IR 05000280/1987009

Insp Repts 50-280/87-09 & 50-281/87-09 on 870405-0502.No Violations Identified.Major Areas Inspected:Licensee Actions on Previous Enforcement Matters,Plant Operations,Maint & Surveillance & LER Review & 10CFR21 Reviews

ML20214V989
Person / Time
Site:	Surry
Issue date:	05/21/1987
From:	Cantrell F, Gloesen W, Holland W, Larry Nicholson NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II)
To:
Shared Package
ML20214V976	List: IR 05000280/1987009 ML20214V973
References
50-280-87-09, 50-280-87-9, 50-281-87-09, 50-281-87-9, NUDOCS 8706150038
Download: ML20214V989 (13)

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NUCLEAR REGULATORY COMMISSION

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Report Nos.: 50-280/87-09 and 50-281/87-09 Licensee: Virginia Electric and Power Co~mpany Richmond, Virginia 23261 Docket Nos.: 50-280 and 50-281 License Nos.': DPR-32 and'0PR-37

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Facility Name: Surry 1 and 2 Inspection Conducted: April 5 through'May 2, 1987 Inspectors: M d[2D 7 W. E. Holland, Senior Resident Inspector Date Signed 9l W ra L.'E. Nicholson Resident Inspector sholeo Date Signed WAN/bL b, hd%ed 5}2o/67 W. B.~Gloersen ' ' ~ Uate ' Signed Approved by: K fdP_ 6[2/[87 F. S. Cantrell, 2B Section Chief Date Signed Division of Reactor Projects SUMMARY Scope: This routine inspection was conducted in the areas of licensee action on previous enforcement matters, plant operations, plant maintenance, plant surveillance, followup on inspector identified items, licensee event report review, 10 CFR Part 21 review, quality programs and administrative controls affecting quality, information meetings with local officials and in office review of special report Results: No violations or deviations were identified in this inspection repor G l

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REPORT DETAILS PERSONS CONTACTED Licensee Employees

• R. F. Saunders, Station Manager

• H. L. Miller, Assistant Station Manager

• E. S. Grecheck, Acting Assistant Station Manager

• J. A. Bailey, Superintendent of Operations D. J. Burke, Superintendent of Maintenance S. P. Sarver, Superintendent of Health Physics

• R. H. Blount, Acting Superintendent of Technical Services R. L. Johnson, Operations Supervisor

• J. A. Price, Site Quality Assurance Manager

• W. D. Craft, Licensing Coordinator J. B. Logan, Supervisor, Safety and Licensing

• Attended exit meetin Other licensee employees contacted included control room operators, shift technical advisors, shift supervisors and other plant personne The NRC Region II Section Chief, Floyd S. Cantrell, participated in visits to local officials on April 8 and 9, 198 . Exit Interview The inspection scope and findings were summarized on May 4, 1987, with those individuals identified by an asterisk in paragraph The following new items were identified by the inspectors during this exi One unresolved item (paragraph 7) was identified with regards to clarification of Technical Specification 4.1.E, " Flushing of Sensitized Stainless Steel Piping"(280; 281/87-09-01).

One inspector followup item (paragraph 11) was identified'for followup on licensee review of the corrective action process (280; 281/87-09-02).

The licensee acknowledged the inspection findings with no desenting comment The license did not identify as proprietary any of the materials provided to or reviewed by the inspectors during this inspectio . Licensee Action on Previous Enforcement Matters (92702) ,

(Closed) Unresolved Item 280,281/85-39-01, Determine Temperature Compensation for Set Point Testing of Pressurizer Safety Valves. The issue involved testing safety valves with nitrogen at ambient temperature in

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l lieu of actual operating temperatures. The licensee acknowledged that temperature is a significant setpoint , influencing parameter and agreed to perform subsequent tests at normal operating temperature. This item is close . Unresolved Items-Unresolved items are matters about which more information is required to -

determine whether they are acceptable or may involve violations or deviations. One new unresolved item is identified in paragraph . Plant Operations Operational Safety Verification (71707)

