vs˜ nine mile ili unit e · 2018. 2. 6. · y niagara u mohawk niagaramohawkpower corporation/300...

REGULATORY INFQHHATION DISTRIB

ACCESSION N8R:8408280001 , DuC ~ DATE: 84/08/24FACIL:50-410 Nine Mile Point Nuclear Station/

AUTH,l'JAt!E AUTHOR AFF ILIATIONMANGANiona 05000410

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Y NIAGARAU MOHAWK

NIAGARA MOHAWKPOWER CORPORATION/300 ERIE BOULEVARDWEST, SYRACUSE, N.Y. 13202/TELEPHONE (315) 474-1511

August 24, 1984(NMP2L 0142)

Mr. A. Schwencer, ChiefLicensing Branch No. 2U.S. Nuclear Regulatory CommissionWashington, DC 20555

Re: Nine Mile'oint Unit 2Docket No.-50-410

Dear Mr. Schwencer:

Enclosed for your use and information are the Nine Mile Point Unit 2responses to the Nuclear Regulatory Commission's Safety Evaluation Report openitems. This information has been previously disc'ussed with your staff and issubmitted to aid your review of the Unit 2 license application for theresolution of these open items. This information includes Safety EvaluationReport open items 19, 51-3, 56, 58, 89, 104, 105, 123, 124, 125, 129, 130,154, 155, 157, 158, 159, 160, 161, 167, 170, 171, 172, 173, 175 and 186 .

The enclosed will be included in the next Final Safety Analysis ReportAmendment.

Very truly yours,

NLR:jaEnclosurexc: Project File (2)

C. V. ManganVice President

Nuclear Engineering 5 Licensing

840828000 1 840824PDR ADQCK 05000410E PDR

l ~ )%)

UNITED STATES OF AMERICANUCLEAR REGULATORY COMMISSION

In the Matter of'iagaraMohawk Power Corporation )

(Nine Mile Point Onit 2))'ocket No. 50-410AFFIDAVIT

C. V. Mangan, being duly sworn, states that he is Vice President of NiagaraMohawk Power Corporation; that he is authorized on the part of saidCorporation to sign and file with the Nuclear Regulatory Commission thedocuments attached hereto; and that all such documents are true and correct tothe best of his knowledge, information and belief.

Subscribed and sworn to before me,' Notary Public in and for the State of NewYork and County of , this A+~ day of ~~'~ 1984.

Notary Public in and forounty, New York

" My Commission expires:

FRANCES A VAN AUKEH}4tart 9ohllc In tho Siar ~ ol tin~ YorhQsahllnI ln Ononrlao ~ Co. No. lS22181

My Coeraicchas Saolroc March 20, 19

modes is presented in Tables 3. 5-15 and 3. 5-16. It can beobserved that the overall probability of damage by turbinemissiles is 1.803 x 10 7/yr for Unit 2 if the probability ofturbine failure rate of 1.0 x 10 '/yr recommended by the NRCis used. These results are within the acceptance value of10 ~/yr as outlined in Standard Review Plan 2.2.3, but areslightly higher than the acceptable criteria specified inRegulatory Guide 1.115. These calculated figures areconservative. Therefore, overall probability forunacceptable damage by turbine missiles for Unit 2, whenestimated on a more realistic basis, is much lower, and isconsidered acceptable. A Turb ne System Maintenance Program based onthe Mariufacturer's. (GE) recommendations and calculations of missilegeneration probabilities will be developed within 3 years of obtaining anoperating license.

3.5.1.3.4 Turbine Overspeed ProtectionDesi n Bases

Safet Desi n Basis The turbine-generator overspeed protec-tion controls are not reguired to effect or support the safeshutdown of the reactor or to.perform in the operation ofreactor safety features.Power Generation Desi n; Basis The turbine generator 'on-trols are designed to prevent overspeed that may result froma turbine generator trip or a large reduction in load. Themechanical overspeed trip is set at about 110 percent ofrated turbine spee9. The electrical or backup overspeedtrip is set at about 112 percent of rated turbine speed.These set points will prevent the r'otor from exceeding themaximum transient speed of 120 percent (design overspeed) ofrated turbine speed.

Turbine speed is normally controlled by an electrohydrauliccontrol (EHC) system. The speed control unit of the EHCsystem (Figure 3. 5-1) produces a speed/acceleration errorsignal that is determined by comparing the desired speedwith the actual turbine speed at steady-. state conditions, orthe desired acceleration with the actual acceleration duringstartup. When the speed reference signal is increased in astep, the acceleration control will take over and acceleratethe turbine at the selected rate up to the new speedreference, at which point the speed control willautomatically take control. Upon decrease of the speedreference, the turbine will coast down with the valvesclosed. The valves will reopen only when the new set speedhas been reached. There is no deceleration limit. Duringnormal operation at rated speed, the speed error signal isessentially zero, regardless of the load.

3.5-15

~ g ~ ~

NINE HILE POINT UNIT 2

SPR NO. 51 3

In the staff's review of the HPCS diesel generator, it is not clear thatthe check valve upstream of the air receiver tank is. qualified againstwell established leakage criteria following a seismic event. Theapplicant should amend the FSAR to clarify how sufficient air capacityis assured to start the HPCS,diesel generator immediately after aseismic event.

RESPONSE

This response has been incorporated into revised section 9. 5. 6. 2. 2

0 ~Nine Mile Point Unit 2 CESAR

special fittings are designed, manufactured, and inspectedin accordance with the guidelines and requirements of ANSIStandard B3L. l, ASME Section VIII, or DEMA standards. Theseengine- skid-mounted starting ai r piping and associatedcomponents are over-designed (subjected to low workingstresses) for the application, which results in highoperational reliability. The design of the engine mountedstarting air piping and components to the cited designphilosophy and standards is considered equivalent to asys" em designed to ASME Section I II, Class 3 requirementsw'h regard to system functional operability and inservicereliability:Sufficient air capacity to start the HPCS diesel generator immediatelyfollowing a seismic event is assured by qualification of all piping andall components, including the check valve upstream of the air receivertank, to Seismic Category I requir ements. The air receiver 'tanks arecharged to provide the necessary afr for starting the engine.When the air tank pressure e drops below a pr eset 'valve, the aircompressors operate to recharge their respective tank to the fullycharged condition.No Division I I I diesel generator (DG) control functions aresupplied by the air sta ting system or any other air systemto cont ol emergency t".ip functions and/or diesel generatoroperation, except engine cranking.

9.5.6.3 Inst umentation and ControlInstruments and controlsmanual cont ol of each stasystem. The cont ols fo"in the associated dieselmonitors descr'bed belo~room. The cont ol logic is

a.e provided for automatic andndby d'sel generator starting

eacn starting system are locatedgenerator control rqom. The

are locat d in the main controlsnown on =igure 9.5-41:

Oae ationEach diesel gene a"o. a' compressor is s~artecautoma='call.y when the associated ai" receiver pressure islow and stops automat cal' when the a' pressu e is ..o mal.Each a' compressor can be control'ed manually.

Alarms are provided in t~e main con"=ol room for eachstandby diesel generator s" a="'ng sys-'em 'nope able and eachstandby diesel gene a"or s"ar"'ng system trouble.9. 5. 6. 4 Test'g and Inspect'nThe stancby diesel gene ator star='ng system is designedpermit pe iodic inspect'on ar.d testing of the components andsystems. Start'ng system capability is tested dur'ngpreope at'onal test'ng of the diesel generator. Eilters ardstrainers are checked for "'earl'ness dur'ng rou"'neinspection and testing. Blowdown valves are openecperiodically to blow moisture out of the air receivers.Continued integrity of the starting system is assured

9. 5- "-

J E l -'

Nine

Macle

Porn" Un t 2 FSAR

QUEST ION F271. 10

Zdentify if there are any safety-related deep draft pumps inthe plant.RESPONSE

The only safety-related deep draft pumps'tilized in theUnit 2 design are three residual heat removal pumps, one lowpressure core spray pump, and one high pressure core spraypump.

NRC letter dated December 8, 1983 requested additional.information on methods used to qualify long-term operabilityof deep draft pumps.The following is a description of the method used:

Operability MethodsI,ong-term operability has been considered. 'in theemergency core cooling system. (ECCS) pump design.The ECCS pumps ' ffectiveness is evaluated byacceptance, qualification, and in-plant testing.Operability is assured by functional andsurveillance tests, preventive maintenance, andvibration monitoring as described below.

Functional 'Zesting and Surveillance

Each deep draft pump is scheduled to befunctionally tested in accordance withSection XI of the ASME Boiler and PressureVessel Code, which currently recpxires testingat least once each 31 calendar days.

