The Technical Specification requires the valves to be operable in Mode 1 thru 4.
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| The inspector was informed that some of the valves were tested by Operations during performance of routine periodic test before entering Mode 4 and even though the valves passed, some of the stroke times had increased. The licensee did not identify at that time that the stroke times had increased due to the modification. The licensee is investigating to determine if any modifications were made after leaving Mode 5. Any modifications made af ter leaving Mode 5 would require post modification testing prior to the valve being declared unoperabl This will be identified as Unresolved Item (URI)
| | nc t e |
| 339/88-01-01, pending inspector review to determine if the modifications were installed after leaving Mode 5 and if post maintenance testing was performed, On January 29, the inspectors witnessed Special Test 1-ST-77 which performed a retest on the LHSI pump 1B following its overhaul (see Maintenance, Section 8). The test first placed the LHSI pump in the recirculation mode and completed 1-PT-57.1B, ECCS Subsystem Low Head SI Pump (1-SI-P-1B) satisfactorily. Then with the unit in Mode 5, the pressurizer level at 10% and the pressurizer PORVs blocked open, the licensee opened the LHSI pump discharge valve to perform a full flow test of the pump which was not requireo by regulation Shortly after the discharge valve was opened, and flow and pressure data were taken, the LHSI pump was secured to prevent filling the pressurizer solid (approximate 40 second run time).
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| Based on full flow data and associated discharge pressure data taken, the pump was determined to be operating well above the design operating curve. The licensee determined that the flow reading was correct, based on a comparison with the change in pressurizer level, and in line with the expected flow rate for those condition However, the discharge pressure was too hig The licensee determined, based on a calculation of the horse power needed to develop the recorded discharge pressure and flow rate, that the pump had an efficiency greater than one, which is impossible. Since the flow rate had been determined to be accurate, the licensee concluded that the discharge pressure data at full flow was not correct. Using the data recorded from the recirculation phase of the pump operation, both at full recirculation, approximately shutoff head and full flow, the licensee was able to calculate, based on some conservative assumptions, a best estimate of the discharge head of the pump at full flow This discharge head and flow data point was just below the design head curve but above the curve used for the basis for Emergency Core Cooling System (ECCS) performance. After discussion with the vendor, a review of the vibration data which was very low, achieving a satisf actory flow rate, the satisfactory performance of the Technical Specification required surveillance, and an engineering review of the calculational bisis for the estimate of the pump head at full flow conditions, the licensee declared the LHSI pump 1B fully operational. The licensee has been unable to determine the cause of the incorrect discharge pressure readin _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
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| | is e o vb n e s v m o F e a C i i t t r a o cnr i s o of b e |
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| 11 On January 29, the inspectors witnessed the stroke time testing of MOV 18900, a LHSI pump discharge valve. The test which was conducted per 1-PT-213.8, Valve Inservice Inspection (Safety Injection System)
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| was performed satisfactoril No violations or deviations were identifie . ESF System Walkdown (71710)
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| The following selected ESF systems were verified operable by performing a walkdown of the accessible and essential portions of the systems on February 16, 198 The inspectors walked down the valve alignment of the Unit 1 Low Head Safety Injection System using valve checkoff list 1-0P-7.1 The manual valves inside containment and the valves in the safeguard valve pit area were not checked. No problems were identifie The inspectors informed the licensee of the following observations: The valve area had various tools and trash laying around; Staging was installed in the Low Head Safety Injection (LHSI) pump cubicles; Valves 1-SI-217 and 1-SI-314 need caps installed; Valve 1-SI-307 (Recirculation Line Vent) had boron residue on the pipe cap and packing gland indicating a lea The licensee has removed the tools, trash, and staging from the LHSI are The inspectors also requested that the licensee perform safety evaluations in the future prior to installing any equipment such as staging around safety related equipment. The licensee has committed to performing these safety evaluation No violations or deviations were identifie . Operational Safety Verification (71707)
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| By observations during the inspection period, the inspectors verified that the control room manning requirements were being met. In addition, the inspectors observed shif t turnover to verify that continuity of system status was maintained. The inspectors periodically questioned shift personnel relative to their awareness of plant condition Through log review and plant tours, the inspectors verified compliance with selected Technical Specification (IS) and Limiting Conditions for Operation _ _ _ _ - _ _ - _ - _ _ _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
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| In the course of the monthly activities, the resident inspectors included
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| {' a review of the licensee's physical security program. The performance of
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| various shifts of the security force was observed in the conduct of daily activities to include: protected and vital' areas access controls, searching of personnel, packages and vehicles, badge issuance. and retrieval, escorting of visitors, patrols and compensatory post In addition, the resident inspectors observed protected area lighting, protected and vital areas barrier integrity and verified an interface 2 between the security organization and operations or maintenanc On a regular basis, Radiation Work Permits (RWP) were reviewed and the specific work activity was monitored to assure the activities were being
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| 3 conducted per the RWP The inspectors kept informed, on a daily basis, of overall status of both units and of any significant safety matter related to plant operation Discussions were held with plant management and various members of the operations staff on a regular basis. Selected portions of operating logs and data sheets were reviewed dail The inspectors conducted various plant tours and made frequent visits to the control room. Observations included: witnessing work activities in progress; verifying the status of operating and standby safety systems and equipment; and confirming valve positions, instrument and recorder readings, annuciator alarms, and housekeeping. | | 1 cC e 0 i o |
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| The following comments were noted:
| | _ y |
| On February 2, with Unit 1 in Mode 5 preparing to return to power operation, a Power Operated Relief Valve (PORV) lifted at it's low
| | _ |
| . pressure setpoin The Unit was solid with pressure approximately 320 psig and the "B" Reactor Coolant Pump (RCP) operating just prior to the event. The licensee had just started the "A" RCP and the operators
| | t |
| .j were increasing pressure to maintain the necessary differential pressure j across the number one seal on the "A" RCP. By the pressure indication 1 available to the operator in the control room, primary pressure appeared
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| ! to be stable around 335 psig. However the PORV lifted at its setpoint of
| | i |
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| secure Initial NRC review of the events surrounding this value lifting i indicated no operational problems.
