ML18086A622
| ML18086A622 | |
| Person / Time | |
|---|---|
| Site: | Salem  |
| Issue date: | 05/20/1981 |
| From: | Case E Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML18086A623 | List: |
| References | |
| NUDOCS 8106050125 | |
| Download: ML18086A622 (23) | |
Text
F UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D. C. 20555 PUBLIC SERVICE ELECTRIC AND GAS COMPANY PHILADELPHIA ELECTRIC COMPANY DELMARVA POWER AND LIGHT COMPANY ATLANTIC CITY ELECTRIC COMPANY DOCKET NO. 50-311 SALEM NUCLEAR GENERATING STATION, UNIT NO. 2 FACILITY OPERATING LICENSE License No. DPR-75
- 1.
The Nuclear Regulatory Commission (the Commission) having found that:
A.
The application for license filed by Public Service Electric and Gas Company for itself and the Philadelphia Electric Company, Delmarva Power and Light Company and Atlantic City Electric Company (herein-after referred to as the licensees) complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act),
and the Commission's regulations set forth in 10 CFR Chapter I and all required notifications to other agencies or bodies have been duly made; B.
Construction of the Salem Nuclear Generating Station, Unit No. 2 (facility) has been substantially completed in conformity with Con-struction Permit No. CPPR-53 and the application, as amended, the pro-visions of the Act and the regulations of the Commission;
- c.
The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission; D.
There is reasonable assurance: (i) that the activities authorized by this operating license can be conducted without endangering the health and safety of the public, and (ii) that such activities will be con-ducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I; E.
Public Service Electric and Gas Company is technically qualified to engage in the activities authorized by this operating license in accordance with the Commission's regulations set forth in 10 CFR Chapter I; 11}5 *.
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F. The licensees are financially qualified to engage in the activities
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authorized by this license in accordance with the Commission's re~ulations set forth in 10 CFR Chapter I; G.
The licensees have satisfied the applicable provisions of 10 CFR Part 140, 11Financial Protection Requirements and Indemnity Agreements, 11 of the Commis~ion's regulations; H.
The issuance of this operating license will not be inimical to the common defense and security or to the health and safety of the public; I.
After weighing the environmental, economic, technical and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of Facility Operating License No. DPR-75 subject to the conditions for protection of the environment set forth herein is in accordance with 10 CFR Part 50 Appendix D of the Commission's regulations and all applicable requirements have been satisfied; and J.
The receipt, possession, and use of source, byproduct and special nuclear material as authorized by this license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40 and 70.
- 2.
Pursuant to approval by the Nuclear Regulatory Commission at meetings on January 14, 1981, April 28, 1981, and May 19, 1981, the License for Fuel-Loading anQ Low-Power Testing issued on April 18, 1980 is superseded by Facility Operating License No. DPR-75 hereby issued to Public Service Electric and Gas Company, Philadelphia Electric Company, Delmarva Power and Light Company and Atlantic City Electric Company (licensees) to read as follows:
A.
This license applies to the Salem Nuclear Generating Station, Unit No. 2, a pressurized water nuclear reactor and associated equipment*
(the facility), owned by the licensees. The facility is located on the southern end of Artificial Island on the east bank of the Delaware River in Lower Alloways Creek Township in Salem County, New Jersey and is described in the Final Safety Analysis Report as supplemented and amended and the Environmental Report as supplemented and amended.
B.
Subject to the conditions and requirements i~corporated herein, the Commission hereby licenses:
(1 )
Public Service Electric and Gas Company, Philadelphia ~lectric Company, Delmarva Power and Light Company and Atlantic City.
Electric Company to possess the facility at the designated loca-tion in Sal em County, New Jersey, in accordance with the pro-cedures and limitations set forth in this license;.
j -
' (2)
Public Service Electric and Gas Company, pursuant to Section 104b of the Act and 10 CFR Pa~t 50~ "Domestic Licensing of Production and Utilization Facilities," to possess, use and operate the facility at the designated location in Salem County, New Jersey, in accordance witn the limitations set forth in this l i cen se; (3)
Public Service Electric and Gas Company, pursuant to the Act and 10 CFR Part 70, to receive, possess and use at any time special nuclear material as reactor fuel, in accordance with the limita-tions for storage and amounts required for reactor operation, as described in the Final Safety Analysis Report, as supplemented and amended; (4)
Public Service Electric and Gas Company, pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration and as fission detectors in amounts as required; (5)
Public Service Electric and Gas Company, pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess and use in amounts as required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; and (6)
Public Service Electric and Gas Company, pursuant to the Act and 10 CFR Parts 30, 40 and 70, to possess, but not separate, such by-product and special nuclear materials as may be produced by the operation of the facility.