The inspector conducted daily inspections in the following areas: control room staffing, access, and operator behavior; operator adherence to approved procedures, technical specifications, and limiting conditions for operations; examination of panels containing instrumentation and other reactor protection system elements to determine that required channels are operable; review of control -room operator. logs, operating orders, plant deviation reports, tagout logs, jumper logs, and tags on components to verify compliance with approved procedure The inspector conducted weekly inspections in the - following areas:

verification of- operability of selected ESF systems by valve alignment, breaker positions, condition of equipment or component (s),'and operability of instrumentation and support stems essential to system actuation or performanc Plant tours which included observation of general plant / equipment conditions, fire protection and preventative measures, control of activities in. progress, radiation protection controls, physical security controls, plant housekeeping conditions / cleanliness, and missile hazard The inspector conducted biweekly inspections in the following areas:

l verification review and walkdown of safety-related tagout(s) in effect; review of sampling program (e.g., primary and secondary coolant samples,

, boric acid tank samples, plant liquid and gaseous samples); observation of I control room shift turnover; review of implementation of the plant problem l

identification system; verification of selected portions of containment l

isolation lineup (s); and verification that notices to workers are posted r as required by 10 CFR 19.

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r Certain tours were conducted on backshifts. Backshift tours were

! conducted on April 9, 15, 18, 21, and 22. Inspections included areas in

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the Units 1 and 2 cable vaults, vital battery rooms, Steam Safeguards areas, emergency switchgear rooms, diesel generator rooms, control room,

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I auxiliary building, cable penetration areas, independent spent fuel i

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storage facility, low level intake structure, and Safeguards Valve Pit areas. Reactor coolant system leak rates were reviewed to ensure that detected or suspected leakage from the system was recorded, investigated, and evaluated and that appropriate actions were taken, if required. The inspectors routinely independently calculated RCS leak rates using the NRC Independent Measurements Leak Rate Program (RCSLK9). On a regular basis, radiation work permits (RWPs) were reviewed and specific work activities were monitored to assure they were being conducted per the RWPs. Selected radiation protection instruments were periodically checked, and equipment operability and calibration frequency were verifie In the course of monthly activities, the inspectors included a review of the licensee's physical security progra The performance of 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; and patrols and compensatory post Unit 1 began the reporting period at power. The unit operated at power throughout the inspection perio Unit 2 began the reporting period with the unit critical and preparations being made to latch the turbine after balancing evolutions. The unit was connected to the grid and power operation recommenced on April 7,198 The unit operated at power throughout the remainder of the inspection perio Engineered Safety Feature System Walkdown (71710)

The inspector performed a walkdown of the accessible areas of the Containment Isolation system for both units to verify its operabilit This verification included the following: confirmation that the licensee's system lineup procedure matches plant drawings and actual plant configuration; hangers and supports are operable; housekeeping is adequate; valves and/or breakers in the system are installed correctly and appear to be operable; fire protection / prevention is adequate; major system components are properly labeled and appear to be operable; instrumentation is properly installed, calibrated and functioning; and valves and/or breakers are in correct position as required by plant procedure and unit statu Within the areas inspected, no violations or deviations were identified. Maintenance Inspections (62703)

During the reporting period, the inspectors reviewed maintenance activities to assure compliance with the appropriate procedure Inspections areas included the following:

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Preventive Maintenance of 4160 Volt Circuit Breakers The inspector witnessed portions of the inspection and cleaning of the 4160 V circuit breaker 15J10 that supplies component cooling pump 1-CC-P-1B. This preventive maintenance was being performed per procedure EPH-BKR-E/A1, " Inspect / Service 4160 V Circuit Breakers". Procedure adherence was adequate with the crew demonstrating a thorough knowledge of the. subject equipmen Within the areas inspected, no violations or deviations were identified. Surveillance Inspections (61726)

During the reporting period, the inspectors reviewed various surveillance activities to assure compliance with the appropriate procedures as follows:

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Test prerequisites were me Tests were performed in accordance with approved procedure Adequate coordination existed among personnel involved in the tes Test data was properly collected and recorde Inspection areas included the following:

Flushing of Sensitized Stainless Steel Piping Periodic test procedure 1-PT-18.5, " Flushing of Sensitized Stainless Steel Piping", implements portions of the requirement to perform monthly flushes of the safety injection piping as specified in Technical . Specification 4.1.E. Stress relieving during original construction of some of the cold bent type 316 stainless steel piping resulted in its becoming sensitized to stress corrosion crackin The above procedure flushes possible contaminants which could cause accelerated corrosion to the safety injection piping from the charging pump discharge header to the containment missile barrier for flow to both the hot and cold legs of each loop. The inspector verified that the test results for the previous year were acceptable and properly documented. A review of the flush path revealed that the entire length of piping required to be flushed by the applicable technical specification was not included. The licensee produced a document that stated that only certain portions of the piping within the flush boundary are sensitized, but it did not adequately qualify all piping within the required test boundary. The licensee was continuing the search for additional documentation when the inspection period ended. This item will be tracked as an unresolved item (280;281/87-09-01).

Testing of Safeguards Logic The inspector witnessed portions of the performance of periodic test 1-PT-8,5, " Consequence Limiting Safeguards Logic (Hi-Hi Train)". This monthly surveillance ensures that both trains of this engineered safeguards system actuates on the proper logic. The inspector discussed

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the test with the instrument technicians and reviewed the completed procedure. No discrepancies were note ,

Within the areas inspected, no violations or deviations were identified. Followup on Inspector Identified Items (92701)

(Closed) Inspector Followup Item (IFI) 280/86-41-02 and 281/86-41-03, Followup on Repairs and Testing of the Service Water Side of the Component Cooling Water Heat Exchanger. The licensee completed an evaluation regarding the deterioration of the shell side end bells and subsequently replaced all eight end bells. This item is closed. Licensee Event Report (LER) Review (92700)

The inspector reviewed the LERs listed below to ascertain whether NRC reporting requirements were being met and to determine appropriateness of the corrective action (s). The inspector's review also included followup on implementation of corrective action and review of licensee documentation that all required corrective action (s) were complete on selected LER (Closed) LER 280/86-05, Isolated Phase Bus Duct Arcing. The issue involved a manual trip of the reactor due to arcing on the A isolated phase bus. This arcing occurred due to ground straps that bridge butting sections of duct developing corrosion product buildup on the contact surfaces of their lugs. Corrective action included replacing the damaged section of the duct and welding the connections to prevent recurrenc Remaining shunt straps were inspected and replaced where necessary. The inspector reviewed documentation in the station commitment tracking system and determined that appropriate corrective action was taking place. This item is close (Closed) LER 280/86-07, Failure of Bolting Material in Valve Flanges. Two bolting studs in a motor operated valve were found to have failed due to intergranular stress corrosion of 410 stainless stee The bolting material had been installed as part of a valve bolting material design change issued in 1979. A test, inspection and replacement program for both units was completed for studs with the same or unknown material. The replacement material was ASTM A193 B7 bolting material. This item is close (Closed) LER 280/86-21, Inoperable Individual Rod Position Indicators (IRPI). The issue involved IRPI disagreement with the control rod group demand position by more than 12 steps. This condition is in violation of T.S. 3.12.E. The IRPI for the effected rods were recalibrated to give correct indicattun and returned to service in less that 2 1/2 hours. IRPI drif t is known to be a generic Westinghouse PWR problem. This item is close ..