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| ! These corrective actions will be detailed in the LER 88-008 to be issued l by the licensee before March 2. The inspector will review and follow up 1 on these corrective actions during the associated LER review and close
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| On February 12, the licensee voluntarily shut Unit 2 down in response to questior.s raised by the NRC concerning compliance with ASME Code Section XI on certain containment isolation valves (see Inspection Report 338, 339/88-02 for details). These containment isolation valves were associated with component cooling water to the RCPs and should not be stroke tested with the RCPs running. Consequently, the licensee shut the unit dcwn to allow securing of the RCPs for stroke testing and repairs as necessary of the component cooling water containment isolation valve The inspectors witnessed the testing of several of the valves per 1-PT-212.1, Valve Inservice Inspection (Component Cooling System). All of the valves were tested satisf actorily with the exception of TV-CC-201B which closed in 62.4 second The Technical Specification (TS) require-ment for this valve is less than 60 seconds and the results from the last satisfactory test performed on October 25, 1987, indicated the valve closed in 6.6 second The valve was declared inoperable and the appropriate TS action statement was entere The licensee removed, overhauled and reinstalled the solenoid valves associated with TV-CC-201B and all other valves that had previously failed or were in the alert conditio The overhaul and inspection of the solenoid valve TV-SOV-CC-201B did not reveal any proolems which would have caused the solenoid to stic The licensee completed retests of the component cooling water containment isolation valves prior to the unit restart. All the valves were tested satisfactorily and TV-CC-201B closed in approximately 6.2 seconds. Unit 2 was restarted on February 14 and placed back on line on February 15, 198 No violations or deviations were identified.
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Category:CORRESPONDENCE-LETTERS
MONTHYEARML20217K4391999-10-18018 October 1999 Provides Response to RAI to Support USI A-46 Program Submittal for North Anna Power Station,Units 1 & 2.Rev 10 to BNL Rept 52361,encl ML20217H3301999-10-14014 October 1999 Forwards Rev 0 to COLR for North Anna 2 Cycle 14 Pattern Su. No New Commitments Intended by Ltr ML18152B3541999-10-12012 October 1999 Requests Use of Code Case N-532 & N-619,per Provisions of 10CFR50.55a(a)(3).Detailed Info Supporting Request,Encl. Attachment 2 Includes Technical White Paper That Provides Further Technical Info ML20216K1681999-10-0101 October 1999 Forwards Vols I-VIII of Rev 35 to UFSAR for Naps.Rev Also Includes Update to Chapter 17 of Ufsar,Which Contains Operational QA Program.Changes to Program Description Do Not Reduce Commitments Contained Therein ML20212J9101999-10-0101 October 1999 Forwards SE Accepting Licensee 990916 & 27 Relief Requests IWE-3 for Plant.Se Addresses Only IWE-3 Due to Util Urgent Need for Relief.Requests IWE-7 & IWE-8 Will Be Addressed at Later Date ML18152B3391999-09-27027 September 1999 Forwards Revised Relief Request IWE-3,which Now Includes Addl Visual Exam Requirement After post-repair or Mod Pressure Testing Is Completed,Per Telcon with NRC ML20212G5091999-09-22022 September 1999 Forwards in Triplicate,Applications for Renewal of Licenses for Listed Individuals.Encls Withheld,Per 10CFR2.790(a)(6) ML18152B6671999-09-17017 September 1999 Forwards Two NRC Forms 536,containing Info on Proposed Site Specific Operator Licensing Exam Schedules & Estimated Number of Applicants Planning to Take Exams And/Or Gfes,In Response to NRC Administrative Ltr 99-03 ML18152B3331999-09-17017 September 1999 Forwards Revised 180-day Response to NRC GL 96-05, Periodic Verification of Design-Basis Capability of Safety-Related Motor-Operated Valves. ML18152B3341999-09-16016 September 1999 Requests Relief from Specific Requirements of Subsection IWE of 1992 Edition with 1992 Addenda of ASME Section XI Re Containment Liner Examination Requirements,For North Anna & Surry Power Stations ML20211N2531999-09-0808 September 1999 Responds to Request to Exceed 60,000 Mwd/Mtu Lead Rod Burnup in Small Number of Fuel Rods in North Anna Unit 2.Informs That NRC Offers No Objection to Requested Use of Rods in Reconstituted Fuel Assembly.Se Supporting Request Encl ML18152B4471999-09-0101 September 1999 Requests That NRC Remove Listed Labels from Distribution ML20211L9151999-09-0101 September 1999 Forwards Response to NRC Request for Comments Re Closure of Review of Response to GL 92-01,Rev 1,Suppl 1, Reactor Vessel Structural Integrity ML20211J2211999-08-31031 August 1999 Approves Request to Remove Augmented ISI (Aii) Program for RCS Bypass Lines from North Anna Licensing Basis.Se Re Request to Apply LBB to Eliminate Augmented Insp Program on RCS Bypass Lines Encl ML20211H4131999-08-27027 August 1999 Informs That Util Revised Encl Bases for TS 2.2.1, Reactor Trip Sys Instrumentation Setpoints, Discussing Steam Flow/ Feed Flow Mismatch Portion of Steam Flow/Feed Flow Mismatch & Low SG Water Level Reactor Trip Setpoint ML20138B3241999-08-23023 August 1999 Forwards Draft