- c.
This license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act and to the rules, regulations and orders of the Commis~ion now or hereafter in effect; and is subject to the additfonal conditions specified or incorporated below:
(1)
Maximum Power Level Public Service Electric and Gas Company (PSE&G) is authorized to operate the facility at steady state reactor core power *1 evel s not in excess of 3411 megawatts (thermal).
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- w (2)
Technical Specifications The Technical Specifications contained in Appendices A and B attached hereto are hereby incorporated into this license.
PSE&G shall operate the facility in accordance with the Technical Specifications.
(3)
Special Low Power Test Program
. (-4)
PSE&G shall complete the training portion of the Special Low Power Test Program in accordance with PSE&G's letter dated September 5, 1980 and in accordance with the Commission's Safety Evaluation Report "Sp~cial Low Power Test Program", dated August 22, 1980 (See Amendment No. 2 to DPR-75 for the Salem Nuclear Generating Station, Unit No. 2) prior to operating the facility at a power level above five percent.
Within 31 days following completion of the power ascension testing program outlined in Chapter 13 of the Final Safety Analysis Report, PSE&G shall perform a boron mixing and cooldown test using decay heat and Natural Circulation.
PSE&G shall submit the test procedure to the NRC for review and approval prior to performance of the test~ The results of this test shall be submitted to the NRC.
prior to starting up following the first refueling outage
- Initial Test Program PSE&G shall conduct the post-fuel-loading initial test program (set forth in Chapter 13 of the Final Safety Analysis Report, as amended) without making any major modifications of this program unless modifications have been identified and have received prior NRC approval.
Major modifications are defined as:
(a)
Elimination of any test identified in Chapter 13 of the Final Safety Analysis Report, as amended, as essential; (b)
Modification of test objectives, methods or acceptance.
criteria for any test identified in Chapter 13 of the Final Safety Ahalysi s Report, as amended~- as essential; (c)
Performance of any test at a power level different by more than five percent of rated power from there described; and
.. (d)
Failure to complete all tests included in the described program (planned or scheduled for power levels up to the authorized power level) prior to exceeding a core burnup of 120 effective full power days.
(5)
Instrument Trip Setpoints
( 6)
(7)
PSE&G shall submit for NRC review within six months of the date of issuance of this operating license the following values for each Reactor Protection System and Engineered Safety Features instrumentation channel:
(a) the Technical Specification allowable value (the Technical Specification trip setpoint ~
the instrument drift assumed in the accident analysis);
(b) the instrument drift assumed to occur during the interval between Technical Specification surveillance tests; (c)
~he components of the cumulative instrument bias; and (d) the maximum margin between the Technical Specification trip setpoint and the trip value assumed in the accident analysis.
SMII-6 Open Items List Prior to exceeding five percent rated thermal power, PSE&G will resolve to the satisfaction of the NRC's Office of Inspection and Enforcement all remaining construction and testing deficiencies in the SMII-6 Open Items List designated for completion prior to the commencement of power range testing.
All listed items deferred beyond the commencement of power range testing will be subject to review by NRC Region I inspectors.
Compliance With Regulatory Guide 1.97 By June 1, 1983, PSE&G shall implement to the satisfaction of the NRC the provisions of Regulatory Gl!i de 1.97.,
11 Instrumentation for Light-Water-Cooled Nuclear Power Plants to Assess Plant Conditions During and Following an Accident, 11 as modified by PSE&G' s commitments to NUREG-0588 and NUREG-0737.
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__ :.,*- (8)
Snubbers (a) Within 4 months after issuance of the license, PSE&G shall provide a Technical Specification listing of mechanical snubbers.
In the interim, PSE&G will conduct a comprehensive mechanical snubber inspection program implemented by plant instructions.
(b)
The functional testing of hydraulic and mechanical snubbers in accordance with Technical Specification 3.7.9 shall commence with the first refueling outage.