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(Closed) LER 280/86-24, Inoperable Control Room Chiller The issue involved a loss of one of the two operating chiller units when a trip occurred due to high condenser pressure. The high pressure was a result of low service water flow through the condenser due to clogging of the chiller tubes. The tubes clogged in part due to bypassing of the rotating strainer in . the service water supply line which had been removed from service for maintenance. Corrective action included cleaning of the chiller tubes, returning of the rotating strainer to service, and valving out of the bypass around the rotating strainer. Additional corrective action which resulted from a programmatic review of the operations maintenance and tagging procedures was the preparation of additional maintenance operating procedures to control evolutions which have created problems in the past. The inspector reviewed the LER and verified that new procedures are in place to control removal and return to service of the chillers. This item is close (Closed) LER 280/86-25, Manual Reactor Trip Due to Second Dropped Ro The issue involved a manual trip of the reactor from 20% power due to dropping of a second control rod (P-10). The failure of the control rod drive mechanism for the second rod was due to personnel . bumping the connector for that rod during diagnostic troubleshooting of the cause for the first rod (P-6) that had dropped into the core earlier. Corrective action included replacement of the cable and pin connector for rod P-10 and replacement of the stationary gripper coil for rod P-6. All control rods were exercised and tested satisfactorily prior to restar The inspector reviewed the corrective action and also witnessed portions of the unit restart. This item is close (Closed) LER 280/86-26, Quadrant Power Tilt Greater Than 2%. The issue involved the quadrant to average power tilt ratio which exceed 2% for greater than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. This condition was caused by a dropped rod (P-6)

due to a failed stationary gripper coil in the control rod drive mechanism. The coil was replaced during a short outage (see LER 280/86-25-above) and returned to operable status. High flux trip setpoints were lowered during operation with the d-opped rod. This item is close (Closed) LER 280/86-27, Inoperable Control Room Chiller Due to Failed Rela The issue involved loss of two of three control room chillers in contradiction of technical specification 3.1 One chiller was out for maintenance and the second chiller became inoperable due to a failed relay. Corrective action included initial jumpering of the failed relay to return the chiller to service. Additional corrective action included replacement of the failed relay with a spare. This item is close (Closed) LER 280/86-29, Loss of Charging Pumps Service Water Pumps. The issue involved loss of all service water to the Unit 1 Charging Pump Service Water (CPSW) subsystem due to the operating CPSW pump becoming air bound. The other CPSW pump had been removed from service for replacement earlier in the da The cause of the event was determined to be

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introduction of air into the CPSW pump supply line due to a leak in the blowdown line for the in-line strainer in the service water supply line in conjuction with automatic closure of a service water supply cross connect valve actuated by a smoke detector. Corrective action included repairing the leak in the blowdown line for the strainer and restoring the service water cross connect flowpath to the CPSW pump. This item is closed.

(Closed) LER 280/86-30, Control Room Chillers Inoperable Due to Restriction in Service Water Pipe Caused by Marine Growth. The issue involved a loss of one of the two operating chiller units when one of the two service water lines which supply water to the chiller condensers was isolated for planned maintenanc An unexpected reduction in service water flow due to marine growth in the pipe caused the condenser to trip due to high condenser pressure. Corrective action at that time was to return the isolated service w=ter supply line to service. Additional corrective action is discussed in LER 280/86-31 as discussed below. This item is closed.

(Closed) LER 280/86-31, Loss of Charging Pump Service Water System Caused by Failing to Vent a Service Water Strainer. The issue involved a loss of service water flow to the Unit 1 charging pump service water subsystem.

The event occurred when an operator was swapping the filter elements of an in-line duplex strainer and failed to vent the strainer being placed in service resulting in loss of suction pressure to the charging pump service water pump Corrective action included venting the strainer and returning the system to service. Additional investigation revealed that marine growth had accumulated in the service water supply lines resulting in flow losses in the system. Additional corrective actions included cleaning the service water supply lines and instruction to operators to ensure that in-line strainers are filled and vented prior to placing the strainer in servic This item is closed.

(Closed) LER 280/86-33, Containment Air Partial Pressure Out of Band Due to Electronic Drift of Transmitter. The issue involved discovery that the Unit I containment air partial pressure was found to be less that 9.0 psia during performance of periodic test 1-PT-2.12. The cause of the event was instrument drif Corrective action included recalibration of the pressure instruments and establishment of outside air flowpath to raise containment air pressure to the proper band. This item is closed.