Response to Question 1 Re NAPS USI A-46 ML20211D9041999-08-20020 August 1999 Forwards Revised Pages to Third Ten Year ISI Program & Relief Requests, Replacing Pages in 990408 Submittal ML20211B3871999-08-17017 August 1999 Requests Permission to Routinely Discharge from SW Reservior to Waste Heat Treatment Facility Under Existing Vpdes Permit Through Outfalls 108 & 103.Discharges Are Scheduled to Commence on 990907,due to High Priority Placed on Project ML20210T0671999-08-13013 August 1999 Informs of Completion of Review of Proposed Revs of Schedule for Withdrawal of Rv Surveillance Capsules Submitted by VEPCO on 981217.Approves Proposed Revs.Forwards Safety Evaluation ML20210Q9841999-08-12012 August 1999 Forwards Rev 1 to Vepc COLR for North Anna Unit 2,Cycle 13 Pattern Ud, Per TS 6.9.1.7.d.COLR Was Revised to Include Temp Coastdown Operation at End of Cycle 13 ML18152B4081999-08-0606 August 1999 Forwards Response to NRC 990520 & 0525 RAIs Re North Anna & Surry Responses to GL 95-07, Pressure Locking & Thermal Binding of SR Power-Operated Gate Valves. ML20210Q7661999-08-0606 August 1999 Requests Exception to 10CFR50.4 Requirement to Provide Total of Twelve Paper Copies When Submitting Surry & North Anna UFSAR Updates.Seek Approval to Submit Only Signed Original & One CD-ROM Version,Per Conversation with J Skoczlas ML18152B4091999-08-0505 August 1999 Forwards Vepc semi-annual fitness-for-duty Program Performance Data Rept for 990101-990630,IAW 10CFR26.71(d) ML20210N2921999-08-0505 August 1999 Discusses Which Submitted Proposed TSs Bases Change for Containment Leakage. Licensee Changes to Bases May Be Subj to Future Insps or Audits ML20210J8861999-08-0202 August 1999 Provides Clarification to Commitment Made in Identifying Extent by Which Existing Plant Design Complied with RG 1.97,specifically Re Variable, Radiation Exposure Rate ML20210F6121999-07-28028 July 1999 Forwards Supplemental Info on Proposed Irradiation of Fuel Rods Beyond Current Lead Rod Burnup Limit,Documenting Info Provided During 990624 Meeting & Suppl Original Submittal ML18152B3971999-07-26026 July 1999 Provides Estimates of Licensing Actions Expected to Be Submitted in Fys 2000 & 2001,in Response to NRC AL 99-02 ML20209E7621999-07-0909 July 1999 Provides Addl Info to Justify Use of Less than One Gpm Detectable Leakage Rate to Establish Required Margin for Crack Stability in LBB Analysis,Per 980623 Application on Reactor Coolant Loop Bypass Lines 05000338/LER-1999-005, Forwards LER 99-005-00,IAW 10CFR50.73.Commitment Made by Util Encl1999-07-0808 July 1999 Forwards LER 99-005-00,IAW 10CFR50.73.Commitment Made by Util Encl ML20209E3711999-07-0202 July 1999 Forwards Insp Repts 50-338/99-03 & 50-339/99-03 on 990425-0605.Violations Being Treated as Noncited Violations ML18152B4401999-07-0101 July 1999 Informs NRC That on 990511,Dominion Resources,Inc,Executed Amended & Restated Agreement & Plan of Merger with Consolidated Natural Gas Co ML18152B4371999-06-24024 June 1999 Forwards Response to NRC Request for Clarification of Relief Requests Submitted on 990212,requesting Relief from Performing Hydrostatic Testing for Certain Small Diameter Class 1,RCS Pressure Boundary Connections ML20196G2581999-06-23023 June 1999 Discusses Closure of GL 92-01,rev 1,suppl 1,reactor Vessel Structural Integrity ML20212J2951999-06-22022 June 1999 Forwards Corrected Markup & Typed Version of Affected Pages. Requests That Attached Pages for Those Previously Provided in 990506 Submittal Be Replaced & Incorporated Into NRC Review of Proposed TS ML18152B4361999-06-22022 June 1999 Forwards Response to RAI Re Surry & North Anna Power Stations,Units 1 & 2,per GL 96-06 ML20196F1151999-06-22022 June 1999 Forwards Relief Requests NDE-047 & NDE-048 for North Anna Power Station,Unit 1 Re ASME Section XI ISI Program ML20196G2211999-06-21021 June 1999 Forwards Licensee Sampling & Testing Obligations Re Vpdes Permit VA0052451 Reissuance Application.Details of Requests for Sampling & Testing Waivers,Included ML20195J7011999-06-15015 June 1999 Forwards Revised EPIP 2.01 Which Corrects Typo That Was Found in Step 10 of Procedure.Rev Does Not Implement Actions That Decrease Effectiveness of EP ML20195J1391999-06-11011 June 1999 Submits Addl Info as Addendum to Original Application Which Proposed Use of Three Chemicals in Bearing Cooling Tower at North Anna Power Station,Per Reissuance of Vpdes Permit ML18152B4301999-06-0303 June 1999 Informs of Util Intention to Revise Schedule for Submittal of License Renewal Applications for Surry & North Anna Power Stations to March 2002 ML20195C6601999-06-0101 June 1999 Forwards Response to NRC 990216 RAI Re Summary Rept of USI A-46 Program ML20207C9851999-05-28028 May 1999 Requests Regrading of Rt Robinson 990408 Written Exam,Based on Listed Reasons.Answer C for Question 18 Is Requested to Be Reconsidered as Correct or Question Be Deleted ML18152B4261999-05-28028 May 1999 Provides Formal Notification of Effect of Recent Organizational Restructuring on OLs of North Anna & Surry Power Stations,Per NRC 990513 Telcon Request ML18152B4221999-05-27027 May 1999 Forwards Info Concerning Changes to ECCS Evaluation Models & Application in Existing Licensing Analyses for Surry & North Anna Power Stations,Units 1 & 2 ML18152B4231999-05-26026 May 1999 Informs