The initial functional testing shall be completed prior to resuming power operation following the first refueling outage.
(9) Environmental Qualification (Section 3.11, Supplement 5)*
PSE&G shall take the following remedial actions, or alternative actions acceptable to the NRC, with re~ard to the environmental qualification requirements for Class IE equipment:
(a)
No later than June 30, 1982, the wide-range resistance temperature detectors for the reactor coolant system shall be qualified for radiation exposure for the 40-year plant life and appropriate exposure condition due to design basis accidents. Pending completion of such qualification and acceptance by the NRC, PSE&G shall repla~e each of these detectors at each refueling outage.
(b)
Prior to completion of the first refueling outage or June 30, 1982, whichever is earliest, PSE&G shall replace the Scotchcast No. 9 resin seals, used at the electrical connection interface on the NAMCO limit switches, with Conax Electric Conduction Seal Assemblies.
(c)
By no later than June 30, 1982, all safety-related elec-trical equipment in the facility shall be qualified in accordance with the provisions of:
"Guidelines for Evaluating Envirorimental Qualificatjon of Class IE Electrical Equipment in Operating Reactors" (DOR Guide-1 ines); or NUREG-0588, "Interim Staff Position on Environmental Qualification of Safety-Related Electrical Equipment, 11 December 1979.
- References are to the appropriate sections of the Safety Evaluation Report (NUREG-0517) and its supplements.
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(d)
Complete and auditable records must be available and main-tained at a central location which describe the environmental qualification method used for all safety-related electrical equipment in sufficient detail to document the degree of compliance with the DOR Guidelines or NUREG-0588.
Such records should be updated and maintained current as equipment is replaced, further tested, or otherwise further qualified to document complete compliance by June 30, 1982.
(e) Within 90 days of receipt of the equipment qualification safety evaluation, the licensee shall either (i) provide missing documentation identified in Sections 3 and 4 of the equipment qualification safety evaluation which will demonstrate compliance of the applicable equipment with NUREG-0588, or (ii) commit to corrective actions which will result in documentation of compliance of applicable equipment with NUREG-0588 no later than June 30, 1982.
(-10)
Fire Protection (Section 9.7, Supplement 6)
(a)
PSE&G shall install concurrently in Salem Unit 2 all modifications to Salem Unit l implemented to comply with the requirements set forth in sections III.G, III.J, III~L, and III.O of Appendix R to 10 CFR Part 50.
( b)
Prior to exceeding five percent rated thermal power, PSE&G shall:
(1)
Wrap the primary feeds for 125 volt DC control power to the 4160 volt, 460 volt and 230 volt switchgear located above the 4160 volt switchgear at elevation 64.
(2) Take the following corrective action for deficiencies*
associated with the alternative shutdown capability.
(i) Coordinate operating procedures to ensure application of the appropriate alternative method when dictated by plant drcumstance or conditions.
(ii) Provide direction to the Senior Shift Supervisor as to when control room evacuation is dictated; provide direction as to whi. ch procedures, keys, operator. aids, *and equipment will be required in the new control location; and provide a discussion of shift organization and personnel deployment for remote operation.
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- e. (iii) Provide for pre-staging of the special equipment or tools required by local operating procedures.
These items include hand tools, pneumatic jumpers, prepared electrical jumpers, and diesel control power cables.
(iv) Provide a means to maintain system status once local operation has been initiated and to restore normal function to disturbed control systems.
(v)
Provide guidance for ensuring or verifying adequate shutdown margin when outside the control room.
(vi) Provide a means to obtain direct temperature from the hot and cold legs during cooldown as part of the alternate shutdown procedures.
(vii) Implement adequate measures to ensure that effective communicatiom. with alternative shutdown control stations can be established.
(c)
PSE&G shall install adequate 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> emergency lighting, independent of plant power systems, at all locations which may be required to be manned during the alternate shutdown procedure as well as at all avenues of entrance to and egress from those areas.
The emergency lighting shall be installed prior to exceeding five percent power or a continuous fire watch shall be established in the relay room and sufficient dedicated portable battery powered lighting shall be provided for the operating personnel necessary to achieve cold shutdown.
