ML18086A643

NRC Staff Review of Salem 2 (Pse&G) for Full Power Operation

ML18086A643
Person / Time
Site:	Salem
Issue date:	05/19/1981
From:	NRC COMMISSION (OCM)
To:
Shared Package
ML18086A535	List: ML18086A534 ML18086A643
References
REF-10CFR9.7 NUDOCS 8106080072
Download: ML18086A643 (37)

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!!t\\V '-'I,-,, l L....Jl QE SALEM 2 (PSE&G)

FOR FULL rm;E~ OPERATION COMMISSION BRIEFING - MAY 19. 1981

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GENERAL BACKGROUND I

CABLE SEPARATION REVIE~*! T~AM CONDUCT OF REVIEW FINDINGS AND ACTIONS CONCLUSIONS RECOMMENDATION

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. APRIL 2s MEETrNG ALL ISSUES RESGL'v'ciJ EXCEPT FIRE PROTECTION

. ACTIONS SINCE LAST i*iC:Ciii~G TEAM VISIT TO SALEM TEAM REPORT ISSUED SSER AND LICENSE PREPARED

. PURPOSE OF MEETING DISCUSS RESULTS OF TEAM'S EVALUATION

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CABLE S,_......... -....... """.. ""'.-.....,.., ',..~" llf ttl-\\Ki-i i,j,i,,i;~ i\\C.Y lC.i"I I C.Hrl COMPOSED OF IE AND NRf\\ r~~-3Gm;EL OBJECTIVES MAKE FINDING ON ADEQUACY OF PSE&G'S CABLE SEPARATION

. STUDY MAKE FINDING ON' ADEQUACY OF co*RRECTIVE ACTIONS TAKE~'.

REV 1 EW SY.STEMS NEEDED FOR sHuwurii1 I

REVIEW CABLE ROUTING

. REVIEW EQUIPMENT AND CABLES RE~~~RING PROTECTION

. EVALUATE ADEQUACY OF PROTECTIVE MEASURES ASSUMPTIONS AND CRITERIA

-. IMPLEMENTATION

I JEAN FINDINGS

. P5E&G 1S CABLE SEPARATION STUDY ACCEr7~~~::

LICENSEE COMMITMENTS

. VERIFICATION - JULY 15., 1981 I

. DOCUMENTATION INTERIM, JULY 17, 1981 FINAL, AUGUST 17, 1981

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I L.; 1-n" 1.I. \\.I" ACCEPTABLE IN MANY PLANT AREAS snMi: Al')'=""" r:ir11*11 RE SHORT-TERM c0ooC'l"'TT\\tt: ACTION

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I MAJOR EQUIPMENl,AREAS: : : :*: i ALTERNATE SHUTDOWN

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i*iAjOR EQU I PViENT AREAS DESC~i~TIGN OF PSE&G APPROACH CooncrTT'1C ACTIQl\\IC:

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P.D!J !"!" ! ONAL CAB!..~-WRAPP I NG FIRE BARRIER EXTENSION ADDITIONAL BARRIERS FOR AREAS PROTECTED BY SPRINKLERS SCULT\\111 I:'

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- 1 IMMEDIATE ACTION l S~QRT-TERM ACT! C~~

_ ALL REMAINING.11.CTIONS BY JULY 31., 198J.

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ALTERNATE SHUTDOWN DESCRIPTION OF PSE&G APPROACH I

CORRECTIVE MCiIONS PROCED~~::: r-~GDIFICATI~~~

COMMUNICA.TIONS., LIGHTING SCHEDULE PRIOR TO OPERATTON ABOVE 5% POWER

• CABLE SEPARATiui~ ~TuuY ACCEPTABLE

• CORRECTIVE ACTIO~~~..CCEPTABLE WITH RECOMMENDED MODIFIC.~.T!ONS

REVISIONS TO DRAFT ~ICENSE OF i-iAY 15,, 1931

• RESTATEMENT OF REQUIREME~!T FOR COMPLIANCE WITH APPENDIX R TO 10 CFR PART 50 CPAGF 7. PARAGRAPH C. Cll) (A))