That Vepc Will Revise 180 Day Response to NRC GL 96-05,within 120 Days of Date of Ltr to Incorporate Commitment to Participate in Joint Owners Group Program as Applicable ML20206U7441999-05-20020 May 1999 Informs That NRC Unable to Conclude That NAPS Has Met Intent of Supplement 4 to GL 88-20.RAI Re Fire Area of IPEEE Encl. Response Requested within 90 Days of Submittal Date ML20207A8541999-05-20020 May 1999 Forwards RAI Re Licensee Listed Responses to GL 95-07, Pressure Locking & Thermal Binding of Safety-Related Power-Operated Gate Valves. Response Requested within 90 Days of Submittal Date ML20195B5381999-05-14014 May 1999 Forwards Rev 8,Change 2 to North Anna Units 1 & 2 IST Programs for Pumps & Valves. Summaries of Program Changes Provided for Each Unit IST Program.Relief Requests Have Been Removed from IST Programs ML18152A3701999-05-13013 May 1999 Submits Proposal to Use Provisions of ASME Section XI Code Case N-597 for Analytical Evaluation of Class 1,2 & 3 Carbon & Low Alloy Steel Piping Components Subjected to Wall Thinning as Result of Flow Accelerated or Other Corrosion ML20206L4661999-05-10010 May 1999 Forwards SE Accepting Request to Delay Submitting Plant, Unit 1 Class Piping ISI Program for Third Insp Interval Until 010430,to Permit Development of Risk Informed ISI Program for Class 1 Piping 1999-09-08
[Table view] Category:NRC TO UTILITY
MONTHYEARML20062D7631990-11-0606 November 1990 Forwards FEMA Re Plant Emergency Exercises on 900808.Two Deficiences in Offsite Performance Noted ML20058H0211990-10-29029 October 1990 Forwards Insp Repts 50-338/90-26 & 50-339/90-26 on 900908-24 & 1009-12.No Violations or Deviations Noted ML20058D7431990-10-26026 October 1990 Grants 901004 Request for Waiver from Tech Spec 6.9.1.7 Re Submittal of Core Surveillance Rept ML20058D7291990-10-25025 October 1990 Ack Receipt of Re Violations Noted in Insp Repts 50-338/90-18 & 50-339/90-18 ML20058B4151990-10-24024 October 1990 Ack Receipt of 880808 & 900613 Responses to NRC Bulletin 88-004 Re Potential safety-related Pump Loss ML20058E5771990-10-23023 October 1990 Forwards Requalification Exam Rept 50-338/OL-90-01 for Units 1 & 2 Administered During Wks of 900820 & 27 ML20058E9271990-10-23023 October 1990 Forwards SALP Repts 50-338/90-22 & 50-339/90-22 for June 1989 - Aug 1990 ML20062C4311990-10-18018 October 1990 Forwards SE & TER Concluding That Util Actions Do Not Conform to Requirements of Station Blackout Rule.Plant Emergency Diesel Generators Do Not Have Excess Capacity Available to Qualify Generators as Aac Source ML20062B2531990-10-12012 October 1990 Requests That Analyses of Liquid Samples Spiked W/ Radionuclides Be Completed as Soon as Practicable,But No Later than 60 Days from Receipt of Samples.Results Should Be Sent to DM Collins at Listed Address ML20062B6471990-10-11011 October 1990 Advises That Rev 15 to Guard Training & Qualification Plan Consistent w/10CFR50.54(p) & Acceptable ML20058B4241990-10-10010 October 1990 Confirms Region II Insp of fitness-for-duty Program on 901023-25.Tentative Itinerary Encl ML20058B3871990-10-10010 October 1990 Forwards Details Re Allegation Rept Rii 90-A-0152,per 901001 Telcon.Encl Withheld (Ref 10CFR2.790) ML20058A8481990-10-0909 October 1990 Forwards Insp Repts 50-338/90-23 & 50-339/90-23 on 900819- 0915.Violation Noted But Not Cited ML20059N1011990-09-19019 September 1990 Forwards Insp Repts 50-338/90-19 & 50-339/90-19 on 900820-24.Violations Noted But Not Cited ML20059K7941990-09-11011 September 1990 Forwards Insp Repts 50-338/90-18 & 50-339/90-18 on 900708- 0818 & Notice of Violation ML20059K7301990-09-0707 September 1990 Ack Receipt of in Response to Violations Noted in Insp Repts 50-338/90-11 & 50-399/90-11.Expresses Appreciation Re Issues Concerning EOPs & Abnormal Procedures ML20059K6811990-09-0606 September 1990 Forwards Insp Repts 50-338/90-20 & 50-339/90-20 on 900806- 10.No Violations or Deviations Noted ML20058P8841990-08-0606 August 1990 Forwards Insp Repts 50-338/90-16 & 50-339/90-16 on 900709-13.No Violations or Deviations Noted ML20056A0491990-07-30030 July 1990 Forwards Insp Repts 50-338/90-17 & 50-339/90-17 on 900709-13.No Violations or Deviations Noted ML20055H3831990-07-25025 July 1990 Confirms 900720 Verbally Granted Temporary Waiver of Compliance from Tech Spec 3.3.1.1,Table 3.3-2 Re Response Time Testing of Pressurizer High Level Reactor Trip Function ML20056A5331990-07-20020 July 1990 Forwards Summary of 900718 Mgt Meeting at Plant Re self-assessment of Facility ML20055H4401990-07-0505 July 1990 Ack Receipt of Providing Scenario for Plume & Injection Pathway Exercise Scheduled on 900807 & 08 ML20055H4491990-07-0303 July 1990 Forwards Summary of 900625 Meeting W/Util in Region II Ofc Re Emergency Preparedness Upgrade Program.List of Attendees Also Encl ML20055H6151990-06-28028 June 1990 Forwards Insp Repts 50-338/90-13 & 50-339/90-13 on 900514-18 & 29.Noncited Violations Noted ML20055H6271990-06-26026 June 1990 Forwards Insp Repts 50-338/90-14 & 50-339/90-14 on 900604-08.No Violations or Deviations Noted ML20059M8771990-06-13013 June 1990 Forwards NRC Performance Indicators for First Quarter 1990. W/O Encl ML20248B4731989-09-21021 September 1989 Forwards Insp Repts 50-338/89-26 & 50-339/89-26 on 890716- 0822 & Notice of Violation ML20247P4281989-09-18018 