(d)
By July 31, 1981, PSE&G shall:
. (1) Modify or extend existing barriers in 4160 volt switchgear room in order to protect redundant control and power cables currently located abov~ fire barrier;
- e. (2)
Provide a one-hour barrier for the cable trays associated with the turbine-driven auxiliary feedwater pump in the auxiliary feedwater pump room; (3)
Provide a one-hour barrier around one of the redundant cables associated with power, instrumentation, and control for the diesel generators (located in the proximity of the diesel generators) where separation is less than 20 feet.
(4)
Provide smoke detectors in the area of the power feeds to redundant diesel generators in the 4 ft. wide hallway near the waste gas tanks.
(5)
Wrap redundant cables supplying power to the 4 kv switchgear from the diesel generators in the 4 kv switchgear room where separations is less than 20 feet.
(6)
Wrap redundant cables supplying power from 230 volt switchgear to the battery chargers where separation is less than 20 feet.
Raise barriers separating equipment needed for shutdown so that the top of the barrier is above the top of the redundant raceways or wrap both redundant raceways in the following areas:
460-230 volt switchgear, 125 volt D-C switchgear, the valve motor control centers located in the electrical penetration area, and the pressurizer heater buses located in the electrical penetration area *
. Extend barrriers in an 11L 11 shape configuration for the following equipment: the 4160 volt switchgear, 460-230 volt switchgear, the 125 V DC switchgear, the valve motor control centers, and the pressurizer heater buses.
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' (9)
Wrap one of the redundant power cables from the diesel generators located in the fuel oil storage tank room.
(10)
Provide one hour fire barrier for the 207 panel or the turbine driven auxiliary feedwater control cabinet.
(11)
Provide a one hour fire barrier for the remote shutdown panel.
(12)
PSE&G shall review its Fire Interaction analysis for any additional areas impacted by the assumptions and criteria identified in the NRC review team's report as being inconsistently applied or with which the team did not concur.
PSE&G shall report the results of this review to the NRC and complete all additional corrective actions by July 31, 1981.
(e)
By June 5, 1981, PSE&G shall re-route the alternate shutdown power feed in order to provide protection for this cable from a fire affecting the normal instrument trains. Until this modification is complete a continuous fire watch shall be stationed in the elevation 84 switchgear room.
During the period when new leads are being landed, and no power feed to the alternate shutdown instruments is available, an additional fire watch shall be stationed continuously in the Relay Room.
(f)
By July 15, 1981, PSE&G shall complete final engineering verification of the fire protection analysis and corrective actions.
(g)
During the performance of Startup Procedure SUP 82.5, Shutdown From Outside Control Room, PSE&G shall satisfactorily demonstrate the following additional operations:
(1)
Local start of diesel genertor using alternative control power source.
- e. (2)
Local operation of 4 KV breaker.
(3)
Local start of the containment fan cooler unit.
(4)
Local operation of a motor operated and an air operated valve.
(5)
Local control of charging.
(h)
Prior to July 31, 1981, PSE&G shall complete all required cable wrapping.
(11) Containment Isolation (Section 6.2.3, Supplements 4 and 5)
Within 90 days after issuance of the license, PSE&G shall demonstrate to the satisfaction of the NRC that the present containment isolation provisions for the main feedwater lines comply with the requirements of General Design Criterion 57 under all postulated accident conditions, or propose a design change that will achieve compliance.
If necessary, the design change shall be implemented during the first refueling outage.
(12)
Main Condenser (Section 14.0, Supplement 4)
Prior to exceeding 50 percent power, PSE&G shall complete the preoperational testing of the remaining three of six circulators to be tested in the main condenser for the circulating water system.
(13) River Traffic Accidents (Section 2.2.1, Supplement 1)
PSE&G shall also report for the Salem facility any informa-tion reported for the Hope Creek facility relating to circumstances which suggest that the risk from flammable gas clouds (resulting from river traffic accidents on the Delaware River) varies significantly from that previously considered.
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- 12 (14)
Waterhammer Test (Appendix C, A-1, Supplement 4 and Section 22.2, II.E.1.1, Supplement 5)
Prior to exceeding 90 percent power, PSE&G shall perform a test program to show that unacceptable waterhammer damage will not result from anticipated feedwater transients to the steam generator.
Prior to performing the test program, PSE&G shall obtain NRC approval of the test procedures.
