ML062280013

Tech Spec Pages for Amendment 223 Regarding Administrative Changes and Relocation of Certain Technical Specification Responsibilities

ML062280013
Person / Time
Site:	Pilgrim
Issue date:	08/09/2006
From:	NRC/NRR/ADRO/DORL/LPLI-1
To:
References
TAC MC5419
Download: ML062280013 (18)

Text

B. Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No.223 , are hereby incorporated in the license. The licensee

-shall operate the facility in accordance with the Technical Specifications.

C. Records ENO shall keep facility operating records in accordance with the requirements of the Technical Specifications.

D. Equalizer Valve Restriction - DELETED E. Recirculation Loop Inoperable - DELETED F. Fire Protection ENO shall implement and maintain in effect all provisions of the approved fire protection program as described in the Final Safety Analysis Report for the facility and as approved in the SER dated December 21, 1978 as supplemented subject to the following provision:

ENO may make changes to the approved fire protection program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

G. Physical Protection The licensee shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR27817 and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The combined set of plans, which contain Safeguards Information protected under 10 CFR 73.21, is entitled: 'Pilgrim Nuclear Power Station Physical Security, Training and Qualification, and Safeguards Contingency Plan, Revision 0' submitted by letter dated October 13, 2004.

Amendment "223

1.0 DEFINITIONS (continued)

REFUELING INTERVAL REFUELING INTERVAL applies only to Inservice Code Testing I Program surveillance tests. For the purpose of designating frequency of these code tests, a REFUELING INTERVAL shall mean at least once every 24 months.

REFUELING OUTAGE REFUELING OUTAGE is the period of time between-the shutdown of the unit prior to a refueling and the startup of the plant after that refueling. For the purpose of designating frequency of testing and surveillance, a REFUELING OUTAGE shall mean a regularly scheduled outage; however, where such outages occur within 11 months of completion of the previous REFUELING OUTAGE, the required surveillance testing need not be performed until the next regularly scheduled outage.

SAFETY LIMIT The SAFETY LIMITS are limits below which the reasonable maintenance of the cladding and primary systems are assured.

Exceeding such a limit is cause for unit shutdown and review by the Nuclear Regulatory Commission before resumption of unit operation. Operation beyond such a limit may not in itself result in serious consequences, but it indicates an operational deficiency subject to regulatory review.

SECONDARY SECONDARY CONTAINMENT INTEGRITY means that the CONTAINMENT reactor building is intact and the following conditions are met:

INTEGRITY

1. At least one door in each access opening is closed.

2. The standby gas treatment system is operable.

3. All automatic ventilation system isolation valves are operable

.or secured in the isolated position.

SIMULATED AUTOMATIC SIMULATED AUTOMATIC ACTUATION means applying a ACTUATION simulated signal to the sensor to actuate the circuit in question.

SOURCE CHECK A SOURCE CHECK shall be the qualitative assessment of channel response when the channel sensor is exposed to a radioactive source.

STAGGERED TEST A STAGGERED TEST BASIS shall consist of: (a)a test schedule BASIS for n systems, subsystems, trains, or other designated components obtained by dividing the specified test interval into n equal subintervals; (b)the testing of one system, subsystem, train or other designated components at the beginning of each subinterval.

SURVEILLANCE Each Surveillance Requirement shall be performed within the FREQUENCY specified SURVEILLANCE INTERVAL with a maximum allowable extension not to exceed 25 percent of the specified SURVEILLANCE INTERVAL.

The SURVEILLANCE FREQUENCY establishes the limit for which the specified time interval for Surveillance Requirements may be extended. It permits an allowable extension of the normal surveillance interval to facilitate surveillance schedule and Amendment No. 47-7-2231- 1-5

2.0 SAFETY LIMITS 2.1 Safety Limits 2.1.1 With the reactor steam dome pressure < 785 psig or core flow < 10% of rated core flow:

THERMAL POWER shall be < 25% of RATED THERMAL POWER.

2.1.2 With the reactor steam dome pressure > 785 psig and core flow > 10% of rated core flow:

MINIMUM CRITICAL POWER RATIO shall be > 1.06 for two recirculation loop operation or > 1.08 for single recirculation loop operation.

2.1.3 Whenever the reactor is in the cold shutdown condition with irradiated fuel in the reactor vessel, the water level shall not be less than 12 inches above the top of the normal active fuel zone.

2.1.4 Reactor steam dome pressure shall be _<1325 psig at any time when irradiated fuel is present in the reactor vessel.