DELETION OF CONDITION ON r1lNIMUM STAFFING LEVEL <PAGE 8,,

PARAGRAPH C. Ul) (B) (2) C v r r I))

• REVISION TO DEADLINE FOR ESTABLISHING REGULARLY SCHEDULED EI GHT~HOUR SH I FTS <PAGE 16,, PARAGRP.PH c I C25) (A)

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RECOMMENDATION AUTHORIZE DIRECTOR OF NRR TO ISSUE FP LICENSE

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PROPOSED DRAFT LICENSE FOR SALEM 2

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D. C. 20555 Docket No.:

50-311 Mr. R. L. Mittl, General Manager Licensina and Environment Engineering and Construction Department Public Service Electric and Gas Company 80 Park Plaza Newark, New Jersey 07101.

SUBJECT:

SALEM NUCLEAR GENERATING STATION, UNIT NO. 2* ~ ISSUANCE OF FACILITY OPERATING LICENSE DPR-75 The Nuclear Regulatory Corrmi ssi on has issued the enclosed Faci 1 i ty Operating License DPR-75 to the Public Service Electric and Gas Company, Philadelphia Electric Company, Delmarva Power and Light Company and Atlantic City Electric Company for the Salem Nuclear Generating Station, Unit No. 2, located in Salem County. New Jersey. License No. DPR-75 authorizes operation of the Salem Nuclear Generating Station, Unit No. 2 at 100 percent power {3411 megawatts thermal).

Also enclosed are copies.of the related Supplement No. 6 to the Safety Evaluation Report and a copy of the Federal Register Nati ce, which has been forwarded to.*

the Office of the Federal. R~gister for publication.

Enclosures:

Sincerely, Darrell G. Eisenhut, Director Di vision* of Li censi na

• Office of Nuclear Reactor _Regulation

l. Faci 1 i ty Operating License No. DPR-75 with Appendices A and B (Technical Specifications)

2. Supplement No. 6 to Safety Evaluation Report

3. Federal Register Notice cc:

See next page

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 no ti fi cations 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 faci 1 i ty wi 11 operate in conformity with the' app 1 i cation, as amended, the provisions of the Act, and the regulations of the Commission; D.

There is reasonab 1 e assurance: ( i) that the acti vi ti es 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 TO CFR Chapter-I; E.

Public Service Electric and Gas Company is te_fhnically qualified to engage in the activities authorized by this operating license in accordance with the Commission 1 s regu 1 a ti ons set fo.rth in 10 CFR.

Chapter I;

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The licen.sees are financially qualified to engage in the activities authorized by this license in accordance with the Commission 1s regulations set forth in 10 CFR Chapter I; G.

The licensees have satisfied the applicable provi~ions of 10 CFR Part 140, 11Financial Protection Requirements and Indemnity Agreements, 11 of the Commission 1s 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 1 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 1s regulations in 10 CFR Parts 30, 40 and 70.

2.

Pursuant to approval by the Nuclear Regulatory Cammi ssi on at meetings on January 14, 1981, April 28, 1981, and May 19, 1981, the License for Fuel-Loading and 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 Ci'ty 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 1 i censees. The facility is 1 ocated 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 incorporated herein, the Commission hereby licenses:

(l)"

Public Service Electric and Gas Company, Philadelphia Electric Company, Delmarva Power and Light Company and Atlantic City Electric Company to possess the facility at the designated loca-tion in Salem County, New Jersey, in accordance with the pro-

. cedures and limitations set forth in this license;

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Public Service Electric and Gas Company, pursuant to Section 104b of the Act and 10 CFR Part 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 with the limitations set forth in this license;

( 3}

. Pub 1 i c 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 Rep*ort, 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 fonn, for sample analysts or instrument calibration or associated with radioactive apparatus or components; and (6)

Public Service Electric and Gas Company, pursuant to the Act and

.1 O CFR Parts 30, 40 and 70, to possess, but not separate,. such by-product and special nuclear materials as may be produced by the opera ti on of the f aci 1 i ty.