(15)
Prior to resuming power operation following the first refueling outage:
(a) Control Rod Guide Thimble (Section 4.2.2, Supplement 4)
PSE&G shall submit the details of the inspection program for control rod guide thimble tube wall wear for NRC approval.
(b)
Inspection Ports (Section 5.2.5, Supplement 5)
PSE&G shall install inspection ports in the steam generators.
(c) Pressure Isolation Valves (Section 5.3.2, Supplement 5)
PSE&G shall install leak test connections on the pressure isolation valves; until installation of the leak test connections, PSE&G may substitute multiple valve leak tests for Technical Specification 3.4.7.2.f, such that the cumulative leakage from two valves in parallel lines shall not exceed two gallons per minute~ and the cumulative leakage from three valves in parallel lines shall not exceed three gallons per minute.
(d) Diesel Generator Reliability (Section 8.3.4, Supplement 5)
PSE&G shall implement the following. design and procedural modifications with respect to die~el generator reliability:
(i) Complete a formal training program for all the mechanical and electrical maintenance and quality control personnel, including supervisors, who
- are responsible for the maintenance and avail-ability of the diesel generators.
The depth and quality of this training program shall be at least equivalent to that of training programs normally conducted _by major diesel engine manufacturers.
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I *1 (e)
( f) (ii) Develop operating procedures that require loading the diesel engine to a minimum of 25 percent of full load for one hour after eight hours of con-tinuous no load operation or as recommended by the engine manufacturer.
Containment Sump Model Test (Appendix C, A-43, Supplement 4)
PSE&G shall submit the confirmatory results of.the containment sump model test program, along with a description of any sump modifications resulting from the tests.
Under-Voltage Protection (Section 8.4.1, Supplement 4)
PSE&G shall install a second level of undervoltage protection for the emergency buses.
(g) Reactor Containment Electrical Penetrations (Section 8.4.3., Supplement 4)
PSE&G shall add a fuse in series with the primary device of each one of 12 circuits fed from 230 volt ac motor control centers to provide backup protection for reactor containment electrical penetrations.-
Each fuse shall be located in an independent-compartment in the control center of the present primary device.
(16)
Loss of Non-Class lE Instrumentation and Control Power Bus During Operation (Section 7.9, Supplement 5)
PSE&G shall implement the design modifications identified in the PSE&G letter dated July 31, 1980 prior to resuming power operation following the first refueling outage.
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~.... (17) Turbine Inspection (Section 3.5.1, Supplement 5)
Prior to resuming power operation following the second refueling outage, PSE&G shall subject the low pressure turbines to an inservice inspection. The inspection shall consist of visual and volumetric examinations.
The visual examination shall be applied to 100 percent of all the accessible surface of the rotors, discs and blading.
The volumetric examination shall use an ultrasonic technique to fully examine the bore and keyway region of the discs in each low pressure turbine.
The inspection results and evaluation of this inservice inspection shall be reported to the NRC and shall be accepted by the NRC prior to startup following the second refueling outage.
(18)
Vibration Dynamics Effects Test (Section 3.9.1, SER)
PSE&G shall conduct a preoperational vibration dynamic effects test program for all ASME 1, 2 and 3 piping systems and piping restraints during startup test programs and initial operation.
(19)
Differential Pressure Baseline Data (Part II,Section I.G, Supplement 4)
PSE&G shall obtain baseline data regarding differential pressure across the elbow pressure taps in each reactor coolant loop for various pump combinations during startup and initial operation.
(20)
Engineered Safety Feature Reset Controls (Section 7.10, Supplement 5)
In conformance with IE Bulletin 80-06, PSE&G shal.l _correct the reset actions for the two sets of valves identified in the PSE&G letter dated June 13, 1980, as* corrected by the PSE&G letter dated July 18, 1980, prior to operating the facility at a power level above five percent.
PSE&G shall also perfonn the additional testing required by IE Bulletin 80-06 prior to operation above five perce~t power.
"'* **... (21)
Sump Performance (Section 6.3.3, Supplement 5)
(a)
Prior to resuming power operation following the first refueling outage, PSE&G shall provide a detailed survey of insulation materials.
(b)
Prior to operation above five percent power, control room operators shall be trained in the recognition and mitigation of LP! performance degradation.