(Closed) LER 280/86-34, Control Room Chiller Tripped Due to Clogging of the Service Water Y-Type Straine The issue involved a loss of one of the two operating chiller units when a trip occurred due to high condenser pressur The high pressure was a result of low service water flow through the condenser due to clogging of the chiller suction strainer.

The strainer clogged in part due to bypassing of the rotating strainer in the service water supply line. Corrective action included cleaning of the Y strainer and valving out of the bypass around the rotating strainer.

Additional corrective action included placing the cleaning of the chiller suction strainers on a monthly cleaning cycle in accordance with maintenance procedure. This item is close r

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(Closed) LER 281/84-19, Reactor Trip (Low Condenser Vacuum). The issue involved a reactor trip from 22% power due to a turbine trip on low condenser vacuu The cause of the low condenser vacuum was a leaking manway gasket on a moisture separator reheater crossunder pipe and small leaks on feedwater heater vent lines. Corrective action included repairs to the leaks and replacement of the manway gaske Also, operating procedure was revised to prevent startup without sufficient condenser vacuum. The inspector reviewed commitment tracking information which indicated that all corrective action was complete. This item is close (Closed) LER 281/84-21, Reactor Trip by Turbine Trip. The issue involved a reactor trip from 20% power caused by a turbine trip. The turbine trip was caused by a loss of the operating B Main Feed Pump when its breakers opene The main feed pump trip was due to excessive drift in the pressure switches that input the low flow signals to the recirculation valve / pump trip logic resulting in a pump trip signal prior to the recirculation valves receiving an open signal. Corrective action included recalibration of the pressure switches and modification of plant procedures to ensure that both main feed pumps remain in operation until the recirculation valves have been verified in the open position. This item is close (Closed) LER 281/86-03, Turbine Trip / Reactor Trip From High Steam Generator Level. The issue involved a turbine trip / reactor trip from 16%

power due to the B main feedwater bypass valve failing to close on demand.The valve failure was believed to be due to a blockage in an air pilot relay which prevented proper air flow to the valve operato Corrective action included cycling of the instrument air supply to the affected valve which apparently cleared the blockage. An engineering review was conducted to evaluate the most effective method for controlling contaminants in the instrument air system. Also procedures were revised to verify proper operation of the main feedwater bypass valves prior to using them. The inspector verified that procedure was revised. The inspector also reviewed the engineering study which recommended additional air compressors and new air purification / drying equipment. This equipment has been funded and is presently being procured for installation this year. This item is close (Closed) LER 281/86-08, Safety Related Valve Found Energized at Powe The issue involved discovery of the low head safety injection pump discharge isolation to the cold legs motor operated valve electrical breaker in the energized condition. Technical specifications require that this valve be de-energized at powe Corrective action included verification that the valve was open from the control room and removal of power to the MOV by opening of the breake A human performance evaluation study was performed to determine appropriate corrective action to prevent recurrenc The study recommended, in part, that technical specification related breakers be verified open during normal shift This action was implemented in station operator logs. The inspector verified that appropriate breakers had been included in station logs for verification of correct position on a shift basi This item is close .

(Closed) LER 281/86-14, Excessive Containment Sump Trip Valve Leakage.

The issue involved excessive leakage of the subject valves which was discovered during Type C containment leakage testing after shutdown of Unit 2 for refueling in October 198 The cause of the event was attributed to excessive containment decontamination efforts at the start of the refueling outage. This effort resulted in depositing of debris in the containment sump which potentially deposited on the valve seat preventing full closure of the valve. Corrective action included the redesign of the system to include ball valves as the containment isolation valves. In addition, the system had a check valve installed to minimize cycling of the new trip valves. The inspector reviewed the LER and verified that the modification was installed during the outage. This item is closed.

(Closed) LER 281/86-15, Pressurizer Safety Valves Outside of Allowable Setpoints. The issue involved surveillance test results during a refueling outage which determined that the subject valve setpoints were out of tolerance. The cause of the event was attributed to minor valve damage / wear and failure to compensate for operating temperature during previous surveillance tests. Corrective action included refurbishment of the valves and lift point adjustment within the required tolerance. Also, further testing will be performed in a test facility under simulated actual operating condition This item is closed.