Pump'nletpressure, cLifferential pressure, flowrate, motor vibration, and motor bearingtemperature measurements wi1.1 be taken.Engineering analyses are performed to identifychanges or pump performance trends that may beindicative. of off-normal operating conditions.Functional testing and surveillancerequirements are specified in NMP2 TechnicalSpecifications, surveillance proWchrres, andinservice inspection (XSI) programs.

b. Preventive Maintenance Program

Preventive maintenance and surveillancetesting are scheduled at. periodic intervals.

QSR F271.10-1.

Scheduled preventive maintenance consists ofobtaining megger (resistance) readings of themotor windings, lubricating critical rotatingcomponents, plus general cleaning andinspection of rotating electrical equipment atperiodic intervals specified in preventivemaintenance procedures. Inspection„overhaul,alignment, and impeller lift adjustments willbe scheduled as the ISI program test resultsindicate.

C. Vibration Monitoring Program

As part of the NMP2 plant IS I programs,vibration measurem'ents wi1 l be taken inaccordance with'Section XI of the ASME'oilerand Pressure Vessel Code, which currentlyrequires monitoring, every 31 days. Inaddition, vibration data bases will beestablished during the preoperationaL/startuptesting phase and will be used for comparisonpurposes during later .surveillance testing.Journal bearing wear and shaft whip can bededuced from motor vibration increases. Thedata will be evaluated on a scheduled basis topredict potential bearing and journal failuresand establish replacement schedules. Datawill be available onsite for inspection.

Vibration should be limited to .3 in/sec. velocity peak-to-peak over allmeasured frequencies as measured by an LSD 360 or equivalent equipnent, whenthe motor and punp are operated as a'nit, over the normal design range ofcr ssure and flow. This limit is based on normal oper ation. Higher mmentaryincr eases may be acceptable during starting oi at shut off. This limit is notbased on what the equipnent can withstand. The equipnent danage threshold ishi+er: close to .020 irch-, mcmentary and not sustained. Any sustainedv'br ation. over .3 in/sec may cause excessive bearing wear.

2. Background

ECCS Pump Design,

The ECCS pumps used at NMP2 are manufacturedby Byron Jackson (BJ) Pumps.. Each ECCS pumpis supplied with a casing or suction barrel.These pumps are- not installed in a wet sump;These deep draft, pumps, due to their relativeshortness, demonstrate fewer of the problemsassociated with longer pumps. The longestECCS pump in. service at the NMP2 plant is24 ft long. The rigidity of the pump assemblyis 'nhanced by the use of seismic ringsbetween the pump assembly and the barrel.

The hydraulic design has been developed overthe last 40 years of experience in manyapplications. The; pumps use a doubLe suctionfirst stage to provide stability over a. wide

Q&R F271.10-2

range of flows. Column frequencies are wellremoved from the pump speed.The barrels are relatively large in diameter,thereby providing low velocities around thepump inlets. The suction barrels includeseismic restraints (spoke configuration) whichact as flow straighteners to suppress vortexformation. All pumps are provided with highprecision, k'eyed sleeve-type couplings.The ECCS pumps contain design . features topreclude failure of the impellers, impellerstaking, shafts, bear'ngs, wear rings,couplings, and stuffing boxes. The designincludes safety factors ( loading criteria)based on the expected pressures, temperatures,.and loadings defined in the designspecification. Lateral restraints areincluded in the pump to control deflections.Tolerances assuring alignment of the shaft andpumping elements are verified by designcalculations. Motor shaft deflections withintolerance are predicted in a static seismicanalysis and, are verified by a qualificationtest of a similar motor. A dynamic analysisof the pump and motor is performed todetermine resonances and predict loadingsthroughout the pump and motor.

ECCS Pump TestingTests are performed on each pump delivered. The testsinclude head versus flow, NPSH, and vibration monitoring.The assembled pumps are checked for porper assembly andlow friction by hand turning (rotating) the shaft. Eachpump is run for a total of 100 hours during testing. Aqualification test of a similar pump motor was oerformed.This data provides qualification of the NMP2 pumps motorsby a similarity analysis.

Q&R F271. 10- 3

!.'.ng .'.~g l.e Po> nt Jn' 2 CESAR

O'UEL SYSTEM DESIGN

The fuel system design for Unit 2 is identical to thatreviewed and approved for GESSAR II {Reference 1). Methodsand criteria used to evaluate fuel system performance arealso identical to those used for GESSAR II. The results ofthe NRC review of Section 4.2 of GESSAR II documented inReferences 2 and 3 are therefore applicable to Unit 2.

The Nine Hile Point Unit 2 post irradiation fuel surveillanceprogram for GE designed and manufactured fuel assemblies is theprogram proposed by GE (References g through 8). This programhas been,previousIy approved as satisfying SRP Section 4.2.II.D'.3

4. 2-1

4. 2. 1 References

1. General Electric Standard Sa ety Analysis Report, DocketNo. 50-447.

2. Safety Evaluation Report Related to the Final DesignApproval of the GESSAR II BWR/6 Nuclear Island Design,NUREG-0979, April 1983.

3. Safety Evaluation Report Related to the Final DesignApproval of the GESSAR II BWR/6 Nuclear Island Design,NUREG-0979 (Supplement No. 1), July 19B3.

(4) J. S. Charnley (GE) to C. H. Berlinger, (HRC),. "Post-Irradiation. Fuel Surveillance Program", Hovember 23,

1983.

(5) L. S. Rubenstein (HRC) to R. L. Gridley (GE),"Post-Irradiation Fuel Surveillance"., January 18, 1984.

f

(co) J. S. Charnley (GE) to L. S. Rubenstein (HRC), "FuelSurveil lance Progr am", February 29, 1984..

(7) J. S. Charnley (GE) to L. S. Rubenstein (HRC), "AdditionalOetails Regarding Fuel Surve'illance Program", Hay 25>1984.

{8) L. S. Rubenstein (HRC) to R. L. Gridley (GE), "Acceptanceof GE Proposed Fuel Surveillance Program," June 27, 1984.

4. 2-2,

Nine Mile Point Unit 2 FSAR

9A. 3. 2 Administrative Procedures and. Controls

ADMINISTRATIVE CONTROL'S

Procedures similiar to those presently in effect at Nine MileUnit 81 are being developed for Unit II and will comply withBTP CMEB 9.5-1, Section C.2 Items A through O. 'heseprocedures will be under the control of the supervisor fireprotection nuclear and co-approval by the required supervisors.The administrative controls for fire protection, consist of thefire protection organization, the fires brig'ade Itraining, thecontrols over combustibles and ignition source,'the prefire plansand procedures for fighting fires, surveillance and maintenanceof fire protection features,and quality assurance.9A.3.3 Fire Brigade

A fire brigade of five members has been established atUnit 2. A Nuclear Fire Chief and four nuclear fire fightersare assigned rotating shifts with fire, rescue, and firstaid responsibilities. In addition, these people performinstructions and tests on the fire systems and equipment asrequired. All members shall have knowledge „. in. safetyrelated systems, as. this is a required module in the fixebrigade training programs. The ability to- pass. an annualphysical examination and agility test is required foremployment in the fire department. Brigade members reportdirectly to the Supervisor of Fire Protection-Nuclear or hisassistant.Personal protective equipment such as turnout coats, boots,gloves, and helmets are provided for brigade members. Inaddition approved self-contained breathing apparatus isprovided. Complete sets of equipment are stored in aminimum of ten locations throughout the plant.An approved breathing air-compressor is presently in use forSCBA bottle refilling, in addition a bottle cascade systemis available.Fire brigade members will be trained as outlined in APN-10P(Nuclear Fire Fighter and Nuclear 'ire Chief Training) .This training program is intended to ensure that the Brigade-Leader and at least two members shall have sufficienttraining and a knowledge of plant safety-related systems tounderstand the effects of fire and fire suppression on safeshutdown capability.Technical training for nuclear fire fighters and nuclearfire chiefs shall consist of classroom sessions and in-plantinspections showing site specifics covering the subjects asoutlined. in APN-10P.Station. practical training for nuclear fire fighters andnucleax'ire chiefs shall consist of on-the.-job training,fire drills, training exercises and demonstrations, lecture

9A..3-31

Nine Nile Point Unit 2 5'SAR

QUESTION E460. 18 ( 11. 4)

Provide the NMP2 Process Control Program establishing a setof process parameters and boundary conditions within whichreasonable assuranc'e can be given that solidification willbe complete with essentially zero-Cree liquid based on therecommended WFC-VRS, Topical Report process parameters. Yourprocess control program should include administrative and/orplant operating. procedures to meet waste form structuralstability requireme'nts set forth in Section 61.56 of10CPR61.