(22)
Radiation Protection Organization (Section 12.0, Supplement 5)
PSE&G shall complete the reorganization actions and programs associated with radiation protection no later than November 1, 1981.
(23)
Category I Masonry Walls (Section 3.8.3, Supplement 5)
(a)
Prior to oper~tion above five percent power, PSE&G shall submit the information requested in the NRC letter dated January 8, 1981.
(b)
Prior to startup following the first refueling, PSE&G shall resolve the difference between the staff criteria and the criteria used by PSE&G to the satisfaction of the NRC and implement the required fixes that might result from such a resolution.
(24)
TMI Action Plan Conditions (Section 22.2, Supplement 5)
Unless otherwise noted, each of the following conditions references the appropriate section of Supplement No. 5 to the Safety Evaluation Report (NUREG-0517) for the Salem Nuclear Generation Station, Unit 2, dated January 1981 and shall be completed to the satisfaction of the NRC by the times indicated.
(a) Shift Manning (Section 22.2, I.A.1~3)
PSE&G shall establish regularly scheduled eight-hour shifts without reliance on routine use of overtime by June 3, 1981.
(b)
Short-Term Accident Analysis and Procedure Revision (Section 22.2, I.C.1 and I.C.8)
The operators shall be briefed on the rev1s1ons to the emergency operation instruction within 30 effective full power days of operation.
(c) Auxiliary Feedwater System Reliability Evaluation (Section 22.2, II.E.1.1)
(i)
PSE&G shall install auxiliary feedwater storage tank level indications and.alanns in accordance
- with the PSE&G letter of May 5, 1980 prior to startup after the first refueling.
(ii)
PSE&G shall perform a 48-hour endurance test on all auxiliary feedwater system pumps prior to operation at 100 percent power.
PSE&G shall provide a report on the results of these tests to NRC within 60 days of completion of the tests.
(iii)
PSE&G shall resolve to NRC's satisfaction the*
issue concerning time available for operator action to prevent pump damage prior to operation above five percent power.
(d) Upgrade Emergency Preparedness (Section 22.2, 111.A.l.l and Section 22.3, 111.A.2)
(i)
No later than 90 days from the date of issuance of this license, PSE&G shall report to the NRC the status of any items related to emergency preparedness identified* by FEMA or the. NRC as requuiring further action.
(ii)
PSE&G shall provide meteorological and dose assessment remote interrogation capability to meet the criteria of Appendix 2, NUREG~0654, Revision l as follows:
(a) a functional description of upgraded capabilities by January 1, 1982, (b) installation of hardware and software by July 1, 1982 provided that NRC approval is received by four months prior to that time and (c) full operational capability by October 1, 1982.
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- {iii)
PSE&G shall provide substantiation that the back-up source of meteorological information from the NWS Office, Greater Wilmington Airport adequately characterizes the site conditions with respect to wind direction and wind speed by July 1, 1981.
{iv)
PSE&G shall provide substantiation that uncertainties associated with plume trajectory prediction, associated with the occurrence of sea-land breeze circulations within the plume exposure pathway zone, are compatible with the planned recommendations for protective actions that would be based upon such projections by July 1, 1981.
(e)
Primary Coolant Sources Outside Containment (Section 22.2, III.D.1.1)
{i) For those systems in which leakage is measured during shutdown, PSE&G shall make and report leak rate measurements prior to initial startup.
{ii) For those systems in which 1 eakage is measured during operations, PSE&G will make and report leak rate measurements within 60 effective full-power days of plant operation.
(25)
TMI Action Plan Dated Conditions (Section 22.3, Supplement 5)
Each of the following conditions references the appropriate section of Supplement No. 5 to the Safety Evaluation Report (NUREG-0517) for the Salem Nuclear Generating Station, dated January 1981, and shall be completed to the satisfaction of the NRC by the times indicated.
{a) Short-Term Accident Analysis and Procedure Revision (Section 22.3, I.C.l)
PSE&G shall implement the requirements of Item I.C.l specified in NUREG-0737, "Clarifi~ation of TMI Action Plan Requirements," no later than the implementation dates established in NUREG-0737.
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Reactor Coolant System Vents (Section 22.3, II.B.1)
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(c)
(d)
PSE&G shall submit procedural guidelines for and a description of the reactor coolant system vents by July 1, 1981.