(Closed) LER 281/86-16, Closure of Containment Radiation Monitoring Trip Valves Due to Inadequate Procedure. The issue involved automatic closure of the subject valves during performance of a containment type A test due to a high CLS signal. The cause of the event was inadequate procedure.

Corrective action included stopping the test, restoring plant conditions by reopening the valves, and then shutting the subject valves prior to resuming the tes Also, future test procedure has been revised to preclude recurrence of the event. This item is closed.

(Closed) LER 281/86-17, Inadvertent Auto Start of the #3 Emergency Diesel Generator Due to Personnel Error. The issue involved an unplanned auto start of the #3 Emergency diesel generator during performance of Periodic Test 8.5A, Consequence Limiting Safeguards (CLS) Functional Test Hi Hi System. The cause of the event was failure to perform the procedure in the proper sequenc Corrective action included stopping the EDG, stopping the test and reviewing the event. After understanding the cause, the test was properly completed. A Human Performance Evaluation System (HPES) investigation was conducted and the conclusion of that review was that the procedure was adequate, and training of the craft was adequate.

However, the report recommended peer review of the event with regard to use of procedure and attention to detail. This item is closed.

(Closed) LER 281/86-19, Individual Rod Position Indicators Out of Calibration During Unit Startup Due to Instrument Drif The issue involved IRPI disagreement with the control rod group demand position by more than 12 steps. This condition is in violation of T.S. 3.1 The

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IRPI for the effected rods were recalibrated to give correct indication and returned to service in less that 2-3/4 hours. IRPI drift is known to be a generic Westinghouse PWR proble This item is close No violations or deviations were identified.

1 CFR Part 21 Inspections (36100)

(Closed) 280/P2184-01, Deficient Gimble Valve for Auxiliary Feedwater Pump Turbine. The issue involved failure of the subject valve to fully close under high inlet pressure and low steam flow. Surry power station was identified as one of the stations affected by the vendor. In a memorandum dated in May, 1984, the station determined through conversations with the vendor that the subject issue was not applicable to Surry Power Statio The inspector reviewed the licensee documentation that the issue was not applicable to the station. This item is close (Closed) 280/P2186-02, Kamam Model KMG-HRH Noble Gas Monitor Does Not Meet Design Specification. The issue involved the subject monitors indicating a saturated condition less that the required 1X10+5 micro curies /cc. The vendor corrected the software in the circuitry and reinstalled and tested the subject monitors at the station in October, 1986. The inspector verified with the instrument sh.9 that the modification was completed and tested. This item is close (Closed) 280/P2186-03, BBC Brown Boveri K600/K800 Circuit Breaker wire harness coming in contact with racking gear inside breaker. The issue involved potential damage to the wire harness resulting in failure of several components in the breaker. Recommended corrective action included inspections of the breakers for damage to the wire harness. The licensee conducted inspections of these types of breakers for damage to the wire harnesses in accordance with vendor recommendations. The inspections were conducted by Maintenance Procedure EPL-BKR-E/R1 which was modified to inspect for wiring damage. No damage was found. The inspector reviewed the applicable part of the maintenance procedur This item is close No violations or deviations were identified.

11. Quality Programs and Administrative Controls Affecting Quality (35701)

During this inspection period, the inspectors reviewed the licensee's program for implementation of 10 CFR 50, Appendix B, Criterion XVI (Corrective Action). This requirement is implemented by the licensee's Topical Report VEP 1-5A, Amendment 5 dated June 1986. In that report, the licensee states in section 17.2.16 that " Adverse conditions significant to quality, the cause of the cunditions, and the corrective actions taken are reported to appropriate levels of both offsite and onsite management by the use of a Deviation Report." This requirement is implemented at the station by Administrative Procedure SUADM-0-12, (Operations Department Notifications). In that procedure, deviations are defined and examples are listed which require submittal of a deviation report. The inspectors have held several meetings with licensee management to discuss deviation