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 Commission now* or hereafter in effect; and is subject to the additional conditions specified or incorporated below:

(1)

Maximum Power Level Pub lie.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 ( therma 1 ) *

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(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 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 "Special Low Power Test Program", dated August 22, 1980 (See Amendment No. 2 to DPR-75 for the Salem Nuclear Generating Stat.ion, 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 perfonna boron mixing and cooldown test using decay heat and Natu.ral Circulation.

• PSE&G shall submit the test procedure to the NRC for review and approval prior to performance of the*

test. 'l"he results of this test shall be submitted to the NRC prior to starting up following the first refueling outage.

(4)

Initial Test Program PSE&G shall conduct the post-fuel-loading initial test program (set forth in Chapt~r 13 of the Final Safety Analysis Report, as amended) without making any major modifications of this p.rogram unless modifications have be*n identified. and have received prior NRC approval

• Major modi fi cations are defined as:

(a)

Elimination of any testidentified 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 Analysis Report, as amended, as essential;

( c).

Perfonnance of any test at a power leve 1 different by more than five percent of rated power from there described; and H.*-.:~~--;*--*'* ".-*---*****.-:-**"*

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(dl 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 PSE&G shall submit for NRC review within six months of the date of issuance of this opera*ting 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 tl:te interval between Technical Specification surveillanc_e tests; (c) the 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.

(6)

SMII-6 Open Items List Prior to exceeding five percent rated thenna 1 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 I terns Li. st desi g_nated for completion prior to the commencement of power range testing.

All listed items deferred beyond the commencement of power range testing wi 11 be subject to review by NRC Region I inspectors *.

(7)

Master Equipment List Prior to exceeding five percent rated thennal power, PSE&G will have in place a complete Master Equipment List as detailed in correspondence to-NRC Region I dated June 3; 1980.

(8)

Compliance i'ith Regulatory Guide 1.97 By June l, 1983, PSE&G shall implement to the satisfaction of the NRC the pr,ovisions of Regulatory Guide l.97, "Instrumentation for Light-Water-Cooled Nuclear Power Plants to Assess Plant Conditions During and Following an Accident," as modified by PSE&G's commitments to NUREG-0588 and NUREG-0737.

( 9)

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 mechani ca 1 snubbers in accordance with Technical Specification 3.7.9 shall conunence with the first refueling outage.

The initial functional testing shall be completed prior to resuming power operation following the first refueling outage.

( 10)

Environmental Qua*l ifi ca ti on (Section 3.11, Supplement 5)*

PSE&G shall take the following remedial actions, or alternative actions acceptable to the NRC, with regard to the environmental qualification requirements for Class IE. equipment:

(al Prior to exceeding five percent power, PSE&G shall have in place the procedural modifications described in the environmental qua 1 i fi ca ti on submi tta 1 dated December 1, 1980.

(b)

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, P SE&G shall replace each of these detectors at.each refueling outage.

(c) Prior to completion of the first refueling outage or June jQ, 1982, whichever is earliest, PSE&G shall replace the Scotchcast No. 9 resi rr seals, used at the e*l ectri cal connection interface on the NAMCO limit switches, with Conax Electric Conduction Seal Assemblies.

(d)

By no later than June 30, 1982, all safety-related elec-tri ca 1 equipment in the f ac.i 1 i ty sha 11 be qua 1 i fi ed in accordance with the provisions of:

"Guidelines for Evaluating Environmental Qualification of Class IE Electrical Equipment in Operating Reactors" (DOR Guide-lines); or NUREG-0588, "Interim Staff Position on Environmental Qualification of Safety-Related Electrical Equipment," December 1979.

• References are to the appropriate sections of the Safety Eva 1 uati on Report

( NUREG-0517) and its supplements.

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(e) 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.

(f) 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) co1J1Tiit to corrective actions which will result in documentation of compliance of applicable equipment with NUREG-0588 no later than June 30, 1982.