The reactor coolant system vents shall be installed no later than July 1, 1982.
Plant Shielding (Section 22.3, II.B.2)
PSE&G shall complete modifications to assure adequate access to vital areas and protection of safety equip-ment following an accident resulting in a degraded core not later than January 1, 1982.
Post-Accident Sampling (Section 22.3, II.B.3)
PSE&G shall complete corrective actions needed to provide the capability to promptly obtain and perform radioisotopic and chemical analysis of reactor coolant and containment atmosphere samples under degraded core conditions without excessive exposure no later than January 1, 1982.
(e) Relief, Safety and Block Valve Test Requirements (Section 22.3, II.D.1)
PSE&G shall qualify the reactor coolant system relief, safety and block valves under expected operating conditions for design basis transients and accidents in accordanc.e with the plant-specific requirements and schedules established in NUREG-0737, 11Clarification of TMI Action Plan Requirements.
11 (f) Auxiliary Feedwater Initiation and Indication (Section 22.3, II.E.1.2)
PSE&G shall upgrade, as necessary, __ automatic initiation of the auxiliary feedwater system and indication of auxiliary feedwater flow to each steam generator to safety grade quality no later than July 1, 1981 *
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I (g) Containment Isolation Dependability (Section 22.3, lI.E.4.2)
(i)
PSE&G shall reduce the containment setpoint pressure that initiates containment isolation for nonessential penetrations to the minimum compatible with normal operating conditions no later than July 1, 1981.
(ii)
PSE&G shall install a high radiation isolation signal on the containment purge and vent isola-tion valves no later than July 1, 1981.
(h) Additional Accident Monitoring Instrumentation (Section 22.3, II.F.l)
PSE&G shall install and demonstrate the operability of instruments for continuous indication in the control room of the following variables.
Each item shall be completed by the specified date in the condition:
(i) Containment pressure from minus five psig to three times the design pressure of the containment no later than January 1, 1982; (ii) Containment water level from (i) the bottom to (iii )
(iv)
(v) the top of the containment sump, and (ii) the bottom of the containment to an elevation equivalent to a 600,000 gallon capacity no later than July 1, 1981; Containment atmosphere hydrogen concentration from 0 to 10 volume percent no later than January 1, 1982; 7
Containment gamma radiation up to 10 ra~/hr. no Jater than January 1, 1982; and I
Noble gas effluent from each, potenti.al 5 rel ease point from normal concentrations to 10 uCi/cc (Xe-133) no later than January 1, 1982.
'. PSE&G shall provide the capability to continuously sample gaseous effluents and analyze these samples no later than January 1, 1982.
Until the above installation is completed, PSE&G shall use interim monitoring procedures and equipment.
(i) Inadequate Core Cooling Instruments (Section 22.3, II.F.2)
PSE&G shall install and demonstrate the operability of additional instruments or controls needed to supplement installed equipment in order to provide unambiguous, easy-to-interpret indication of inadequate core cooling no later than January 1, 1982.
(j) Thermal Mechanical Report (Section 22.3, II.K.2.13)
PSE&G shall submit a detailed anal~sis of the thermal-mechanical conditions in the reactor vessel during recovery from small breaks with an extended loss of all feedwater no later than January 1, 1982.
(k) Analysis of Voiding Potential (Section 22.3, II.K.2.17)
PSE&G shall analyze the potential for voiding in the reactor coolant system (RCS) during anticipated tran-sients.
- PSE&G shall submit this analysis no later than January 1, 1982.
(1) Sequential Auxiliary Feedwater Flow Analysis (Section 22.3, Il.K.2.19)
PSE&G shall provide a benchmark analysis of sequential auxiliary feedwater (AFW) flow to the steam generators following a loss of main feedwater no later than January 1, 1982.
(m)
Effect of Loss of Alternating-Current Power on Pump Seals (Section 22.3, II.K.3.25)
PSE&G shall determine, by analysis or experiment, the consequences of a loss of cooling water to the reactor' cool ant pump seals.
PSE&G shall subm.i t the results
- of the evaluation and proposed modifications no later than January 1, 1982.
(n)
Revised Small-Break Loss-of-Coolant-Accident Methods (Section 22.3, II.K.3.30)
PSE&G shall comply with the requirements of this position as specified in NUREG-0737, "Clarification of TMI Action Plan Requirements."