September 1989 Ack Receipt of Informing NRC of Steps Taken to Correct Violations Noted in Insp Repts 50-338/89-12 & 50-339/89-12 ML20247C2011989-09-0707 September 1989 Forwards Safety Evaluation Accepting Util 890512 Response to IE Bulletin 80-11, Masonry Wall Design IR 05000338/19890181989-09-0101 September 1989 Ack Receipt of Informing NRC of Steps Taken to Correct Violations Noted in Insp Repts 50-338/89-18 & 50-339/89-18.Implementation of Corrective Actions Will Be Examined During Future Insps ML20246M7141989-08-23023 August 1989 Forwards Insp Repts 50-338/89-22 & 50-339/89-22 on 890601-0714.No Violations or Deviations Noted ML20246M5381989-08-22022 August 1989 Forwards Insp Repts 50-338/89-27 & 50-339/89-27 on 890731-0804.No Violations or Deviations Noted IR 05000338/19890141989-08-21021 August 1989 Ack Receipt of Informing NRC of Steps Taken to Correct Violations Noted in Insp Repts 50-338/89-14 & 50-339/89-14 ML20246M4781989-08-21021 August 1989 Confirms 890627 Telcon Between Rf Saunders & PE Fredrickson Re 890824 Mgt Meeting.Meeting Requested to Review Results of SALP Program for Facility ML20246H2371989-08-21021 August 1989 Forwards Safety Sys Outage Mods & Maint Team Insp Repts 50-338/89-200 & 50-339/89-201 During Wks of 890508 & 22.No Violations Noted.Identified Weaknesses Re Performance of Vendor Surveillance Activities ML20246L2331989-08-15015 August 1989 Forwards SALP Repts 50-338/89-16 & 50-339/89-16 for May 1988 - May 1989.Overall Performance Satisfactory During Assessment Period ML20245L3381989-08-0707 August 1989 Forwards Insp Repts 50-338/89-24 & 50-339/89-24 on 890710-14.No Violations or Deviations Noted ML20248D9791989-08-0303 August 1989 Forwards Request for Addl Info Re Pipe Stresses Due to Differential Settlement Between Svc Bldg & Main Steam Valve House.Responses Should Be Provided in Forthcoming License Amend Request ML20248D9011989-08-0303 August 1989 Advises That NRC Approval Neither Granted Nor Required in Case of Certification Since Util Assumes Responsibility for Regulatory Compliance w/10CFR55.45(b)(2) IR 05000338/19890111989-08-0303 August 1989 Ack Receipt of Informing NRC of Steps Taken to Correct Violations Noted in Insp Repts 50-338/89-11 & 50-339/89-11 ML20248D2571989-07-31031 July 1989 Forwards Corrected Pages 1 & 2 to Insp Repts 50-338/89-12 & 50-339/89-12 Due to Pages Not Being Photocopied Correctly ML20246A3941989-07-28028 July 1989 Forwards Insp Repts 50-338/89-21 & 50-339/89-21 on 890613-14.No Violations or Deviations Noted IR 05000338/19890151989-07-25025 July 1989 Ack Receipt of Re Violations Noted in Insp Repts 50-338/89-15 & 50-339/89-15 ML20247D5211989-07-17017 July 1989 Forwards Insp Repts 50-338/89-12 & 50-339/89-12 on 890412-14 & 20-26 & Notice of Violation ML20247D5161989-07-12012 July 1989 Forwards Summary of Mgt Meeting Held on 890619 at Region II Ofc Re self-assessment of Facility.List of Attendees & Handout Encl ML20246K3031989-07-0707 July 1989 Forwards Insp Repts 50-338/89-19 & 50-339/89-19 on 890605-09.No Violations or Deviations Noted ML20246G1361989-07-0505 July 1989 Discusses Insp Repts 50-338/89-08,50-339/89-08,50-338/89-14 & 50-339/89-14 & Forwards Notice of Violation.Violations Noted:Inadequate Svc Water Supply to safety-related Spray Sys During Accident Conditions.W/O Notice of Violation ML20246E7221989-06-30030 June 1989 Forwards Insp Repts 50-338/89-20 & 50-339/89-20 on 890605-09 & 12-13.No Violations or Deviations Noted ML20246D4191989-06-30030 June 1989 Advises That 890329 Rev 22 to Physical Security Plan Consistent W/Provisions of 10CFR50.54(p) & Acceptable ML20246J8941989-06-29029 June 1989 Forwards Insp Repts 50-338/89-14 & 50-339/89-14 on 890418-0531 & Notice of Violation.Concerns About Mgts Ability to Ensure Future Independent Review Activities Will Meet Both Ltr & Intent of Tech Specs 1990-09-07
[Table view] Category:OUTGOING CORRESPONDENCE
MONTHYEARML20212J9101999-10-0101 October 1999 Forwards SE Accepting Licensee 990916 & 27 Relief Requests IWE-3 for Plant.Se Addresses Only IWE-3 Due to Util Urgent Need for Relief.Requests IWE-7 & IWE-8 Will Be Addressed at Later Date ML20211N2531999-09-0808 September 1999 Responds to Request to Exceed 60,000 Mwd/Mtu Lead Rod Burnup in Small Number of Fuel Rods in North Anna Unit 2.Informs That NRC Offers No Objection to Requested Use of Rods in Reconstituted Fuel Assembly.Se Supporting Request Encl ML20211J2211999-08-31031 August 1999 Approves Request to Remove Augmented ISI (Aii) Program for RCS Bypass Lines from North Anna Licensing Basis.Se Re Request to Apply LBB to Eliminate Augmented Insp Program on RCS Bypass Lines Encl ML20210T0671999-08-13013 August 1999 Informs of Completion of Review of Proposed Revs of Schedule for Withdrawal of Rv Surveillance Capsules Submitted by VEPCO on 981217.Approves Proposed Revs.Forwards Safety Evaluation ML20210N2921999-08-0505 August 1999 Discusses Which Submitted Proposed TSs Bases Change for Containment Leakage. Licensee Changes to Bases May Be Subj to Future Insps or Audits ML20209E3711999-07-0202 July 1999 Forwards Insp Repts 50-338/99-03 & 50-339/99-03 on 990425-0605.Violations Being Treated as Noncited Violations ML20196G2581999-06-23023 June 1999 Discusses Closure of GL 92-01,rev 1,suppl 1,reactor Vessel Structural Integrity ML20206U7441999-05-20020 