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requirements and use of deviation reports to track and trend corrective action The licensee is reviewing the implementing procedure and will provide feedback to the inspectors on the outcome of this revie Followup on licensee review of the corrective action process is identified as an inspector followup item (280; 281/87-09-02). No violations or deviations were identifie . Information Meetings with Local 0fficials (94600)

On April 8 and 9,1987, the inspectors, accompanied by the Section Chief from the Region II office, conducted meetings with local officials in the surrounding counties and citie The counties visited included Surry, Isle of Wight, James City, and York. The city visited was Newport New The purpose of the meetings was to provide a brief description of the present NRC organization, provide appropriate business telephone numbers and points of contact, and to introduce the resident inspector The meetings were held with appropriate persons including local government coordinators, county administration, and city management. In general, the meetings were constructive with' no major concerns identifie The inspectors also left a standing invitation for additional meetings with interested parties or city officials to discuss matters of mutual interes . Effluent Semiannual Reports (90713)

Technical Specification 6.6.3.C requires the licensee to submit, within 60 days of January 1 and July 1 of each year, routine Radioactive Effluent Release Reports covering the operation of the unit during the previous six months of operation. The inspector reviewed the Semi-Annual Radiological Effluent Release Report for the periods July 1, 1986, through December 31, 1986. The review included an examination of the liquid and gaseous effluent release data. The data are summarized below for liquids and gases for calendar years 1985 and 1986:

Effluent Summary: Surry Power Station Gases - Summation of all releases for Units 1 and 2 1985 1986 Fission and Activation Gases (curies) 2.07 E+3 1.99 E+3 Iodine (curies) 2.55 E-2 1.75 E-2 Particulate (curies) 1.23 E-3 3.43 E-3 Tritium (curies) 3.27 E+1 2.89 E-1 Liquids - Summation of all releases for Units 1 and 2 Fission and Activation Products (curies) 8.55 E+0 8.77 E+0 H3 (curies) 1.09 E+3 8.73 E+2 Dissolved entrained gases (curies) 8.66 E+0 1.23 E+1

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It should-be noted that the quantities of fission and activation products-in liquid waste releases from the plant have been on a downward trend since 1983. From 1983 through 1985, for example, annual liquid release totals were 14.5 curies, 9.73 curies, and 8.55 curies, respectivel ' Quantities of radioactivity released in liquid form during 1986 did not vary significantly from 198 Technical specification .6.6.3.C requires the Radioactive Effluent Release Report to be submitted within 60 days after January 1 of each year and to

. include'an assessment of the radiation doses to the maximum exposed member of the public due to radioactive liquid and gaseous effluents released from the site during the previous calendar year. The assessment of the radiation doses is to be performed in accordance with the Offsite Dose Calculation Manual (ODCM). The inspector reviewed the 1986 annual and quarterly doses to the maximum exposed member of the public- from the '

release of airborne I-131, tritium, and all radionuclides in particulate form with half lives greater than eight days. This was defined as - an infant, exposed through the grass-cow-milk pathway, with the thyroid as the critical organ. The beta and gamma air doses due to noble gas released from the site were calculated at the site boundary. The maximum exposed member of the public from radioactive materials in liquid effluents in unrestricted areas was defined as an adult, exposed by either the invertebrate or fish pathway with the critical organ being either the thyroid or the gastrointestinal tract. A summary of the.1985 and 1986 annual doses to the maximum exposed member of the public is presented in the table belo Dose Summary: Surry Power Station Liquid Effluent Pathway 1985 1986 Total Body (mrem) 3.05 E-2 4.29 E-2 Thyroid (mrem) 5.03 E-2 3.83 E-2 GI-LLI (mrem) 2.03 E-1 1.96 E-1 Gaseous Effluent Pathway 1985 1986

Gamma (mrad) 1.11 E+0 1.19 E+0

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Beta (mrad) 3.02 E+0 3.32 E+0 Thyroid (mrem) 2.30 E-1 3.53 E-2

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