(ll)

~ire Protection (Section 9.7, Supplement 6}

(a)

PSE&G shall comply with the requirements set forth in sections III.G,. III.J, III.L, and IU.* O of Appendix R to 1 O CFR Part 50 in accordance with the requirements of

§50.48 of 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 vol~ and 230 volt switchgear located above the 4160 volt switchgear at elevation 64.

( 2 ), Take the following corrective action for defi ci enci es associated with the alternative shutdown capability.

( i) Coordinate opera.ting. procedures to ensure application of the appropriate alternative method when dictated by plant circumstance or conditions.

(ii) Pro vi de direction to the Senior Shi ft Supervisor as to when control room evacuation is dictated; provide direction as to which procedures, keys, operator aids, and equipment wi 11 be required in the new control location; and provide a discussion of shift organization and personnel deployment for remote operation.

(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.

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(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 communications with alternative shutdown control stations can be established.

(viii) Increase minimum staffing: level, on shift, to include the following individuals; 2 Senior Reactor Operators? 4 Nuclear Control Operators, 10 Equipment/

Utility Operators, the Shift Technical *Advisor, and one maintenance electrician.

(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 a~ well as at all avenues of entrance to and egress from* those areas.

The emergency 1 i ghti ng sha 11 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 1 i ghti ng shal 1 be provided for the operating personne 1 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 above fire barrier;

( 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 roam where separations is 1 ess. than 20 feet.

( 6)

Wrap redundant cab 1 es supplying power from 230 vo 1 t switchgear to the battery chargers where separation is less than 20 feet.

( 7)

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 0-C switchgear, the valve motor control centers located in the electrical penetration area, and the pressurizer heater buses located in the electrical penetration area.

( 8)

Extend barrri ers 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. *

(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 pane 1 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 1s 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 modifi ca ti on is comp 1 ete 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 ava i 1ab1 e, an addi ti ona 1 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 contra 1 power. source.

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(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 va 1 ve *.

( 5}.Local control of charging.

(h)

Prior to July 31, 1981, PSE&G shall complete all requ.ired

• cable wrapping.

(12)

Containment Isolation (Section 6.2.3, Supplements 4 and 5)

J-( a). Prior to exceeding five percent power, PSE&G sha 11 i ns:ta 11 a reset alarm for the containment purge. and pressure-vacuum re 1 i ef valve reset circuitry.

(b) Prior to exceeding.five percent power, PSE&G shall align the isolation valves in the containment pressure-vacuum relief lines such* that the maximum open position corresponds to 60 degrees.

(c) 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 *

. (13)

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 c.i rcul a tors to be tested in the-main condenser for* the circulating water system.

(14)

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-.

(15)

Waterhammer Test (Appendix C, A-1, Supplement 4 and Section 22.2, 11.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 sha 11 obtain NRC approval of the test procedures.

(16). 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 genera tors.

(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 1 i nes. sha 11 not exceed two gallons per minute, and the cumulative leakage from three valves in parallel 1 i nes sha 11 not exceed three ga 11 ons per minute.

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(d) Diesel Generator Reliability (Section 8.3.4, Supplement 5)

PSE&G shall implement the following design and procedural modifi ca ti o.ns with respect to diesel generator reliability:

(i) Complete a formal training program for all the mechanical and electrical maintenance and quality control personnel,_ including supervisors, who are responsi b 1 e for the maintenance and ava i 1-abi 1i ty of the di ese 1 generators. The depth and

_ quality of this training program sha 1l be at least equivalent to that of training programs normally conducted by major diesel engine manufacturers.

(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.

(e) 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 modifi cations resulting from the tests.

(f}

Under.;.Voltage-Protection (Section 8.4.1, Supplement 4}

PSE&G shall install a second 1 evel of undervol tage 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 conta.i nment el ectri ca T penetra ti ans.

Each fuse sha 11 be located. in an indepen~ent compartment in the control center of the present* primary device.

(17)

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

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. power operation following the first refueling outage.

PSE&G shall also provide the results of the analysis and review of instrument failure modes, in tabular form, to the operators for use with existing procedures prior to operation above five percent power.