May 1999 Informs That NRC Unable to Conclude That NAPS Has Met Intent of Supplement 4 to GL 88-20.RAI Re Fire Area of IPEEE Encl. Response Requested within 90 Days of Submittal Date ML20207A8541999-05-20020 May 1999 Forwards RAI Re Licensee Listed Responses to GL 95-07, Pressure Locking & Thermal Binding of Safety-Related Power-Operated Gate Valves. Response Requested within 90 Days of Submittal Date ML20206L4661999-05-10010 May 1999 Forwards SE Accepting Request to Delay Submitting Plant, Unit 1 Class Piping ISI Program for Third Insp Interval Until 010430,to Permit Development of Risk Informed ISI Program for Class 1 Piping ML20206P6401999-05-0505 May 1999 Refers to Public Meeting Conducted at North Anna Power Station on 990413 to Discuss Results of North Anna Plant Performance Review.List of Attendees Encl ML20205S0321999-04-21021 April 1999 Forwards SER Accepting Util 980804 Requests for Relief from Certain Requirements of Subsections IWE & Iwl of 1992 Addenda of ASME Section Xi.Alternatives for IWE2,IWE4,IWE6 & IWL2,authorized Pursuant to 10CFR50.55a(a)(3)(ii) ML20205Q2451999-04-12012 April 1999 Forwards Insp Repts 50-338/99-01 & 50-339/99-01 on 990131- 0313.Three Violations of NRC Requirements Occurred & Being Treated as non-cited Violations,Consistent with App C of Enforcement Policy ML20205T1411999-04-0909 April 1999 Informs That on 990407,A Royal & Ho Christensen Confirmed Initial Operator Licensing Exam Scheduled for Y2K.Initial Exam Dates Scheduled for Wks of 000925 & 1002 for Approx 11 Candidates ML20196K9891999-03-29029 March 1999 Confirms Plans to Hold Meeting on 990413 at North Anna Nuclear Information Center to Discuss North Anna Plant Performance Review ML20205B5641999-03-24024 March 1999 Forwards Audit Rept of North Anna Power Station,Units 1 & 2 Conducted on 990126-28 in Glen Allen,Va.Audit Team Assessment of Y2K Project Plan Identified Plan as well-structured,well Organized & Well Implemented ML20196L0021999-03-24024 March 1999 Discusses Plant Performance Review of North Anna Power Station Completed by NRC on 990205.Found Overall Performance at North Anna to Be Acceptable.Several Examples of Inadequate or Untimely Problem Resolution Were Noted ML20207E1331999-03-0101 March 1999 Forwards Insp Repts 50-338/98-11 & 50-339/98-11 on 981220- 990130.No Violations Noted.Util Conduct of Activities at North Anna Power Station Generally Characterized by Safety Conscious Plant Operations & Good Maintenance ML20203F8681999-02-16016 February 1999 Forwards Request for Addl Info Re Util 970527 plant-specific Summary Rept in Response to USI A-46 Program at North Anna Power Station,Units 1 & 2 ML20196K3681999-01-21021 January 1999 Discusses Closure of Tasks Re Generic Implication of part- Length Control Rod Drive Mechanism Housing Leak at Prairie Island,Unit 2 & Anna Power Station,Units 1 & 2 ML20199K3221999-01-14014 January 1999 Forwards Insp Repts 50-338/98-10 & 50-339/98-10 on 981108- 1219.No Violations Identified.Conduct of Activities at North Anna Power Station Generally Characterized by safety-conscious Plant Operations ML20198S3921999-01-0606 January 1999 Forwards Request for Addl Info on Resolution of USI A-46 for North Anna Power Station,Units 1 & 2 IR 05000338/19980051999-01-0606 January 1999 Ack Receipt of Informing NRC of Steps Taken to Correct Violations Noted in Insp Repts 50-338/98-05 & 50-339/98-05 on 981105 ML20198H8951998-12-22022 December 1998 Forwards Corrected Authorizing Proposed Alternative for Remainder of Second 10-yr Insp Interval & Se.Authorization Ltr Erroneously Dtd as 981103 & End Dates of Second 10-yr Insp Intervals Incorrect ML20198P0401998-12-14014 December 1998 Refers to 981210 Open Meeting at Licensee Request at Region II Re Weld Discrepancies Identified on Various Auxiliary Feedwater Sys Pipe Supports During Safety Sys Engineering Insp.List of Attendees & Util Presentation Handouts Encl ML20196J5591998-12-0808 December 1998 Submits Correction to Transmittal Ltr ,which Forwarded SE Authorizing Licensee Relief Request Re Rev to NDE-32, Svc Water Sys Leaks, Per 10CFR50.55a(a)(3)(ii). Corrected Date Should Be 981203 ML20198A7491998-12-0404 December 1998 Confirms 981203 Telcon Between L Hart of Licensee Staff & V Mccree of NRC Re Meeting Scheduled for 981210 in Atlanta, Ga Concerning Pipe Support Potential Construction Errors or Drawing Errors ML20198H9341998-12-0303 December 1998 Forwards SE Authorizing Proposed Alternative for Remainder of Second 10-yr Insp Interval for Plant,Per Util 970224 Relief Request ML20196G9431998-12-0202 December 1998 Advises of Planned Insp Effort Resulting from Insp Planning Meeting,Completed on 981102.Details of Insp Plan for Next 4 Months Encl ML20196A6581998-11-25025 November 1998 Forwards Notice of Withdrawal of 960321 Application for Amends to Licenses NPF-4 & NPF-7 for Plant.Changes Would Have Clarified Requirements for Testing Charcoal Absorbent in Waste Gas Charcoal Filter Sys ML20196B0011998-11-23023 November 1998 Forwards Emergency Response Data Sys Implementation Documents,Which Include Data Point Library Updates for Listed Plants.Changes Should Be Made to Data Base as Soon as Possible.Without Encl ML20196H3951998-11-0505 November 1998 Forwards Insp Repts 50-338/98-05 & 50-339/98-05 on 980713- 17,27-31 & 0921-25 & Notice of Violation & Re Failure to Implement Adequate Corrective Actions to Resolve Corrosion of AFW Tunnel Pipe Supports Identified in Sept 1996 ML20196G1161998-11-0303 November 1998 Forwards Safety Evaluation Authorizing Rev to ISI Program Relief Reuest NDE-32 Re SWS Leaks,Submitted on 980224,for Remainder of Second 10-yr Insp Interval for Each Unit ML20155H8061998-10-29029 October 1998 Responds to Discussing NRC Initiatives & Efforts. Plans for Another Stakeholders Meeting Underway for 981113. Staff Will Continue to Solicit Feedback & Comments from Public on Initiatives ML20154Q8331998-10-21021 October 1998 Informs That Info Submitted in 980911 Application & Affidavit Re WCAP-15063-P, W In-Reactor Creep Model, Marked Proprietary,Will Be Withheld from Public Disclosure Per 10CFR2.790(b)(5) & Section 103(b) of AEA of 1954 ML20154G3611998-10-0707 October 1998 Informs That Util 951018,960722 Responses to Anomalies Identified in SER Dtd 950924,acceptable & Subject to NRC Inspection.Request for Relief from Valve Quarterly Tests & Proposal to Extend Test Interval,Not Acceptable ML20155B0531998-10-0202 October 1998 Forwards Exam Repts 50-338/98-301 & 50-339/98-301 on 980817- 21 & 31-0903.Fourteen Candidates Passed & One Failed Exam ML20155B3741998-09-25025 September 1998 Cancels Meeting Which Was Scheduled for 981109.Purpose of Meeting Was to Discuss SALP for North Anna Power Station. Informs That NRC Has Suspended SALP Program Until Staff Completes Review of NPP Performance Assessment Process ML20239A3801998-09-0202 September 1998 Confirms 980819 Telephone Conversation Between D Summers & L Garner Re Meeting at NRC Request Which Has Been Scheduled for 981109.Purpose of Meeting Will Be to Discuss SALP for North Anna Power Station ML20151T9351998-08-27027 August 1998 Informs of Change Being Implemented by Region II Re Administrative Processing of Licensee Responses to Novs. Licensee NOV Responses Which Accept Violations & Require No Addl Communication to Be Ack in Cover Ltr of Next Insp Rept ML20237E0111998-08-25025 August 1998 Discusses Completion of Licensing Action for GL 97-05, Steam Generator Tube Insp Techniques, ML20151T5531998-08-18018 August 1998 Forwards Insp Repts 50-338/98-07 & 50-339/98-07 on 980720-23.No Violations Noted.Insp Observed Selected Portions of Emergency Organization Response in Key Facilities During EP Plume Exposure Exercise IR 05000338/19980011998-08-0404 August 1998 Discusses Re Insp Rept Review & Three Clarifications Re Insp Repts 50-339/98-01 & 50-338/98-01 Discussions of Security at ISFSI ML20237B0001998-07-30030 July 1998 Confirms 980728 Telcon Between D Sommers & R Haag Re Meeting Scheduled for 980810 in Atlanta,Ga to Discuss Recent Mgt Changes & Items of Interest ML20236M0291998-07-0808 July 1998 Forwards Request for Addl Info Re ASME Section XI Relief Requests NDE-37,through NDE-41 for North Anna Power Station, Unit 1 ML20236K5451998-07-0707 July 1998 Forwards SER Accepting Proposed Change in Commitment on Inservice Insp Program for Protection Against Dynamic Effects Associated W/Postulated Rupture of High Energy Main Steam & Feedwater Piping,In Mechanical Equipment Room ML20236F7311998-06-29029 June 1998 Forwards Request for Addl Info Related to Fire,Seismic & High Wind,Flood & Other External Events Areas of IPEEE Submittal IR 05000338/19980021998-06-25025 June 1998 Ack Receipt of Informing NRC of Steps Taken to Correct Violations Noted in Insp Repts 50-338/98-02, 50-339/98-02 & 72-0016/98-02 ML20236J9871998-06-24024 June 1998 First Final Response to FOIA Request for Documents.Documents Listed in App a Already Available in Pdr.Documents Listed in App B Being Released in Entirety ML20248M0381998-06-0909 June 1998 Forwards Request for Addl Info Re Revised Loop Stop Valve Operation.Changes Will Modify Requirements for Isolated Loop Startup to Permit Filling of Drained Isolated Loop Via Backfill from RCS Through Partially Opened Loop Stop Valves 1999-09-08
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FEB 161959 Virginia' Electric and Power Company ATTN: Mr. W. R. Cartwright, Vice President, Nuclear Operations 5000 Dominion Boulevard Glen Allen, VA 23060 ,
Gentlemen:
SUBJECT: ENFORCEMENT CONFERENCE SUMMARY NRC INSPECTION REPORT N05. 50-338,339/88-31 This letter refers to the Enforcement Conference held at our request on January 18, 198 This meeting concerned activities authorized for your North Anna facilit The issues discussed at this conference related to your corrective action on several control room habitability deficiencies identified during an NRC review. A list of attendees, a summary, and a copy of your handout are enclosed. We are continuing our review of these issues to deter-mine the appropriate enforcement actio In accordance with E.790 of the NRC's " Rules of Practice," Part 2, Title 10, Code of Federal Regulations, a copy of thit letter and its enclosures will be placed in the NRC Public Document Roo Should you have any questions concerning this matter, please contact u
Sincerely, Original signed by J. Philip Stohr (for)
Malcolm L. Ernst Acting Regional Administrator l Enclosures: List of Attendees Meeting Summary
' Handouts ;
cc w/encls:
G. E. Kane, Station Manager R. F. Saunders, Manager - Nuclear Programs and Licensing Commonwealth of Virginia bcc w/encls: 1 A. F. Gibson !