(o)
Compliance With 10 CFR Part 50.46 (Section 22.3, II.K.3.31)
PSE&G shall perform plant-specific calculations using NRG-approved models for small-break loss-of-coolant accidents (LOCAs) to show compliance with 10 CFR Part 50.46.
PSE&G shall submit these calculations by January 1, 1983, or one year after NRG approval of LOCA analysis moctels, whichever is later, only if model changes have been made.
(p)
Emergency Support Facilities (Section 22.3, III.A.1.2)
PSE&G shall maintain in effect an interim Technical Support Center and an interim Emergency Oper~tions Facility until such time as the final facilities are complete.
D.
An exemption from certain requirements of Appendix J to 10 CFR Part 50 is described in the Office of Nuclear Reactor Regulation's Safety Evaluation Report, Supplement No. 4. This exemption was authorized by law and will not endanger life or property or the common defense and security and is otherwise in the public interest. The exemption, therefore, remains in effect.
The granting of the exemption was authorized with the issuance of the License for Fuel-Loading and Low-Power Testing, dated April 18, 1980.
The facility will operate, to the extent authorized herein, in conformity with the application as amended, the provisions of the Act, and the regulations of the Commission.
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- E.
PSE&G shall maintain in effect and implement all provisions of the NRC approved physical security plan en.titled "Salem Generating Station, Security Plan, Revision 4, Amendment 2 11
, dated August 3, 1978, sub~itted pursuant to 10 CFR 73.40 including amendments and changes made under the authority of 10 CFR 50.54(p).
Pursuant *to 10 CFR Section 2.790(d), this plan is being withheld from public disclosure because it is deemed to be commercial or financial information within the meaning of 10 CFR Section 9.5(a)(4) and subject to disclosure only in accordance with 10 CFR Section 9.12.
F.
A temporary exemption from General Design Criterion 57 found in Appendix A to 10 CFR Part 50 is described in the Office of Nuclear Reactor Regula-tion 1 s Safety Evaluation Report, Supplement No. 5, Section 6.2.3.1. This exemption is authorized by law and will not endanger life or property or the common defense and security and is otherwise in the public interest.
The exemption, therefore, is hereby. granted and shall remain in effect through the first refueling outage as discussed in Section 6.2.3.1 of Supplement 5 to the Safety Evaluation Report.
The granting of the exemption is authorized with the issuance of the Facility Operating License, dated May 20, 1981.
The facility will operate, to the extent authorized herein, in conformity with the application as amended, the provisions of the Act, and the regulations of the Commission..
G.
This license is subject to the following additional condition for the protection of the environment:
Before engaging in additional construction or operatio~al activities which may result in an environmental impact that was not evaluated by the Commission, PSE&G shall prepare and record an environmental evaluation of such activity.
When the evaluation indicates that such activity may result in a significant adverse environmental impact that was not evaluated, or that is significantly greater than that evaluated in the Final Environmental Statement or any addendum thereto, PSE&G shall provide a written evaluation of such activities and obtain prior approval from the Director of Nuclear Reactor Regulation.
H.
If PSE&G plans to remove or to make significant changes in the normal operation of equipment that controls the amount of radioactivity in effluents from the Salem Nuclear Generating Station, the NRC shall be notified in writing regardless of whether the change affects the amount of radioactivity in effluents.
I.
PSE&G shall report any violations of the requirements contained in Section 2, Items C.(3) through C.(2~)). E., F., and G of this license within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by telephone and confirmed by telegram, mailgram, or facsimile transmission to the Director*of the Regional Office, or his designee, no later than the first working day following the violation, with a written followup report within 14 days.
J. The licensees shall immediately notify the Commission of any accident at this facility which could result in an unplanned release of quantities of fission products in excess of allowable limits for normal operation established by the Commission.
K.
The licensees shall have and maintain financial protection of such type and in such amounts as the Commission shall require in accord-ance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims.*
L.
This license is effective as of the date of issuance and shall expire at midnight September 25, 2008.
Attachment:
Appendices A & B Date of Issuance: May 20, 1981 FOR THE NUCLEAR REGULATORY COMMISSION Edson G. Case, Acting Director Office of Nuclear Reactor Regulation