RESPONSE

The process control program is not yet available. Generictests have been run on their process using their ownmethodology which indicate the stability requirements of10CFR61 will be met by the NMP2 system.The vendor of the VRS system is preparing a program based onthe requirements of 10CFR61, the NRC' final waste clas-sification and waste form technical position papers concern-ipg stability requirements for solidified waste states thatgeneric information from topical reports using actual orsimulated waste can be used to qualify a process controlprogram.

Tests, will be performed based on the analytical standardsset forth. by the NRC. Test information will be collected toestablish a complete program prior to making the VRS systemoperational.The process control program is expected to be available bythe second quarter of ]g85.


QUESTION E460.19 (11.4)'I

Section 20.311 of 10CFR20 requires that any licensee whotransfers radioactive waste to a land disposal facility mustclassify the waste according to Section 61.55 of 10CFR61.Provide a compliance program to assure proper classificationof waste in accordance with guidance provided in Low-LevelWaste Licensing Branch Technical Position on RadioactiveWaste Classification, Rev. 0, dated May 1983.RESPONSE

Radioactive waste shipments are classif ied according toSection 61. 55 o f 10CFR61 by a combination of directmeasurements 'and scaling factors. Direct measurements aremade of the significant gamma-emitting nuclides, grossalpha, and water content of each batch of waste shipments.Scaling factors, initially developed from industry data andsubsequently from actual measurements on composite samplesof waste batches, are used to quantify nuclides not directlymeasured. The factors will be redeveloped when significantchanges are observed in various process streams and on aperiodic basis.

Specifically, the following is used to quantify the nuclideslisted in Tables 1 and 2 of Section 61.55 for each radioac-t'ive waste stream:

Co-60, Cs-137, and other gamma-emitting nuclides withsufficient yield - By direct gamma ray spectroscopy.Ni-63, Sr-90, Tc-99, and I-129 - By scaling to nuclidesdirectly measured.Transuranics, Pu-241, and Cm-242 - By scaling to grossalpha, directly measured.H-3 - By scaling to water content.C-14, Ni-63, and Nb-94 in activated metal - Byphysical calculations based on exposure.

Procedures. will be developed by March 1985 for classification of wasteshipments from Unit 2. Training procedures will be developed andtraining will be provided prior to use of the procedures.

None Hiie Point Unit 2 FSAR

QUESTION F471.21 (SRP 13. 1)

(a) Figure 13. 1-9 shows that the health physics. andchemistry functions at, NMP-2 are not separated into aHealth Physics Section and Chemistry Section supervisedby a Health Physics Supervisor and a ChemistrySupervisor as recommended by our positions inSection 1 I.A. 1 of NUREG-0731. The organisation andFigure 13.1-9 should be revised to reflect separatesupervision of these distinct functional areas..

(b). The applicant should provide qualifications in the form'f a resume for the Superintendent, Chemistry andRadiation Management (RPM) to demonstrate that the RPMmeets the requirements of Regulatory Guide 1.8,"Personnel Selection and Training."

(c) The applicant should commit to using the criteria ofANSI 3. 1, December 1979, in selecting the individualtemporarily filling the RPM' position as outlined inNUREG-073 1 .

(d) The applicant should commit to t ain health physicstechnicians in acco rdanc e with the criteria'fANSI/ANS 3. 1-1978, which requires one year of relatedtechnical t aining and two years of experience, orANSI 18. 1, which also r equires such training andexperience. Additionally, radiochemistry and radiationprotect/on are separate specialties each requ3.ring twoyears of working experience, as indicated in ANSI 18.1.The applicant should commit to provide experiencedtechnicians with appropriate qualifications ancL two~years of experience in each specialty, chemistry andradiation protection, or should separate the functionsinto two distinct specialties in accordance 'ithANSI 18. 1.

(e) To comply wi'th the criteria of NUREG-0654, Table B-l andthe II.A.d(2) of NUREG-073 1, the applicant should committo have at least one "ANSI 18. 1 qualified health physics

. technician on the site at all times.RESPONSE

See rev. sed Chapter 13..

Q&R F471.21;1

11

'I


TABt'.E 13.l-3 (Cont)

Su ervisor Com uter 0 erations and Maintenance Nuclear

This supervisor is responsible for the proper operation ofthe station process computer, the security computers, thedocument control computer, the outage management andscheduling computer, site applications on the Niagara Mohawksystem computers and the operation and maintenance of thevarious mini and micro computers used on the site forprocess and results applications.Su ervisor Technical Su ort NuclearThe Supervisor Technical Support Nuclear is in charge of thecoordination of the activities of the General Site TechnicalSupport Staff. This staff is composed of technicalassistants of diverse training and exp'erience, who areassigned on special projects within the TechnicalDepartment.

Supervisor Fire Protection Nuclear

The Supervisor Fire Protection Nuclear performs generalplanning, testing, inspection and overseeing of the stati'onfire protection functional activities'eriodic testing ofthe systems and portable equipment is performed by shift.fire brigade personnel or technicians under. the direction ofthe Shift Supervisor or Supervisor Fire Protection.Su erintendent Chemistr and Radiation Mana ement

The Superintendent Chemistry and Radiation Management isresponsible for the chemistry, radiochemistry, radiationprotection and emergency planning requirements of thestations(He is the "Radiation Protection Manager" defined in ANSI 18.1-1978).He also coordinates the chemical'ndradiochemical aspects of the effluent and environmentalmonitoring to ensure the maintenance of site criteria.Under his direction are the Supervisor Chemistry andRadiation Protection, Supervisor Radiological Support, andthe Environmental Coordinator.

Su ervisor Chemistr and Radiation Protection

The Supervisor Chemistry and Radiation Protection has directresponsibility for the Radiochemistry and RadiationProtection Technicians and for the operation of theChemistry and Radiochemistry laboratory, radiationprotection program, and radiological monitoring'quipment.

2 of 7

Nine Mile Point Unit 2 CESAR

TABIE 13.1-3 (Cont)

(When he temporarily fills the ("Radiation Protection Manager" )Superintendent Chemistry and Radiation Management position, heis qualified to ANS 3.1 Draft 1979)Under his direction are the Unit Radiation ProtectionSupervisor, Unit Chemistry Supervisor, and SupervisorInstrument Support.

Su ervisor Radiolo ical Sup ortThe Supervisor Radiol'ogical Support has the responsibilityof assisting the Superintendent Chemistry and RadiationManagement in providing technical and - administrativeguidance in the areas of Emexgency Planning, ALARA,Radiological Engineering, Respiratory Protection, andDosimetry (He is an individual who can temporarily fill the ("RadiationProtection Manager" ) Superintendent Chemistry and Radiation Management'sposition and is qualified to Section 4.4.4 of ANS 3.1 Draft 1979).Under his direction is a technical support staff to provide

technical guidance in the above areas.Unit Radiation Protection Su ervisorUnder the general direction of the Chemistry and RadiationProtection Supervisor, 'his supervisor is responsible forproviding technical and administrative guidance in the areaof radiation protection and for managing and controllingpersonnel exposures to radiation and radioactive materials.A Technical Specialist is assigned to assist thissupervisor.

Unit Chemistr Su ervisorUnder the general direction of the Chemistry and RadiationProtection Supervisor, this supervisor is responsible forproviding technical and administrative guidance in the areaof Chemistry and for managing and controlling radioactiveand chemical effluents. A Technical Specialist is assignedto assist this supervisor.Su ervisor Instrument Su ortUnder the general direction of the Chemistry and RadiationProtection Supervisor, this supervisor is responsible for aprogram to assure that all counting room and radiationprotection instrumentation, as well as sealed sources, areproperly inventoried and maintained. A Technical Specialistis assigned to assist this supervisor.AI,ARA Coordinator

Under the general direction of the Supervisor RadiologicalSupport, this supervisor is responsible for developing andmaintaining a formal AMA progx am to assure that the

2a of 7

Nine Nile Point Unit 2 ESAR

TABI.E 13. 1-3 {Cont)

Radwaste 0 erations Su ervisorThe Radwaste Operations Supervisor, under the generaldirection of the Supervisor Operations, is responsible forcoordinating the sa fe and e fficient conduct of wasteoperations. He schedules and coordinates waste shipmentsand supervises the packing of radioactive waste asnecessary. He directs and supervises the work of operatorsassigned to duties in the waste facility. AssistantSupervisors Radwaste Operations are assigned, as required.