G. R. Jenkins l NRC Resident inspector /
l DRS Technical Assistant .
Document Control Desk 3Gvw h R I I, Ril Ril Ril y (N k, U
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SShaeffer PFredrickson B ilson DCo ins eyes AGi on 02/. /89 02/p/89 ,> 02/g /89 ff/ 9 2/f d/89 42/ 89 RI T '{
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ENCLOSURE 1 l
l ENFORCEMENT CONFERENCE ATTENDEES i
Virginia Electric and Power Company W. Cartwright, Vice President-Nuclear Operations G. Kane, Station Manager R. Saunders, Nuclear Programs and Licensing Manager M. Bowling, Assistant Station Manager J. Hegner, Licensing Supervisor R. Boehling, Project Engineer Nuclear Regulatory Commission, Region II M. Ernst, Acting Regional Administrator, RII ,
L. Reyes, Director, Division of Reactor Projects (DRP) ,.
D. Collins, Acting Director, Division of Radiation Safety and Safeguards (DRSS),RII B. Wilson, Branch Chief, DRP F. Cantrell, Section Chief, DRP P. Fredrickson, Section Chief, DRP l G. Jenkins, Director, Enforcement and Investigation Coordination Staff -
t J. Kahle, Section Chief, DRSS L. King, Resident inspector, DRP
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M. Lewis, Project Engineer, DRP l R. Marston, Reactor Inspector, DRSS B. Uryc, Senior Enforcement Coordinator S. Shaeffer, Project Engineer, DRP Nuclear Regulatory Commission, Headquarters L. Engle, Project Manager, Nuclear Reactor Regulation (NRR)
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ENCLOSURE 2 ENFORCEMENT CONFERENCE SUMMARY An Enforcement Conference was held at the Region 11 Office with Virginia Electric and Power Company (VEPCO) on January 18, 1989, to discuss control room habitability issues at the North Anna Power Statio The Regional Administrator opened the meeting by expressing the NRC's concerns regarding control room habitability problems and corrective actions taken to dat The licensee's Vice President of Nuclear Operations then gave a brief discussion about the subject enforcement issues and their understanding of the NRC's concerns in this area. Also mentioned were some of the corrective actions taken to date. Subsequent discussions consisted of: general system design review, including Updated Final Safety Analysis Report (UFSAR) basis and Technical Specification (TS) 3.7.7.1 applicability; control room habitability chronology of events; cause of potential safety concerns; corrective action for both specific and root causes of potential safety concerns and their safety significanc VEPC0 recognized that potential problems exist with control room habitability due to the marginal design of the air supply systems. They further stated that the habitability systems were designed just to meet the criteria, and their intent is to correct any design deficiencies. During the discussions, the NRC expressed concerns about the timeliness of corrective actions. VEPC0 responded by commenting on the limited available physical space for modifications, the seismic design constraints, and the fact that both units were operating during the modification process. Also addressed in detail by both NRC and VEPC0 representatives was the operability of the Bottled Air Pressurization System with respect to control room pressure boundary inleakage. An inleakage rate of 10 CFM was used to estimate the effect of individual control room door openings which may be necessary during the first hour of an accident. Bottled air is used for the first hour's ventilation and then suction is switched to the turbine building for the next 31 days. The NRC questioned the inleakage rate and discussed the possibility of a bottled air test to provide an actual test of the control room's physical configuratio VEPC0 is considering performance of this tes VEPC0's position is that the makeup air from the i bottles is controlled by a pressure control valve and not by flow rate and with the 10 CFM inleakage estimate, the bottled air will maintain the control room at a positive pressure as required by TS 3.7.7.1. Discussions were also conducted relative to design deficiencies, questionable control of air dampers, and the failure to conduct surveillance in appropriate ways.
l One change was noted in the licensee's handout regarding completed corrective actions for potential safety concerns. Revised operating procedures for fuel handling reflects placing the emergency control room ventilation in service during fuel movement and not the control room ventilation as indicated in the presentation handou _ _ _ _ _ - .
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Enclosure 2 2 i
During the course of the meeting, VEPC0 made the following commitments: ;
- Submit GDC 19 reanalysis for NRC review, which will include administrative control Add requirement for health physics survey of control room and place in procedure All engineering modifications are to be completed by the 1990 refueling outages with administrative controls in plac Analyze control room habitability for all modes of operation (other than those required by TS).
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Add auto-start for emergency fan in recirculation mode upon receipt of bottled air system actuatio Add auto-isolation of normal supply and exhaust on receipt of fuel !
building high high radiation alar Correct inconsistency between design basis and actual design and operation by expanding current Design Basis Documentation Action Plan to include reconciliation with physical configuration and station document Reevaluate UFSAR assumptions for multiple control room envelope entrie Revise TS regarding interpretation of the 0.05 inch positive pressure requirements for control room envelope during the first hou !
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