(18)

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 fallowing the second refue 1 i ng outage.

(19)

Vibration Dynamics Effects. Test (Section 3.9*.1, SER)

PSE&G* shall conduct a preoperational vibration dynamic effects test program for all ASME l, 2 and 3 piping systems and piping restraints during startup test programs and initial operation.

(20}

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.

(21}

Engineered Safety Feature Reset Controls (Section 7.10, Supp 1 ement 5)

• In conformance with IE Bulletin 80-06, PSE&G sha 11 correct the reset actions for the two sets of valves identified in the PSE&G 1 etter 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 percent power.

(22)

Sump Performance (Section 6.3.3, Supplement S)

{a)

PSE&G shall establish guidelines to ensure that an operator will be delegated the responsibility of monitoring the performance of ECC systems during the recirculation mode prior to operation above five percent power.

(b}

PSE&G shall establish a post-accident log for recording low-pressure injection performance which will be included in the Emergency Duty Officer's Check Sheet prior to opera ti on above five. percent power.

(c) Prior to resuming power operation following the first refueling outage, PSE&G shalJ provide a detailed survey of insulation materials.

( d}

Prior to operation above five percent power, contro 1 room operators shall be trained in the recognition and mitigation of LP I performance degradation.

(23)

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.

(24)

Category I Masonry Walls (Section 3.8.3, Supplement 5)

(a) Prjor to operation above five percent power, PSE&G shall:

(i) Submit the information requested in the NRC letter dated January 8, 1981.

(ii) Complete the wall capacity strengthening program or remedial actions described in Section 3.8.3 of Supple-ment 5 to the Safety Eva 1 uati on Report.

(iii) Confirm that the proposed remedi a 1 actions do not preclude the option of implementing additional modi-fications which would, if dictated by future staff review,.render the masonry wall design to meet the zero tensile stress requirements under OBE and SSE conditions.

. *.* ~'.~--*..,...,..... *:-*' *,.,_,..

(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.

(25)

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 Genera ti on Sta ti on, Unit 2, dated J.anuary 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 with out* re 1 i ance on routine use of overtime by June 1, 1981.

(b) Short-Term Accident Analysis and Procedure Revision (section 22.2, t.c.1 and t.c.8)

PSE&G shall revise the emergency operation instruction in accordance with NRC comments on the reviewed procedures prior to operation above five percent power.

The operators shall be briefed on the revisions within 30 effective fu 11 power days of operation.

(c) Control Room Design Review (Section 22.2, I.D.l}

PSE&G shall complete the modifications to the emergency procedures prior to operation above five percent power.

(d) Tra-ining for Mitigating Core Damage (Section 22.2, II.B.4)

PSE&G shall complete the training of all operating personnel in the use of installed plant systems to control or mitigate an accident fn which the core is severely damaged prior to operation above five percent power.

--._--.... ---.---.~~---*

--~--~-- _..,, - -

--.-~--,,.. --....,

(e) Auxiliary Feedwater System Reliability Evaluation (Section 22.2, II.E.1.1)

(i)

PSE&G shall implement all surveillance and. operat-ing procedures detailed in Section 22.2, 1I.E.1.1 of Supplement No. 5 to the Safety Evaluation Report on Salem Nuclear Generating Station, Unit 2 prior to operation above five percent power.

(ii)

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.

(iii}

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.

(iv)

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.

( i ) No 1 ater 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 capabi 1 i ty to meet the criteria of Appendix 2, NUREG-0654, Revision l as. fo 11 ows:

(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.

(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.

(g}

Primary Coolant Sources Outside Containment (Section 22.2.

III.0.1.IJ (i) For those systems in which leakage is measured during shutdown, P SE&G sha 11 make and report leak rate measurements prior to initial startup.

(ii) For* those systems in which leakage is measured during operations. PSE&G will make and report 1 eak rate measurements within 60 effective.

full-power days of plant operation.

(26)

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.ll PSE&G shall implement the requirements of Item r.c.1 specified in NUREG:-0737, "Clarification of TMI Action Plan Requirements:* no later than the implementation dates established in NUREG-0737.