.Radiolo ical En ineerUnder the general direction .of the Supervisor RadiologicalSupport, this supervisor is responsible for providing highlyspecialired technical advice and assistance in 'the area ofradiological. engineering.Emer enc Coordinator

This supervisor has responsibility for maintaining andmodifying the Emergency PLan and Procedures as required, formaintaining the Emergency Plan Monitoring equipment and forthe scheduling, operation and analysis of drills and otherexercises of , the Emergency Plan and Procedures. Anassistant emergency coordinator is assigned., to assist thissupervisor.

Envi ronmenta 1 Protection CoordinatorThis supervisor is responsible for coordination of theenvironmental programs associated with the Nine Mile PointSite and operated by contractors, and also for environmentalmonitoring conducted by site personnel.

3 of 7

I\ I'I

~ ~

eI

0Nine Mile Point Unit 2 FSAR

TABIE 13.,1-4 (Cont)

TitleTraining SpecialistNuclear

Emergency Coordinator

Supervisor Chemistryand Radiation Protection

Unit Radiation ProtectionSupervisor

Unit: Chemistry Supervisor

Supervisor InstrumentSupport

Supervisor RadiologicalSupport

Section ofANSI N18.1-1978

No. Site . Containing

16 NA

NA

4.4.3or'.4.4

„

4

4.4.3

4.7.2

4.6. 1~

Dosimetry Coordinator

At&RA Coordinator

Radiation Protection Technicians As Needed

4.7.2

4. 7.2

4.5.2

Chemistry 8 Radiochemistry Technicians

Environmental ProtectionCoordinator

Respiratory ProtectionCoordinator

Radiological Engineer

Assistant StationShift Supervisor NuclearStation ShiftSupervisor Nuclear

Chief Shift OperatorNuclear AuxiliaryOperator E

As Heeded

16

16

12

4.5.2

4. 7.2

4. 7.2

4. 7.2

~4.3. 1

4.3. 1

4.3. 1

4.3. 1

* When one of these individuals temporarily fills the position of SuperintendentChemistry and Radiation Management this individual will meet the qualificationsof Section 4.4.4 of ANS 3el Draft 1979.

2 of 4

l t\

1 1


13.2.16 Shift Technica1 Advisor Training

The Shift Technical Advisor (STA) attends the training program forSenior Reactor Operators (SRO). The SRO program meets the requirementsof NUREG 0737 Appendix C. For a comparison of the SRO program and therequirements for STA training in NURER 0737 Appendix C see Tahle 13.2-2.

13.2.17 Applicable NRC Documentation

The following NRC documents are applicable to training:10CFR50 Kicensing of Production E Utilization

Facilities10CFRSO

10CFR55

10CFR55

10CFR55.33

NUREG-0094

NUREG-0737

10CFR71

RegulatoryGuide 1.8

Appendix R Fire Protection Program forNuclear Power Facilities Operating Priorto January 1, 1979

Operator license

Appendix A Requalification Program ForE,icensed Operators

Appendix E Renewal of EicensesTechnical Specifications 6. 4. 1

NRC Eicensing Operating Guide

Clarification of TMI Action PlanRequirements

Packaging of Radioactive Material forTransport

Personnel Selection and Training

USNRC fetter Harold Denton to all power reactorapplicants and licensees. Subject-qualifications of reactor operators,dated March 28, 1980.

The 'above-listed regulatory guidance has been addressed inthe training program and implementing procedures.

13.2-56

l'L L '1


CHAPTER 13

LIST OF FIGURES

FigureNumber Title13. 1-1

13.1-1a

13. 1-2

13.1-3

13.1-4

13. 1-5

13.1-5a

13. 1»5b

13. 1-6

13. 1-7

13.1-8

13.1-9

13.2-113.2-213. 4-1

13. 5-1

NMPC CORPORATE UPPER MANAGEMENT ORGANIZATIONAND FUNCTION

NMPC UPPER MANAGEMENT NUCLEAR ORGANI7ATXnN

NMPC NUCLEAR AND SECURITY ORGANIZATION

NUCLEAR GENERATION ORGANIZATION

NUCf EAR ENGINEERING ORGANIZATION

UNIT 2 SITE ORGANIZATION CHART - PRODUCTION

PERSONNEL ASSIGNED DURING PREOPERATIONALTESTING AND STARTUP TESTING

TOTAL SITE STAFFING FQR UNITS 1 AND 2

UNIT 2 SITE ORGANIZATION CHART - MAINTENANCE

TECHNICAL ORGANIZATION

UNIT 2 SITE ORGANIZATION CHART - TRAINING

CHEMISTRY AND RADIATIQNPROTECTION ORGANIZATION

OPERATOR TRAINING SCHEDULESRO PROGRAM COMPARISON TO NUREG-0737 APPENOIX CSAFETY REVIEW AND AUDIT OF OPERATIONSORGANIZATION

"AT THE CONTROLS" MAIN CONTROL ROOM

13-viii

Section

13.2.12.413 ~ 2. 12.513. 2. 12. 613.2. 13

13.2.13.113.2.14

13. 2. 14. 113.2.14.21'3.2.14.3

13.2. 1513.2. 15. 113.2.1613.2.1713.3

13. 413. 4. 113.4.213.4.2.113.4.2.213. 4. 3

13.513.5. 113.5. 1. 1

13.5. 1.213.5.1.313.5.1.313 '.1.313.5.1.313.5.1.3

.1

.2

.3~ 4

13.5. 1.313. S. 1. 313.5. 1.313.5. 1.313.5.2

.4.1

.5

.6e7

13.5 ~ 2. 113.5.2. 1. 1


CHAPTER 13

TABLE OF CONTENTS (Cont)

TitleRecordsOther Station EmployeesFire Protection StaffReserve Fire Brigade Trainingand Retraining (APN-10E)Training ProgramTraining of Nonlicensed Personnel(APN-10C)Professional PersonnelQuality Control PersonnelQuality Control Duties ofStation PersonnelTraining Program RecordsRecordsShift Technical Advisor TrainingApplicable NRC DocUmentationEMERGENCY PLAN

OPERATION REVIEW AND AUDITAdministrative ControlsSafety Review and Audit of OperationsSite Operations Review CommitteeSafety Review and Audit BoardAudit Program

PLANT PROCEDURESAdministrative ProceduresConformance with RegulatoryGuide 1.33Preparation of ProceduresAdministxative ProceduresStanding Operating OrdersSpecial Operating OrdersEcgxipment Control ProceduresControl of Maintenance andModificationModification Procedure ObjectivesMaster Surveillance Testing ScheduleProcedures for LogbookTemporary PxoceduresOperating and MaintenanceProceduresControl Room. Operating ProceduresGeneral Plant and System OperatingProcedures

Pacae

13.2-49c13.2-49c13.2-49d

13 . 2-5313.2-53

13.2-5413.2-5413.2-55

13.2-5513.2-5513.2-5513.2-5613.2-5613. 3-1

13. 4-113. 4-113. 4-113. 4-113.4-213.4-3

13 . 5-3.13. 5-1

13.5-113. 5-113.5-213.5-213.5»313.5-3

13. 5-313. 5-313. 5-3a13. 5-3a13. 5-4

13.5-413. 5-4

13.5-4

TABLE 13.2-2

SRO PROGRAM COMPARISON TO NUREG"0737

APPENDIX C

NUREG-0737, Appendix C SRO PROGRAM

6.2 Applied Pundamentals(120 hxs)Plant Specific Rx TechnologyChemistry 4 Corrosion ControlI5CPlant MaterialsPlant Thermal Cycle

Reactor TheorySimulator WeekPlant Systems TxainingPlant Systems TrainingThexmodynamics

80 hours~ 8 hours40 hours

4 hours40 hours

172 hours

6. 3 Man'agement/Supervisory Skills(40 houx's)LeadershipInterpersonal CommunicationMotivation of PersonnelProblem 5 Decisional AnalysisStressHuman BehaviorCommand Responsibilities 4

Lxmf.ts

Admin Procedures,Controls 4 Limitations(Leadership Training)(Procedural Training)

24 hours

16 hours

40 houx's

6.4 Plant Systems (200 hours) Plant Systems Training 200 hours

6.$ Administrative Controls(80 hours) Simulatox Training

Admin Procedures, Controlsand Limitations

25 hours40 hours

65 ours

6.6 General Operating Procedures(30 hours) Simulator Training 30 hours.

6. 7 Tx ansientlAccident Analysis(30 hours)

Simulatox Training 30 hours

6.8 Simulator Training Simulator Training 120 hours

* This table is typical of each training class,, however, the actual hours mayvary by + 20 percent based upon the qualifications and experience of thetraining class.

'lL 7

7

F.S.A.R. Changes to Chapter 13.2

13.2.1.2 Administration of Training Pr ograms

All instructors teaching the licensed training and retrainingprograms in the subjects of systems, integrated responses. transientsand simulator courses shall demonstrate senior reactor operatorqualifications and be enrolled in appropriate requalification programs.Other members of the permanent or non-permanent training staff, who areresponsible for teaching technical subjects, such as reactor theory,heat transfer, fluid mechanics, thermodynamics, health physics,chemistry and instrumentation are exempt from the senior reactoroperator criteria. Guest lecturers who are considered subject matterexperts, who are to be used on a limited basis, are also exempt fromthe Senior Reactor Operator Criterion but shall be monitored by aqualified instructor.

l, '7~ ~


NINE MILE POINT UNIT 2 RESPONSE TO TMI REQUIREMENTS

I.A.1. 1 SHIFT TECHNICAL ADVISOR

FSAR Cross.'Reference

Sections 13.1, 13.2.2

NUREG-0737 Position

Each licensee shall provide an on-shift Technical Advisor tothe Shift Supervisor. The Shift Technical Advisor (STA) mayserve more than one unit at a multiunit site if qualified toperform the advisor function for the various units.

The STA shall have a bachelor's degree or equivalent in ascientific or engineering discipline and have receivedspecific training in the response and analysi:s of the plantfor transients and accidents. The STA shall also receivetraining in plant design and layout, including thecapabilities of instrumentation and controls'n the controlroom. The licensee shall assign normal duties to the STAsthat pertain to the engineering aspects of assuring safeoperations of the plant, including the review and evaluationof operating experience.

The need for the STA p'osition may be eliminated if thequalifications of the Shift Supervisors and Senior Operatorshave been upgraded and . the man-machine interface in thecontrol room has been acceptably upgraded. However, untillong-term improvements are attained, the need for an STAprogram will continue.The NRC staff will establish the detailed elements of theacademic and training requirements of the STA at a laterdate. The level of upgrading required for licensedoperating personnel and the man-machine interface in thecontrol room acceptable for eliminating the need of an STAwill also be determined at a later date. Until theserequirements for eliminating the STA position have beenestablished, the staff continues to require that an STA beavailable for duty on each operating shift when a plant isbeing operated in Modes 1-3 for a BWR. At other times, anSTA is not required to be on duty.Since the accident at TMI several efforts have been made toestablish, for the long term, the minimum level ofexperience, education, and training for STAs. These effortsinclude work on the revision to ANS-3.1, work by the

1.10-5

'lt '1


Institute of Nuclear Power Operations (INPO), and internalstaff efforts.INPO has made available a document entitled Nuclear PowerPlant Shift Technical Advisor.--Recommendations for PositionDescription, Qualifications, Education and Training. A copyof Revision 0 of this document, dated April 30, 1980, isattached as a supplement to this task. Sections 5 and 6 ofthe INPO document describe the education, training, andexperience requirements for STAs. The NRC staff finds thatthe descriptions as set forth in Sections 5 and 6 ofRevision 0 to the INPO document are an acceptable approachfor the selection and training of personnel to staff the STApositions. The INPO document'provides 'interim guidance fora utility in planning its STA program over the long term.Applicants for operating licenses shall provide adescription of their STA training program and their plansfor requalification training on a schedule consistent withthe NRC licensing review schedule. This description shallindicate the level of training attained by STAs anddemonstrate conformance wi'th the qualification and trainingrequirements.

Applicants foroperating licenses shall provide adescription of the long-term STA program, includingqualification, selection criteria, training plans, andplans, if any, for the eventual phase-out of the STA programon a schedule consistent with the NRC licensing reviewschedule.

Nine Mile Point Unit 2 Position

The STA qualifications are shown on Table 13.1-4 and include a bachelor'degree or equivalent in a scientific or engineering descipline. Trainingrequirements are discussed in Section 13.2, and include soecific trainingin plant design and arrangement, and the capabilities of the instrumentsand controls in the control room. The STA's review and evaluate operatingexperience reports, including engineering'spects of assuring safesperations. During off-normal events, he provides the Station ShiftSupervisor with and assessment of station conditions and advises actionsto terminate or mitigate the consequences of off-normal conditions.During this time he shall perform no duties unrelated to assessment.or diagnosis.

1. 10-6

lC '1

~'

Nine Nile Point Unit 2 E'SAR

E.C.3 SHEET SUPERVISOR RESPONSEBEEETY

FSAR Cross Reference

Sections 13.1, 13.5.1

NUREG-0737 Position

The 'ighest level of corporate management of each licenseee,> gshall issue and periodically reissue a management directivethat emphasizes the pximary management responsibility of theShift Supervisor for safe operation of the plant under allconditions on his shift and that clearly establishes hiscommand duties.Plant procedures shall be reviewed to assure that the

'duties, responsibilities, and authority of the Shift'Supervisor and Control Room Operators are properly definedto effect the establishment of a definite Line of commandand clear delineation of the command decision authority ofthe Shift Supervisor in the contxol room relative to otherplant management pex sonnel. Particular emphasis shall beplaced on the following:

The responsibility and . authority of the ShiftSupervisor shall be to maintain, the broadestperspective of operational conditions affecting thesafety of the plant as a matter of highest priorityat all times when on duty in the control room. Theidea shall be reinforced that the Shift Supervisorshould not become totally involved in any singleoperation in times of emergency when multipleoperations are required in the contxol room.

.2- The - Shift. Supervisor, until properly relieved ofduty, shall remain in the control room at all timesduring accident situations to direct the activitiesof Control Room Operators. Persons authorized torelieve the Shift Supervisor shall be specified.

3. Ef the„Shift Supervisor is temporarily absent fromthe control. room during routine operations, a leadControl Room Operator shall be designated to assumethe control zoom command function. These temporaryduties, responsibilities, and the authority shallbe clearly specified.

Training programs. for Shift Supervisors shall emphasize andreinforce the responsibility for, safe operation and the


management function the Shift Supervisor is to provide forassuring safety.

The administrative duties of the Shift Supervisor shall bereviewed by the senior officer of each utility responsiblefor plant operations. Administrative functions that detractfrom or are subordinate to the management responsibility forassuring the safe operation of the plant shall be delegatedto other operations personnel not on duty in the control.room.

The following table clarifies this position:SHIFT SUPERVISOR RESPONSIBIK,ITY (2.2.1.a)

NUREG-0578 .PositionPosition No. Clarification

Highest level of corporatemanagement (1)

V. P. for operations

Periodically reissue (1)

Management direction (1)

Annual reinforcementof company policyFormal documentationof shi ft personnel,all plant management,copy to IE region

Properly defined (2.0)

Until properly relieved (2.8)

Temporari.ly absent (2.C)

Control room defined (2.C)

Defined in writing ina plant procedureFormal trans fer ofauthority, valid SROIicense, Recorded inplant log

Any absence

Includes shift super-visor office adjacentto the control room

Designated (2.C)

Clearly specified

In administrativeprocedures

Defined in administra-tive procedures

1.10-28

'1

'I


NUREG-0578 PositionPosition No. Clarification

SRO training

Administrative duties (4)

Administrative dutiesreviewed (4)

Specified in ANS 3.1(Draft) Section 5.2.1.S

= Not affecting plantsafety

On same interval asreinforcement: i.e.,annual. by V. P. foroperation

Nine Mile Point Unit 2 Position

The response to this task is contained in I.A.1.2.Refer to Task I.A.1.2„ position statement for response toE. C. 3'.

1. 10-29

b

~ I


I.A.1.2 SHIFT SUPERVISOR RESPQNSIBIIITIESFSAR Cross Reference

Sections 13.1, 13.5.1

NUREG-0737 Position

The highest level of corporate management of each licenseeshall issue and periodically reissue a management directivethat emphasizes the primary management responsibility of theShift Supervisor for safe operation of the plant under allconditions on his shift and that clearly establishes hiscommand duties.Plant procedures shall be reviewed to assure that theduties, responsibilities, and . authori ty of the ShiftSupervisor and Control Room Operators are properly definedto effect the establishment of a definite line of commandand c1ear delineation of the command decision authority ofthe Shift Supervisor in the control room relative to otherplant management personnel. Particular emphasis shall beplaced on the following:

The responsibi lity and authority of the ShiftSupervisor shall be to maintain the broadestperspective of operational conditions affecting thesafety of the plant as a matter of highest priorityat all times when on duty in the control room. Theidea shall, be reinforced that the Shift Supervisorshould not become totally involved in any singleoperation in times of emergency when multipleoperations are required in the control room.

2. The Shift'upervisor, until properly relieved,shall remain in the control room at all timesduring accident situations to direct the activitiesof Control Room- Operators. Persons authorized torelieve the Shift Supervisor sha'1 be specified..

3. If the Shift Supervisor is temporarily absent fromthe control room during routine operations, a leadcontrol room operator shall be designated to assumethe control room command function. These temporaryduties, responsibilities, and authorities shall beclearly specified.

Training programs for Shift Supervisors shall emphasize andreinforce the responsibility for saf e operation and the

1. 10-7

~ '1~ 1 '

Nine Mile Point Unit ". FSAR

management function of the Shift Supe visor is to proridefor assuring safety.The administrative duties of the Shift Supervisor shall bereviewed by the senior officer of each utility responsiblefor plant operations. Administrative functions that detractfrom or are subordinate to the management responsibility forassuring the safe operation of the plant shall be delegatedto other operations personneL not on duty in the controlroom.

The fo 1 lowingposition.

table provides clarification to the above

SHIFT SUPERVISOR RESPONSIBILITY (2.2.1.a)NUREG-0578 Position

Position No. ClarificationHighest. level of corporatemanagement (1)

Periodically reissue (1)

V. PE for operations

Annual reinforcementof company policy

Management direction (1) Formal documentation ofshift personnel, all .plant management,copy to IE region

Properly defined (2.0)

Until properly relieved (2.B)

Temporarily absent (2.C)

Control room defined (2.C)

Defined in writing ina plant procedureFormal transfer ofauthority, valid SROLicense, recordedin plant logAny absence

Includes shift super-visor office adjacentto control room

Designated (2.C) In administrativeprocedures

Clearly specified (Z.C) Defined in administ a-tive procedures

1 ~ 10-8

E~ ~ I

~ II ~ ~ 0


NUREG-OS78 PositionPosition No. Clarification

SRO training ( 3 )

Administrative duties (4)

Administrative duties.reviewed. (4.) +

Specified in ANS 3.1(Draft) Section,5.2.1.8

Not affecting plantsafety

On same interval asreinforcement: i.e.,annual by V. P. foroperations

4 ~

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NINE NILE POINT UNIT 2 POSITION

Prior to fuel loading and annually thereafter, the Vice President-NuclearGeneration shall issue a management directive that emphasizes. the primarymanagement responsibility of the Station Shift Supervisor (SSS) for safeoperation of the plant under all conditions on his shift and clearlyestablishes his command duties.

Plant procedures are written to assure that the duties, responsibilities andauthority of the SSS and other licensed control room operators are properlydefined to effect the chain of command.

In the future, administrative duties of the SSS will be reviewed annuallyafter fuel load by the Vice President-Nuclear Generation to ensure that suchfunctions don't detract from safe plant operation.

/

SSS RESPONSIBiLITIES

The Station Shift Supervisor is in charge of all operations on his assignedshift. Under the general direction of the Supervisor Operations Nuclear, hi.s

'unctionincludes direction of shift activities, authorization of equipmentreleases for maintenance, ensuring that the plant is operated safely andwithin the license and technical specifications and ensuring that plantoperations are conducted in accordance with approved procedures. As. overallsupervisor of operations for his shift, the Station Shift Supervisor shouldavoid becoming personally involved in the manipulative tasks or details ofoperati'on of any one portion of the plant so that he may retain acomprehensive perspective of general station conditions at all times. In anemergency situation, however, should the Shift Supervisor choose to performmanipulative functions to ensure that the plant is in a safe condition, he.shall coordinate his actions with the Chief Shift Operator. Whenever hedetermines that the safety of the reactor is in immediate joepardy or whenoperating parameters exceed'ny of the reactor protection circuit setpointsand automatic shutdown should, but does not occur, he has the responsibilityand the authority to order shutdown of the reactor or to personally effect theshutdown.

The Shift Supervisor shall hold an NRC senior reactor operator l.icense. Heshall be continuously present at the plant for the duration of his assignedshift until properly relieved by the oncoming Shift Supervisor". It is hisresponsibility to provide direction for returning the reactor to powerfollowing a trip or an unscheduled power reduction.

Ouring (normal operations) periods when the SSS is out of the control room, hedesignates another SRO the control room command function, as specified byadministrative procedures.

Ouring emergencies, accidents or incidents requiring special procedures, theShift Supervisor shall remain continuously in the control room until relievedby the oncoming shift supervisor or a senior licensed operator designated bythe Supervisot Operations or higher authority. From the control room, heshall continuously assess the condition of the station and provide generaldirection for all operating actions.

„Tr aining programs for SROs reinforce the responsibility for safe operation andthe management function of the control room supervisor to assure safety.

SSS administrative duties have been reviewed, and many of the administrativefunctions have been assigned to other personnel.

k

~ ' 1~ ~

Nine Mile Point Unit. 2 FSAR

I.B.1.2 INDEPENDENT SAFETY ENGINEERING GROUPFSAR Cross Reference

Sections 13.1.1, 13.4

NUREG-0737 Position

Each applicant for an operating license shall establish anonsite independent safety engineering group (ISEG) toperform independent reviews. of plant operations.The principal function of the ISEG is to examine plantoperating characteristics, NRC issuances, LicensingInformation Service advisories, and other appropriatesources of plant design and operating experience informationthat may indicate areas for improving plant safety. TheISEG is to perform independent review and audits of plantactivities, including maintenance, modifications,operational problems, and operational analysis and to aid inthe establishment of programmatic . requirements for plantactivities. Nhere useful improvements can be achieved, itis expected that this group will develop and presentdetailed recommendations to corporate management for such.things as revised procedures or equipment modifications.

Another function of the ISEG is to. maintain surveillance ofplant operations and maintenance activities 'o provideindependent verification that these activities are performedcorrectly and that human errors are, reduced as far aspracticable. ISEG will then be in a positi.on to adviseutility management on the overall quality and safety ofoperations. ISEG need not perform detailed audits of plantoperations and shall not be responsible for signofffunctions such that it becomes involved in the operatingorganization.The new ISEG shall not replace the plant operations reviewcommittee (PORC) and the utility's independent review andaudit group as . specified by current staff quidelines(Standard Review Plan, Regulatory Guide 1.33, StandardTechnical Specifications). ~ Rather, it is an additionalindependent group of a minimum of five dedicated, full-timeengineers, located onsite but reporting offsite to acorporate official who holds a high level,technically-oriented position that is not in the managementchain for power production. The ISEG will increase theavailable technical expertise located onsite and willprovide continuing, systematic, and independent assessmentof -plant activities. Integrating the Shift Technical

\ 7~ ~ 1

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Advisors (STAs) into the ISEG in some way would be desirablein that't could enhance the group's contact with theknowledge of day-to-day plant operations to provideadditional expertise. However, the STA on shift isnecessarily a member of the operating staff and cannot beindependent of it.It is expected that the ISEG may interface with the qualityassurance (QA) cjrganization, but preferably should not be anintegral part of~ the QA organization.The functions of the ISEG require daily contact 'with theoperating personnel and continued access to plant facilitiesand records. The ISEG review functions can therefore bestbe carried out by a group physically located onsite;However, for utilities with multiple sites, it may bepossible to perform portions of the independent safetyassessment function in a centralized location for all theutility's plants. In such cases, an onsite group still isrequired, but it may be slightly smaller than would be thecase if it were performing the entire independent safetyassessment function. Such cases will be reviewed on acase-by-case basis.

At this time, the requirement for establishing an ISEG isbeing applied only to applicants for operating licenses inaccordance with Task I.B. 1.2. The staff intends to reviewthis, activity in about a year to determine its effectivenessand to see whether changes are required. Applicability to

„operating plants will be considered in, implementinglong-'term improvements in organization and management foroperating plants (Task I.B. 1 ~ 1) .Nine Mile Point Unit 2 Position

An onsite ISEG will be established to perform independent reviews of plantoperation. The principal function of the ISEG is to examine plant operatingcharacteristics, various NRC and industry licensing and service advisories,and recommend ones for improving plant operations or safety. The ISEG willperform independent review of plant activities, including maintenance,modifications, operational concerns, and operational analysis and makerecommendations to the Supervisor Technical Support Nuclear. The SupervisorTechnical Support Nuclear (or his designee) will present to OperationsAssessment Committee (OAC) and/or the Technical Superintendent the results ofanalysis including (when useful improvements can be achieved) detailedrecommendations such as revised procedures or equipment modifications.Presentations to SORC are provided by the Operations Assessment Committeedescribed in Section 13.4.

The ISEG will observe plant operations and maintenance activities to'etermine that these activities are being performed properly and providewritten recommendations (when useful improvements can be achieved). The ISEGdoes not perform detailed (gA type) audits, and are not responsible forsignoff functions associated with daily operational activities. The ISEG isindependent of SORC and SRAB but may make recommendations to these groups.

1.10-19

Nine Mile Point Unit 2

The ISEG is a total of ten dedicated full-time engineers, assigned onsiteto Unit 1 and Unit 2, and report to the Supervisor Technical Support Nuclear.The Supervisor Technical Support Nuclear reports to the SuperintendentTechnical Services Nuclear and then reports to the Technical Superintendentwho is responsible for all technical support on site.

Although the Technical Department reports to the General SuperintendentNuclear Generation (who is responsible for operations), the TechnicalDepartment is independent from the direct operational supervision of the plantthat resides with the Station Superintendent. Additionally, the TechnicalDepartment has recourse to resolve safety concerns by addressing such concernsto either the SRAB or the Vice President Nuclear Engineering and Licensing.

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TECHNICALORGANIZATION

NIAGARA MOHAWK POWER CORPORATIONNINE MILE POINT-UNIT 2FINAL SAFETY ANALYSIS REPORT

~ ~ I

IS


I.C".2 SHRIFT AND RELIEF TURNER PROCEDURES


Section 13.5.1

NUREG-0737 Position

The licensees shall review and" revise as necessary the plantprocedure for shift and relief turnover to - assure thefollowing:

A checklist shall be provided for the oncoming andoffgoing. Control Room Gperators and the oncomingShift Supervisor to compLete and sign. ThefoLLowing items., as a minimum, shaLL be included inthe checklist:a. Assurance that critical plant parameters are

within 'llowable limits (parameters andaLlowable limits shall be listed . on. thechecklist).

b.

Co

Assurance of t@e availability and properalignment of all, systems essential to theprevention and mitigation of operationaltransients and accidents by a check of thecontrol console (what to check and criteriafor acceptable status. shall be included in thechecklist) .Zdentifica&oi"of." systems and, components thatare in) a. degraded- 'made of .operation permittedby.'he- Technical Specifications. For suchsystems and components, the length of time inthe "'degraded mode. shall be compared..with, theTechnical Specifications action statement(this shalL be recorded as a separate entry onthe checklist)'.

Checklists. or logs. shaLL be provided for completionby the offgoing ancL-ongoing auxiliary operators andtechnicians. Such checklists or logs shall includeany equipment under maintenance or test'hat byitself could. degrade. a system critical to theprevention and mitigation of operational transientsand accidents or initiate an'perational transient(what.to check and criteria for acceptable statusshaLL be included on the. checklist).

L.L0-.25

0 I 4a~ ~

7 I~ ~ ~

Nine Mile Point Unit 2 E'SAR

3. A system 'shall be established to evaluate theeffectiveness of the shift -.and relief turnover,procedure.

Nine Nile Point Unit 2 Position

The'nit 2 (shift relief turnover) procedures 'will include:

l. A checklist providing for the oncoming and offgoing Control Room Operatorsand the- oncoming. Shift Supervisor to complete and sign. The followingitems, as a minimum, shall be included in.the checklist:

a.

b.

Assurance that critical plant parameters are within allowable limits(parameters and allowable limits shall. be listed on the checklist).

Assurance of the availability and proper alignment of all systemsessential to the prevention and mitigation of operational transientsand accidents by a check of the control console (what to check andcriteria for acceptable status shall be included, in the checklist).

c. Identification of systems and components that are in a off normal orout of service mode of operation permitted by the TechnicalSpecifications. For such systems and,components, the length of timein. the off'normal or out of service mode shall be compared with theTechnical Specifictions action statement;(if any). (This shall berecorded as a separate entry on the checklist.)

2. Checklists or logs shall be provided for completion by the offgoing andongoing operators. Such checklists or logs shall include any equipmentunder maintenance or test that by itself could degrade a system criticalto the prevention and mitigation of operational transients and accidentsor initiate an operational transients and accidents or initiate anoperational transient (what to check and criteria for acceptable statusshall be included on the checklist).

3. A system shall be established to evaluate the effectiveness of the shiftand relief turnover procedure.

1.10-26

Nine Nile Point Unit 2 FSAR

E.C.4 CONTROE ROON ACCESS


Section 13.5.3.

NUREG-0737 Position

The licensee shall make provisions for limiting access tothe control room to those individuals responsibl'e for thedirect operation of the nuclear power plant (e.g.,Operations Supervisor, Shift Supervisor, and Control RoomOperators}, to technical advisors who may be requested orrecpxired to support. the operation, and to predesignated NRCpersonnel. Provisions shall include the following:

1. , Develop and implement an administrative procedurethat:establishes . the authority and responsibilityof the person in charge of the control room to

. limit access, andDevelop and implement procedures that establish aclear 1'ne of authority and responsibility in the.control room in the event of an emergency. Theline of succession for the person in charge of thecont ol room 'hall 'be established and limited topersons possessing a current senior reactoroperator's license. The plan shall clearly definethe

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Nxne Nx].e Poxnt Unxt 2 FSAR

I.C.S PROCEDURES FOR FEEDBACK OF OPERATING EXPERIENCETO PLANT STAFF


Section 13.5.1

NUREG-0737 Position

In accordance with Task Z.C.S, Procedures for Feedback ofOperating Experience to Plant Staff (NUREG-.0660), eachapp canlicant for an operating license shall prepare proceduresto assure that operating information pertinent to plansafety originating both within and outsf de the utilityorganization is continually supplied to operators and otherpersonneersonnel and is incorporated into training and retrainingprograms. These procedures shall:

1. Clearly identi'fy organizational 'esponsibilitiesfor review of operating experience, the feedbackof'ertinentinformation to operators and other

personnel, and the incorporation of suchinformation into training and retraining programs;

2. Identify the administrative and technical reviewsteps necessary in translating recommendations bythe operating experiehce assessment group intoplant actions (e.g., changes to procedures,6perating orders);

3.

S.

Identify the recipients of various categories ofinformation from operating experience (i.e.,supervisory. personnel, st.ft technical advisors,oper'ators, maintenance personnel, health, physicstechnicians) or otherwise provide means throughwhich such information can be raadil.y related tothe gob functions of the recipients;Provide means to assure that affected personnelbecome aware. of and understand information ofsufficient importance that ..it should not wait -foremphasis through routin'e training and retrainingprograms g

Assur e that plant personnel. do not. routinely'receive extraneous and unimportant'nformation onoperating experience in such volume that it wouldobscure priority information or otherwise. detractfrom overall job performance and proficiency;


6. Provide suitable checks to assure that conflictingor contradictory information is hot conveyed tooperators and other personnel until resolution. isreached; and,

7. Provide periodic internal audit to assure that thefeedback program functions effectiveLy at alllevels.

Each utility shall carry out an operating experienceassessment function that viLL involve utility personnelhaving collective competence in all areas important to plantsafety. In connection vith this assessment function, it isimportant that procedures exist to assure that importantinformation on operating experience originating both withinand outside the organization is continualLy provided tooperators and other, personnel and,:that it is incorporatedinto plant operating procedures aad'training and retrainingprograms.

Those involved in the assessment of operatiag experiencevill review information from a variety of sources. Theseinclude operating information from the licensee's ownplant(s), publications such as ZE Bulletins, Circulars, andNotices, and pertinent NRC or industrial assessmeats ofoperating experience. Ia some cases, information may be ofsufficient importance that it must. be dealt with promptly(through instructions, changes to operating and emergencyprocedures, i/suance of special precautions, etc) and mustbe handled in such a manner to assure that operationsmanagement personnel would be directly involved in theprocess. In many other cases, however, importantinformation vill'ecome available which should be brought tothe atteation of operators and other persoanel. for theirgeneral information to assure continued saf e plantoperation.

Since the total volume of information handled by theassessment group may be, Large, it is important thatass'urance be provided that high priority matters are dealtwith promptly and that discrimination is used, in thefeedback of other information so that personnel are notdeluged with uaimportant and extraneous information. to thedetriment of their overall proficiency- It is important.also, that technical reviews be conducted to precludepremature dissemination of conflicting or contradictoryinfo rmation.

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Nine Mile Point Unit 2 CESAR

Nine ile Point Unit 2 PositionUnit 2 will utilize Administrative Procedures and Training Procedures to

implement the feedback of operating experience to plant staff. The procedures:1. Clearly identify organizational responsibi lities for review of

operating experience, the feedback of pertinent information tooperators, and other personnel, and the incorporation of suchinformation in training and requalification training programs (forexample see Section 13.2.4.1.1 item 9).

2. Identify the administrative and technical review steps necessary intranslating recommendations by the Operations Assessment Coneitteeinto plant actions (e.g. changes to procedures, operating orders).Section 13.4 and l. 10 provide information on the OperationsAssessment Committee.

3. Identify the recipients of various .categories of information fromoper ating experience (i.e. shift or supervisor, personnel)" orotherwise provides means through which such information can bereadily. related to the job functions of the recipients (for examplesee Section 13.2.4.1.3).

4. Provide means to assure that affected personnel become aware of andunderstand information of sufficient importance that it should notwait for emphasis through routine training and retraining or standingorders or night orders (for example required reading assignments aremade on an ongoing basis to address this concern).

5. Assure that plant personnel do not routinely receive extraneousinformation on operating experiences in such volume that it couldobscure priority information.

6. Provide suitable checks to assure correct information is conveyed tooperators and other personnel.

7. Provide periodic audits to assure that the feedback program functionseffectively (for example Training Audits).

Operating experience assessment is performed by the Technical SupportGroup, the Operations Assessment Coranittee and SORC as described inAdministrative Procedures on an ongoing basis. The individuals involvedreview information from a variety of sources such as, IE Bulletins, IEInformation Notices, IMPO, reports, LER's, and vendor information letters suchas SILS.

The feedback system provides for early notification of significantinformation to operating personnel and management. The evaluation process,specifically the Operations Assessment Committee meeting, provides assurance

:.that the information is correct and that unimportant and extraneousinformation does not impact overall proficiency.

1. 10-33

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NINE HILE POINT UNIT 2

SER NO. 1675.2.2

. We require the applicant to discuss in detail the analytical method usedto determine the number of the AOS SRVs. This method should'considerthe most limiting events and satisfy a single failure criterion.

RESPONSE

In a LOCA analysis, a particular AOS flow rate is required to bring thevessel pressure down in a prescribed time to allow the operation of lowpressure core cooling following the postulated failure of HPCS. Thisrequired flow rate determines the number of AOS valves. Based on

':generic BWR calculations including that of Hanford, 7 AOS valves arerequired for NHP2. This number will be confirmed by NHP2 .unique ECCSanalysis.

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SER QUESTION 170:

The LOCA analyses reported in the FSAR were for a lead plant representative ofHHP-2. The applicant has committed to perform plant-specific LOCA analyses ina later amendment to the FSAR before fuelloading. The NRC staff will report the results of its review of the plant-specific analyses in a supplement to this report.

SER QUESTION 171:

The staff requires the appl,icant to provide calculated maximum total hydrogengeneration from the chemical reaction of the cladding with water orsteam for the most limiting LOCA case.

RESPONSE:

Information for SER items 170 and 171 will be provided by April 1985.

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NINE MILE POINT UNIT 2

SER NO. 172

Single active component failures and operator errors are considered in thetransient analysis of moderate frequency. The most limiting transient event isa feedwater controller failure with maximum demand with the failure of turbinebypass. The change in CPR is, about 0.27 for an fnitial HCPR of 1.24 whichresults in violation of MCPR safety limit of 1.06. The applicant has statedthat this transient event is one of only 2 to 3 seconds duration: no

fuel'ailurewould be expected. The staff requires, that the applicant demonstratehow they meet a small fraction of 10 CFR 100 criteria violating OL MCPR limit.The applicant should also demonstrate the method used to identify this eventwhen all moderate frequency transients combined with single failure/operatorerror are considered in the evaluation.

RESPONSE

As stated in the response to guestion 440.41, for moderate-frequency events in. Chapter 15, the i'nclusion of any additional single failure or operator errorwould shift the events to infrequent or limiting fault category which has lessstringent safety criteria.

Resporises to questions 440.41 and 440.43 have identified that:

The worst additional single failure/operator error. is the postulatedfailure of turbine bypass, and

2) Among all moderate".frequency transients coupled with turbine bypassfailure, the most limiting event is feedwater controller failure withmaximum demand.

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In this scenario, the final.CPR would violate the.l.06 safety limit for aduration of 2 to 3 seconds.':Consequently, about.2X of fuel rods will undergoboiling transition for 2 to 3 seconds with corresponding peak;clad temperatures(PCT)below 1600 F. Since boiling transition would have to last for much longertnan 30 seconds before PCT approaches the safety limit of 2200 F, no fuelfailure or radiological release is expected. Therefore, the requirement ofmeeting "a small'raction of 10CFR100 limit" is satisified.

NINE MILE POINT UNIT 2

SER. NO. 173

The applicant was asked to justify that operation with partial feedwaterheating to extend the cycle beyond the normal end of cycle condition would notresult in a more limiting change in minimum critical power ratio than thatobtained using, the assumption of normal feedwater heating. The applicant, .indicated that analyses will be provided before operation in this mode if adecision is made to operate in this mode. Until such analyses are provided thestaff will condition the license to prohibit operation in this mode.

RESPONSE

Operating with reduced feedwater temperature after rated end of cycle is notthe design basis of the plant safety analysis. Although it is expected thatcurrent Chapter 15 analyses will bound this operation under a derated feedwaterheating condition, Niagara Mohawk will submit additional'analysis to accompanythe request for this mode of operation. This commitment has been made inresponse to question 440.46.

OPEN ISSUE 175

II.K.3.18 Modification of ADS Lo ic

NMPC is currently evaluating this item. The staff will require'.thatNMP2 should specify which option they are planning to implement.Either Option 2 or 4 is acceptable to the staff.

RESPONSE

Nine Mile Point Unit 2 will implement Option 2. FSAR Section 1.10will be revised to address this commitment.

1


Exem tion Justi ficati on (10CFR50 'Appendix J., Part I I I, A. l. d)1. Systems that are required to maintain the plant 'n

a safe condition during the test shall be operablein their normal mode and need not be vented.

2. Systems that are normally filled wi th water andoperating under post accident conditions need notbe vented.

The control rod drive and hydraulic control for the reactorrecirculation flow control valves'will not,be vented duringthe ILRT as justified by Notes 1'7 and 26 of Table 6.2-56,respectively.The test method utilized is the absolute method, as described in8N-TOP-l, Rev. 1, 1972. Values of primary containment atmospheredry-bulb temperature, dew point temperature (vapor pressure), andpressure are used in the leakage rate calculations.

The primary containment leakage monitoring system (LMS)provides means for monitoring the primary 'containment pres-sure during ILRT. Two independent, pressure sensing lines,each equipped with a quartz. digital type 'bsolute pressuremanometer, are provided in LMS system. One extra quartzmanometer is provided as a not-installed spare(Figure 6.2-73).

Eighteen temperature elements and six humidity analyzers areprovided in. the primary containment atmosphere monitoringsystem (CMS) to monitor dry-bulb and dew point temperatures,respectively (Figure 6.2-71).

The test procedure, test equipment and facilities, period of testing,and verification of leak test accuracy follow the recommendations ofgN-TOP-1, Rev. 1, 1972.

Acceptance criteriaChapter 16.

for a Type A tests are descr'bed in

6. 2.-86

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6 2.6.3 Primary Containment Isolation Valve Leakage RateTests (Type C Tests)

Primary con ainment nment isolation valve leakage rate tests willbe performed by local pressurization in accordance with the

" requirements of Appendix J to 10CFR50. The pressure will be applied inthe same direction as it would be applied when the valve is required anddocumented that the results from the test for a pressure applied in theopposite direction will provide equivalent or more conservative results.Each valve to be tested'ill be closed by normal operation, without anypreliminary exercisinq or adjustment. Table 6.2-56 lists all primarycontainment isolation valves on pipelines penetrating the primarycontainment.

The test pressures and acceptance criteria for the primarycontainment isolation valve leakage rate tests are given inTable 6.2-60.

6.2.6.4 Additional Requirements

The combined leakage rate forall penetrations and valves subject toType B and C tests will be in accordance with 10CFR50 App'endix J.

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6.2.6.5 Scheduling and Reporting of Periodic Tests

The periodic leakage test schedule is given in Chapter 16.

6.2.6.6 Special Testing Requirementsh

The reactor building will be tested as required by Chapter 16.

A peroperational high pressure drywell bypass leakage test will beperformed once prior to fuel load to determine the bypass leakage fromthe drywell into the suppression chamber. The containment will besubjected to the maximum design pressure differential of 25 psi betweenthe drywell and suppression chamber.

The test pressures and acceptance criteria for the drywell bypassleakage tests are given in Table 6.2-61.

6.2-88

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vs˜ nine mile ili unit e · 2018. 2. 6. · y niagara u mohawk niagaramohawkpower corporation/300...

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