2.2 Safety Limit Violation With any Safety Limit not met within two hours the following actions shall be met:

2.2.1 Restore compliance with all Safety Limits, and 2.2.2. Insert all insertable control rods.

Amendment 15, 27, 42, 7-2,133, 146,7, 4,91, 219, 223 2-1

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.5 CORE AND CONTAINMENT COOLING 4.5 CORE AND CONTAINMENT COOLING SYSTEMS SYSTEMS A. Core Spray and LPCI Systems (Cont) A. Co're Spray and LPCI Systems (Cont)

4. During Run, Startup, and Hot Shutdown 1. c. Motor As Specified Modes with the LPCI system inoperable, Operated in 3.13 restore the LPCI system to Operable Valve status within 7 days and maintain both Operability core spray systems and the diesel d. Core Spray Header generators Operable. Otherwise, be in Ap Instrumentation at least Cold Shutdown within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

5. Two low pressure injection/spray Check Once/day subsystems shall be Operable during Calibrate Once/3 Cold Shutdown and Refuel Modes unless the reactor head is removed, the months I

spent fuel pool gates are removed, and Test Step Once/3 water level is at greater than or equal to months elevation 114 foot, except as specified in 3.5.A.6. 2. This section intentionally left blank

6. During Cold Shutdown and Refuel Modes unless the reactor head is 3. LPCI system testing shall be as follows:

removed, the spent fuel pool gates are removed, and water level is at greater than or equal to elevation 114 foot:

a. Simulated Once/

Automatic Operating

a. With one of the required low Actuation Test Cycle pressure injection/spray subsystems inoperable, restore the inoperable b. Pump When tested required low pressure Operability. as specified in injection/spray subsystem to 3.13, verify that Operable status within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. each LPCI pump Otherwise, take immediate action to delivers suspend activities with potential for 4800 GPM at a draining the reactor vessel. head across the

b. With both of the required low pump of at least pressure injection/spray subsystems 380 ft.

inoperable, take immediate action to suspend activities with potential for c. Motor As Specified draining the reactor vessel and Operated in 3.13 restore 1 low pressure Valve injection/spray subsystem to Operability Operable status within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

Otherwise, take immediate action to restore secondary containment and one standby gas treatment system to Operable status and to restore isolation capability in each required secondary containment penetration flow path not isolated.

Amendment No. 1765,200,- 223 223,3/ 3/4.5-2

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.7 CONTAINMENT SYSTEMS (Cont) 4.7 CONTAINMENT SYSTEMS (Cont)

A. Primary Containment (Cont) A. Primary Containment (Cont)

5. All containment isolation check 4. Combined main steam lines:

valves are operable or at least 46 scfh @ 23 psig.

one containment isolation valve where, in each line having an inoperable valve is secured in Pa = 45 psig the isolated position. La = 1.0% by weight of the contained air

@ 45 psig for 24 hrs.

4. NEI 94-01-1995. Section 9.2.3: The first Type A test performed after the May 25, 1995 Type A test shall be performed no later than May 25, 2010.

Primary Containment Isolation Valves Primary Containment Isolation Valves

2. b. In the event any automatic 2. b. 1. The primary containment isolation Primary Containment Isolation valves surveillance shall be Valve becomes inoperable, at performed as follows:

least one containment isolation a. At least once per operating valve in each line having an cycle the operable primary inoperable valve shall be containment isolation valves that deactivated in the isolated are power operated and condition. (This requirement may automatically initiated shall be satisfied by deactivating the be tested for simulated inoperable valve in the isolated automatic initiation and condition. Deactivation means to closure times.

electrically or pneumatically disarm, or otherwise secure the b. Test primary containment valve.)* isolation valves:

1. Verify power operated primary containment isolation valve operability as specified in 3.13.

2. Verify main steam

• Isolation valves closed to satisfy these requirements isolation valve operability may be reopened on an intermittent basis under as specified in 3.13.

I administrative controls.

Amendment No. 13, 136,19, 160, 467, 171, 213, 223 3/4.7-5

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.8 PLANT SYSTEMS (CONT) 4.8 PLANT SYSTEMS (CONTI

2. Mechanical Vacuum Pump Isolation 2. Mechanical Vacuum Pump Isolation Instrumentation Instrumentation LCO 3.8.2 NOTE -------------------- ------------------

When a channel is placed in an Four channels of the Main Steam Line inoperable status solely for the Radiation Monitoring System Radiation - performance of required High function for the mechanical vacuum Surveillances, entry into associated pump shall be OPERABLE Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> APPLICABILITY: provided the associated Function maintains mechanical vacuum pump Whenever any main steam isolation isolation capacity.

I valve is open with steam flowing.

ACTIONS:

--- --------- N- OT E ----------------------- 1. Perform a CHANNEL CHECK Separate Condition Entry is allowed for every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

each channel.

2. Calibrate the trip units every 92 A. One or more required channels days.

inoperable.

3. Perform a CHANNEL I

1. Restore channel to OPERABLE CALIBRATION every 24 status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. months. The allowable trip OR value shall be < 5.5 x normal

2. -------- NOTE ----------------- background.

Not Applicable if inoperable

4. Perform a LOGIC SYSTEM channel is the result of an FUNCTIONAL TEST including inoperable isolation valve. isolation valve actuation every 24 months.

Place channel or associated trip system in trip within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

B. Required Action and associated Completion Time of Condition A not met.

OR Mechanical vacuum pump isolation capability not maintained.

1. Isolate mechanical vacuum within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

OR

2. Isolate Main Steam Lines within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

OR

3. Be in HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

Amendment No. 447-, 223 3/4.8-2

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.9 AUXILIARY ELECTRICAL SYSTEM 4.9 AUXILIARY ELECTRICAL SYSTEM A. Auxiliary Electrical Equipment (Cont) A. Auxiliary Electrical Equipment Surveillance (Cont)

1. Verifying de-energization of the emergency buses and load shedding from the emergency buses.

2. Verifying the diesel starts from ambient condition on the auto-start signal, energizes the emergency buses with permanently connected loads, energizes the auto-connected emergency loads through the load sequence, and operates for

>_5 minutes while its generator is loaded with the emergency loads.

During performance of this surveillance verify that HPCI and RCIC inverters do not trip.

The results shall be logged.

c. Once per operating cycle with the diesel loaded per 4.9.A.1.b verify that on diesel generator trip, secondary (offsite) AC power is automatically connected within 11.8 to 13.2 seconds to the emergency service buses and emergency loads are energized through the load sequencer in the same manner as described in 4.9.A.1.b.2.

The results shall be logged.

Amendment No. 479 223 3/4.9-2

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.9 AUXILIARY ELECTRICAL SYSTEM 4.9 AUXILIARY ELECTRICAL SYSTEM (Cont) (Cont)

B. Operation with Inoperable Eauipment Auxiliary Electrical Equipment Surveillance (Cont)

Whenever the reactor is in Run Mode or Startup Mode with the reactor not in a 3. " Emergency 4160V Buses A5-A6 Cold Condition, the availability of electric Degraded Voltage Annunciation power shall be as specified in 3.9.B.1, System.

3.9.B.2, 3.9.B.3, 3.9.B.4, and 3.9.B.5.

a. Once each operating cycle,

1. From and after the date that calibrate the alarm sensor.

incoming power is not available from the startup or shutdown b. Once each 31 days perform a transformer, continued reactor channel functional test on the operation is permissible under this alarm system.

condition for:

c. In the event the alarm system is

a. 3 days with the startup determined inoperable under transformer inoperable 3.b above, commence logging or safety related bus voltage every 30 minutes until such time as the alarm is restored to operable

b. 7 days with the shutdown status.

transformer inoperable During this period, both diesel 4. RPS Electrical Protection generators and associated Assemblies emergency buses must remain operable. a. Each pair of redundant RPS EPAs shall be determined to

2. From and after the date that be operable at least once per incoming power is not available 6 months by performance of an from both startup and shutdown instrument functional test.

transformers, continued operation b. Once per 18 months each is permissible, provided both diesel pair of redundant RPS EPAs generators and associated shall be determined to be emergency buses remain operable, operable by performance of all core and containment cooling an instrument calibration and I. systems are operable, and reactor by verifying tripping of the power level is reduced to 25% of circuit breakers upon the design. simulated conditions for

3. From and after the date that one of automatic actuation of the protective relays within the the diesel generators or associated following limits:

emergency bus is made or found to be inoperable for any reason, Overvoltage < 132 volts continued reactor operation is Undervoltage > 108 volts permissible in accordance with Underfrequency > 57Hz Specifications 3.4.B.1, 3.5.F.1, 3.7.B.1.c, 3.7.B.1.e, 3.7.B.2.c, and 3.7.B.2.e if Specification 3.9.A.1 and 3.9.A.2.a are satisfied.

Amendment No. 4-9 223 3/4.9-4

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.11 REACTOR FUEL ASSEMBLY (Cont) 4.11 REACTOR FUEL ASSEMBLY (Cont)

C. Minimum Critical Power Ratio (MCPR) C. Minimum Critical Power Ratio (MCPR)

(Cont'd) (Cont'd)

2. The operating limit MCPR values as b. The average scram time to a function of the 1r are given in dropout of Notch 34 is I, Table 3.3-1 of the Core Operating determined as follows:

Limits Report where ,r is given by n specification 4.11.C.2. Y, Ni ,i

• ave = 1=1 n

7 Ni 1=1 Where: an n = number of surveillance tests performed to date in the cycle.

Ni = numbed.of active control rods measured in the ith surveillance test.

Ti = average scram time to dropout of Notch 34 of all rods measured in the ith surveillance test.

c. The adjusted analysis mean scram time (TIr)is calculated as follows:

N1 1/2 TB =g~+1.65 a n

I Ni i=1 Where:

A = mean of the distribution for average scram insertion time to dropout of Notch 34, 0.937 sec.

N1 = total number of active control rods at BOC during the first surveillance test.

( = standard deviation of the distribution for average scram insertion time to the dropout of Notch 34, 0.021 seconds.

Amendment No.24, 42, 54, 5, 133, 138, 6*, 223 3/4.11-3

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.13 INSERVICE CODE TESTING 4.13 INSERVICE CODE TESTING Applicability: Applicability:

Applies to ASME Code Class 1, 2 and 3 Applies to the periodic testing pumps and valves. requirements of ASME Code Class 1, 2 and 3 pumps and valves. I Obiective: Obiective:

To assure the operational readiness of ASME To assess the operational readiness of Code Class 1,2, and 3 pumps and valves. ASME Code Class 1, 2, and 3 pumps and I valves by performance of inservice tests.

Specification: Specification:

A. Inservice Code Testing of Pumps and A. Inservice Code Testing of Pump and Valves Valves

1. Based on the Facility Commercial 1. The ASME OM Code terminology for Operation Date, Inservice Code Testing Inservice Test activities is as follows.

of ASME Code Class 1, 2 and 3 pumps and valves shall be performed in Code Frequencies Terminology accordance with the Inservice Code Testing Program.

Weekly 7 Days Monthly 31 Days Quarterly or 92 Days 3 Mths Semiannually/ 184 Days 6 Mths 9 Months 276 Days Yearly/Annually 366 Days Biannual/2 Yrs 732 Days Amendment No. 4-49, 223 3/4.13-1

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.13 INSERVICE CODE TESTING 4.13 INSERVICE CODE TESTING

3. The provisions in Definitions (1.0) for REFUELING INTERVAL, SURVEILLANCE FREQUENCY, and SURVEILLANCE INTERVAL are applicable to Code testing and to the above frequencies for performing Code testing activities.

4. Performance of Code testing shall be in addition to other specified Surveillance Requirements.

5. Nothing in the Inservice Code Testing Program shall supersede the requirements of Technical Specifications.

Amendment No. 44-9 223 3/4.13-2

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The plant manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.

The plant manager or his designee shall approve, prior to implementation, each proposed test, experiment, or modification to systems or equipment that affect nuclear safety.

5.1.2 The control room supervisor (CRS) shall be responsible for the control room command function. During any absence of the CRS from the control room while the unit is in an operational mode other than Cold Shutdown or Refueling, an individual with an active Senior Reactor Operator (SRO) license shall be designated to assume the control room command function. During any absence of the CRS from the control room while the unit is in Cold Shutdown or Refueling, an individual with an active SRO license or Reactor Operator (RO) license shall be designated to assume the control room command function.

Amendment No. 44*7 223 5.0-1

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.

a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements, including the plant-specific titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications, shall be documented in the Pilgrim Station Final Safety Analysis Report (FSAR);

b. The plant manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant; C. A specified corporate officer for Pilgrim shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety; and

d. The individuals who train the operating staff, carry out health physics, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures 5.2.2 Unit Staff The unit staff organization shall include the following:

a. A non-licensed operator shall be on site when fuel is in the reactor and an additional non-licensed operator shall be assigned when the reactor is in an operational mode other than Cold Shutdown or Refueling.

(continued)

Amendment No. 4.77, 484- 223 5.0-2

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued)

b. At least one licensed Reactor Operator (RO) shall be present in the control room when fuel is in the reactor. In addition, while the unit is in an operational mode other than Cold Shutdown or Refueling, at least one licensed Senior Reactor Operator (SRO) shall be present in the control room.

c. At least two licensed ROs shall be present in the control room during reactor startup, scheduled reactor shutdown and during recovery from reactor trips.

d. Shift crew composition may be less than the minimum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.i for a period of time not to exceed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

e. Higher grade licensed operators may take the place of lower grade licensed or unlicensed personnel.

f. An individual qualified in radiation protection procedures shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, in order to provide for unexpected absence, provided immediate action is taken to fill the required position.

g. The amount of overtime worked by unit staff members performing safety-related functions shall be limited and controlled in accordance with the NRC Policy Statement on working hours (Generic Letter 82-12).

h. The operations manager or assistant operations manager shall hold a Senior Reactor Operator License.

An individual shall provide advisory technical support to the unit operations shift crew in the areas of engineering and accident assessment. This individual shall meet the qualifications specified by the Commission Policy Statement on Engineering Expertise on Shift.

This individual with a Senior Reactor Operator license may.

simultaneously serve a required SRO position.

Amendment No. 4.-7; 223 5.0-3

Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented and maintained.

5.5.1 Offsite Dose Calculation Manual (ODCM)

a. The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and

b. The ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring activities and descriptions of the information that should be included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release, reports required by Specification 5.6.2 and Specification 5.6.3.

Licensee initiated changes to the ODCM:

a. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:

1. sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and

2. a determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;

b. Shall become effective after the approval of the plant manager; and

c. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.

(continued)

Amendment No. 44:77 223 5.0-6

Program and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to ten times the concentration values in Appendix B, Table 2, Column 2 to 10 CFR 20.1001-20.2402;

c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the ODCM;

d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released to unrestricted areas, conforming to 10 CFR 50, Appendix I;

e. Determination of cumulative contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days. Determination of projected dose contributions from radioactive effluents in accordance with the methodology in the ODCM at least

f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I;

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site boundary to areas at or beyond the site boundary conforming to the following:

1. For noble gases: Less than or equal to 500 mrem/yr to the whole body and less than or equal to 3000 mrem/yr to the skin, and

2. For Iodine-1 31, Iodine-1 33, Tritium, and all radionuclides in particulate form with half-lives greater than 8 days: Less than or equal to 1500 mrem/yr to any organ.

h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; (continued)

Amendment No. 47.7- 223 5.0-8

Program and Manuals 5.5 5.5 Proqrams and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

i. Limitations on the annual and quarterly doses to a member of the public from Iodine-131, Iodine-133, Tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and

j. Limitations on the annual dose or dose commitment to any member of the public, beyond the site boundary, due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.

5.5.5 Component Cyclic or Transient Limit This program provides controls to track the FSAR Section C.3.4.1, cyclic and transient occurrences to ensure that components are maintained within the design limits.

5.5.6 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:

1. a change in the TS incorporated in the license; or

2. aapproval change to the updated FSAR or Bases that requires NRC pursuant to 10 CFR 50.59.

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR.

d. Proposed changes that meet the criteria of Specification 5.5.6b above shall be reviewed and approved by the NRC prior to implementation.

Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71 (e).

Amendment No. 492-,223 5.0-9

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area 5.7.1 Pursuant to 10 CFR 20, paragraph 20.1601 (c), in lieu of the requirements of 10 CFR 20.1601, each high radiation area, as defined in 10 CFR 20, in which the intensity of radiation is > 100 mrem/hr but < 1000 mrem/hr, shall be barricaded and conspicuously posted as a high radiation area and entrance thereto shall be controlled by requiring issuance of a Radiation Work Permit (RWP). Individuals qualified in radiation protection procedures (e.g., radiation protection personnel) or personnel continuously escorted by such individuals may be exempt from the RWP issuance requirement during the performance of their assigned duties in high radiation areas with exposure rates < 1000 mrem/hr, provided they are otherwise following plant radiation protection procedures for entry into such high radiation areas.

Any individual or group of individuals permitted to enter such areas shall be provided with or accompanied by one or more of the following:

a. A radiation monitoring device that continuously indicates the radiation dose rate in the area.

b. A radiation monitoring device that continuously integrates the radiation dose rate in the area and alarms when a preset integrated dose is received. Entry into such areas with this monitoring device may be made after the dose rate levels in the area have been established and personnel are aware of them.

c. An individual qualified in radiation protection procedures with a radiation dose rate monitoring device, who is responsible for providing positive control over the activities within the area and shall perform periodic radiation surveillance at the frequency specified by the radiation protection manager in the RWP.

5.7.2 In addition to the requirements of Specification 5.7.1, areas with radiation levels

> 1000 mrem/hr shall be provided with locked or continuouslyguarded doors to prevent unauthorized entry and the keys shall be maintained under the administrative control of an SRO on duty or radiation protection supervision.

Doors shall remain locked except during periods of access by personnel under an approved RWP that shall specify the dose rate levels in the immediate work areas and the maximum allowable stay times for individuals in those areas. In lieu of the stay time specification of the RWP, direct or remote (such as closed circuit TV cameras) continuous surveillance may be made by (Continued)

Amendment No.4--8, 223 5.0-14