I I (b) Reactor Coolant System Vents (Section 22.3, II.B.l)

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.

(c) 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 1 ater than January 1, 1982.

(d) Post-Accident Sampling {Section 22.3, II.B.3)

( e)

PSE&G shall complete corrective actions needed to provide the capabi 1 i ty 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.

Relief, Safety and Block Valve Test Requirements (Section 22.3, t!.D.1)

PSE&G shall qualify the reactor coolant system relief, safety and block valves under expected operating conditio.ns for design basis transients and accidents in accordance with the plant-specific requirements and schedules established in NUREG-0737, 11Cl ari fi cation of TMI Action

• Plan Requirements.

11 (f) Auxiliary Feedwater Initiation and Indication *.

(Sec ti on 22. 3, I!. E". I. 2)

PSE&G shall upgrade, as necessary. automatic initiation of the auxiliary feedwater system and indication of auxi 1 i ary feedwater flow to each steam generator to safety grade* quality no later than July 1, 1981.

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l

-* (g}

Containment Isolation Dependability (Section 22.3, II.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.1)

PSE&G shall install and demonstrate the operabi 1 i ty 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 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; (iii) Containment atmosphere hydrogen concentration from 0 to 10 volume percent no 1 ater than January 1, 1982; (iv) Containment.gamma radiation up to 107 rad/hr. no later than January 1, 1982; and

• (v)

Noble gas effluent from each potential5release

• point from normal concentrati ans 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 1 ater than January l, 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 operabi 1 i ty of additional instruments or controls needed to supplement installed equipment in order to pro vi* de unambiguous, easy-to-interpret indication of inadequate core cooling no later than January l, 1982.

(j) Thermal Mechanical Report (Section 22.3, II.K.Z.13)

PSE&G shall submit a detailed analysis 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 l, 1982.

(k)

Analysis of Voiding Potential (Section 22.3, II.K.2.17)

PSE&G shall ana.lyze the potential for voiding in the reactor coolant system (RCS) during anticipated tran-sients.

PSE&G shall submit this analysis no later than-January l, 1982.

( l)

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-Ctirrent 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 coolant pump seals.

PSE&G shall submit 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.R.3.30)

(o}

PSE&G shall comply with the requirements of this position as specified in NUREG-0737, "Clarification of TMI Action Plan Requirements."

Com~liance With 10 CFR Part 50.46 (Section 22.3,

!I..3.31)

PSE&G shall perform plant-specific calculations using NRC-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 l, 1983, or one year after NRC approval of LOCA analysis models, 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 Operations 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.

• ~*..,-.. --,--**- -*--

--*--~----... -. ---*-----.*-

E.

PSE&G shall maintain in effect and implement. all provisions of the NRC approved physical security plan entitled "Salem Generating Station, Security Plan, Revision 4, Amendment 2 11

, dated August 3, 1978, submitted pursuant to 10 CFR 73.40 including amendments. and changes made under the authority of 10 CFR 50.54(p).

Pursuant tolO CFR Section 2.790(d), this plan is being withheld from public disclosure because it is deemed to be commercial or financial infonnation 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**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 connnon defense and security and is otherwise in the public interest.

The exemption, therefore, is hereby granted and sha 11 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

• The facility will operate, to the extent authorized herein, in conformity with the application as amended, the provis.ions 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 operational activities which may result in an environmental impact that was not evaluated by the Coimnission, PSE&G shall prep~re 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 Environmenta.l 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.

\\

I

~I 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.(26}, 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 desi gnee., no later than the first working day following the.

violation, with a written followup report within 14 days.

J. The licensees shall irrmediately 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 Conunission shall require in accord-ance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public 1 i ability cl aims.

L. This license is effective as of the date of issuance and shall expire at midnight September 25, 2008.

FOR THE NUCLEAR REGULATORY COMMISSION Harold R. Denton, Director Office of Nuclear Reactor Regulation

Attachment:

Appendices A & B Date of Issuance: