ML20010J629

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Forwards Info Re Organizational Structure & Qualifications, in Response to NRC Concerns Expressed at 810902-04 Audit at Util Ofcs.Operator Guidelines & Draft Procedure STA 615 Re Staff Work Hours Encl
ML20010J629
Person / Time
Site: Comanche Peak  Luminant icon.png
Issue date: 09/29/1981
From: Clements B
TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC)
To: Harold Denton
Office of Nuclear Reactor Regulation
Shared Package
ML20010J630 List:
References
TXX-3411, NUDOCS 8110060294
Download: ML20010J629 (20)
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TEXAS UTil.lTIES GENERATING COMinNY ' Log # TXX-3411 , ,

=>umvas uno:n su.am- m.ii File # 913 y .v auv a cymcws September 29, 1981 Mr. Harold R. Llenton, Director 41 Office of Nuclear Reactor Regulation Y U. S. Nuclear Regulatory Commission Washington, D.C. 20555 g[l([ f[fV >

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SUBJECT:

COMANCHE PEAK STUG ELECTRIC STATION DOCKET i40S. 50 445 ANb 50-446 hi s

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DOCUMENTATION OF ITEMS DISCt)SSED DURING SEPTEMBER 2 - 4, 1981 AUDIT TEAM VISIT

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Dear Mr. Denton:

On September 2 - 4, 1981 an NRC audit team visited our of fices to explore items of concern and to confirm staff findings as stated in the Comanche Peak SER with respact to organiidtignal structure and qualifications. Enclosed is documentation of certain items discussed during this visit.

Please let us know if you require any additional information on this matter.

\

Sincereiy, _

.L/ l D >"

BRC: tis Enclosures ,

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8110060294 810929^ '

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\,- Enclosure to TXX-3411

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$V, b 1.A.},2 Shift Supervisor Administrative' Duties a ,

,w s A list of administrative duties bf the' Shift Supervisor will be

, provided to the Vice President, Nuclear, for review prior to fuel load. ' Administrative functions that detrac: from or are subordinate to the management responsibility for ensuring the safe operation of the plant shall be delegated to other operations personnel with no control room operating duties. I Auxiliary Operators and clerical pusonnel will assume these functions.

1.A.1.3 Shift Manning A Shift Technical Advisor (during Modes 1, 2, 3 & 4), a Communicator (member of the Shift Operating Organization), and two Radiation Protection Tephnicians (one qualified to initiate the post-accident sampDng 67,d u.alysis process) will be assigned to each shift.

3 .

Restrictions on the use of overtime, previously discussed in ODA-302,

" Relief of Perso.1nel and Overtime Restrictions", are now incorporated A, ' in Procedure STAsbl5, " Staff Work Hours", a copy of which is attached

\,4, for your review. - +

y.m 1.C.2 Shift Relief My Turid/pr Procedures s (

The checksheet for Auxiliary Operators, as discussed in ODA-302,

" Relief of Personnel", has not been completely developed. However, the precursor to that checklist, " Operator Guidelines", is attached for your review. .

A.

1.C.5 Procedures for Fhedback of Operating Experience to Plant Staff The Operations.hpport Superintendent is responsible for dissemination of all. pert'nent operating experience infonnatioa received from industry cources.5 2ncluded is the INP0 information received from the

. SEE-IP. program which,is disseminated per procedure NOA-XXX (to be

' numbered later).. Other procedures will be developed to handle other es/ 50urces ofMnformation such as NRC bulletins and orders, NRC information notices, and'tne many other sources of industry operating experience information. Procedures will also be developed which ensure that N operating experiences reported onsite, including all licenses event s reports are reviewed by operations support section personnel (STA's)

_ and routed to the appropriate departments including the training department.

13.1.2.1 Plant Staff One operator with at least one year of PWR operating experience will be available on each shift until the plant reaches the maximum licensed power level.

13.4.3 Independent Safety Engineering Group The Independent Safety Engineering Group (ISEG) reporting to the Operations Support Engineer will consist of five engineers with experience in the areas of electrical, mechanical, and nuclear engineering. The Operations Support Engineer, Mr. M. J. Riggs',

resume is attached. At this time, no individuals have been hired to fi el positions as ISEG members. We are proceeding imediately to staff the ISEG with the most qualified individuals available. We will cequire a minimum of three years engineering experience for all individuals at the time they are assigned to the ISEG and will imediately involve them in the design, construction, preoperational testing and initial startup of CPSES to maximize their nuclear power plant experience. This program will ensure that when the ISEG is fully implemented 90 days prior to fuel load, the ISEG members are qualified to carry out their responsibility to improve the overall quality and safety of operations.

TMI-2 Requirements 1.A.1.1. Shift Technical Advisor The Operations Support Engin'eer will provide Shift Technical Advisors to each operating shift in support of the shift supervisor. These Shift Technical Advisors (STAS) will meet the education, experience and training requirements of NUREG-0737, October 31, 1980, Appendix C

" Nuclear Power Plant Shift Technical Advisor". Staffing of these positions began in the Spring of 1981. Presently, there are four Shift Technical Advisors at CPSES. Their resumes are attached.

This initial group of STAS will begin training in October,1981. This training will be conducted by Westinghouse Electric Corporation and by CPSES training personnel and exceeds the requirements of NUREG-0737.

Other groups of STAS will attend similar training programs prior to fuel load of Unit 1.

The necGsary experience required for STAS by NUREG-0737 will be gained by involving these personnel in preoperational and startup testing activities and in design and construction engineering activities at CPSES. At the time of initial fuel load of Unit 1, the necessary number of qualified STAS will be availabic to support the operation of CPSES.

e Operating experience information that is internally generated will be renorted as directed in Procedure ODA-107, " Reporting of Operational Incidents", a copy of which is attached. This report will then be routed to appropriate personnel for their review in accordance with ODA-106, " Review of Documents", a copy of which has been previously transmitted.

The Operations Engineer is responsible for maintaining thorough familiarity with daily station operating activities (ODA-101,

" Operations Department Organization and Responsbilities", Sections 4.2.1, 4.2.2 and 4.2.6, attached). This daily contact with shift operating personnel and Operation Department staff meetings that occur approximately weekly are the primary vehicles for oral dissemination of important information that is not routed as directed in ODA-106.

O Michae1. J. Riggs - Operations' Support Enginecr Education:

i B.S. Nucle.ar Engineering - Texas A&M University - May 1974 General Electric Company Field Engineering Development ; enter, Schenectady, New York - June - October 1974 Large S;eam Curbine Generator Course (6 weeks)

Boiling Water Reactor Technology Course (6 weeks)

General Electric Boiling Heter Reactor Train Center, Morris, Illicois - April - July 1975 Reactor Operator Certification Course (12 weeks)

Instructor Training Course (2 weeks)

Irperience:

Octohar 1974 - April 1975:

Employed by General Electric Company assigned to Brunswick Steam Electric Plant startup group for initial training. Assisted in Rad-waste systems construction and startup. Prsoperationally tested several Radwaste processing systems and seismic monitoring systems.

Assistant G.E. Operational Shift Supervisor for Reactor Initial Operation Testing.

July 1975 - January 1976:

Employed by General Electric Compant, assigned to General 31ectric BWR Training Center as instructor. Taught utility company operators BWR operations and control of all BWR systems. Developed material and lesson plans for specific BWR plant training courses and for GE nee instructors internal training course.

Februarv 1976 - Junc 1978:

Employed by General Electric Company assigned to E. I. Hatch Nuclear Generating Plant startup group. Wrote large percentage of Plant Operating Procedures, including: systems operation instruction, emer-l gency procedures, calibration and maintenance procedures, functional

! and surveillance testing procedures and annunciator response procedures.

l Wrote and reviewed Preoperational Test Procedures. Reviewed Reactor i Startup Test Instructions. Assigned as Preoperational Test Supervisor for Reactor Protection System, Primary Containment Isolation System and Main Generator and Auxiliary Systems; responsible for those system's assembly, deficiencies, construction, acceptance testing, functional testing, preoperational test / testing and support documents. GE Operations Shift Supervisor for Reactor Vessel Hydro and for Recire Pump Vibration Testing. Training Instructor for GE Shift Supervisor Certification course.

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Michael J. Riggs - Page 2 June 1978 - December 1980:

Employed by Texas Utilities Generating Company assigned to Comanche Peak Steam Electric Station startup group. - Initiated Hydraulic Mbdel

! Test Plan for Containment Recirculation Sump flow verifications. Assign-ed es Startup Test Engineer for station battery /DC distribution systems and for all main turbine and generator systems. As turbine / generator coordinator, responsibilities included construction and startup schedul-ing, installation verification and system testing.

January 1981 - September 1981:

Employed by Texas Utilities Generating Company assigned as Electrical Prerequisite Test Coordinator responsible for technical di.rection of startup test electricians, electrical support manpower assignments and projections and develepoent cf backlog testing to include most plant 6.CK7 large motors.

October 1, 1981:

Employed by TUGC0 in the pcsition of Operati
ans' Support Engineer responsible for Shift Technical Advisors and for Independent Safety l Engineering Group.

Certifications:

GE Senior Reactor Operator Certification on Dresden Station Units 2 & 3 -

July 1975 GE Senior Reactor Operator Certification on E.I. Hatch Plant Units 1 & 2 - May 1978 Professional Affiliations:

None l

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SHIFT TECHNICAL ADVISOR RESUMES J. B. McINVALE - Shift Technical Advisor Education:

B.S.N.E. - Georgia Inst':ute of Technology -1981 Experience:

1981 - Employed by the Texas Utilities d"en'erating Company as Engineer (Operations Support).

W. L. STENDEBACH - Shift Technical Advisor Educacion:

B.S.N.E. - Texas A&M University - 1981 Experience:

1980 - Employed by Central Power and Light Company at the Barney 11.

Davis Power Plant as a maintenance helper.

1980 - Employed by Texas A&M University at the Radiological Safety Office engaged in radiation surveying and radioactive waste management.

1981 - Employed by the Texas Utilities Generating Company as Shift Technical Advisor m _

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SHIFT TECHNICAL ADVISOR RESUMES Page 2 M. W. SUNSERI - Shift Technical Advisor Education:

B.S.N.E. - Texas A&M University - 1981 Experience:

1981 - Employed by the Texas Utilities Generating Company as Shift Technical alvisor.

M. D. PALMER - Shift Technical Advisor Educatica:

l B.S.M.E. - Texas Technological University - 1981 1

Experience:

1978 - Employed by Standard Oil of Indiana as engineering trainee.

1979 - Employed by Texas Electric Service Company at Morgan Creek Steam Electric Station.

1981 - Employed by Texas Utilities Generating Company at Comanche Peak Steam Electric Station.

i

COMANCHE PEAK STEAM ELECTRIC STATION STATION ADMINISTRATION MANUAL i

1i w!L Vi Lv STAFF WORK HOURS PROCEDURE NO. STA - 615 BEVISION No. 0 SUBMITTED BY: DATE:

Administrative Supervisor APPROVED BY: DATE:

Menager, Plant Operations l

CPSES ISSUE DATE PROCEDURE NO.

STATION ADMINISTRATION !!ANUA1. STA-615 STAFF WORK HOURS REVISION NO. O PAGE 2 0F 3 1.0 Purpose The purpose of this procedure is to establish a sound policy covering working hours for plant staff who perform safety related functions.

2.0 Applicability This procedure applies to plant staff who perform safety related functions (e.g., senior reactor operators, reactor operators, health physicists, auxiliary operators, 1 & C Technicians,; key maintenance personnel, etc.). This procedure becomes effective when determined '

appropriate by the Manager, Plant Operations.

3.0 Definitions ~

None 4.0 Instructions

. 4.1 Overtime Limitations 4.1.1 Overtise shall not be routinely scheduled to compensate for an inadequate number. of personnel te meet the shif t .

erew staffing requirements. ilowever, du> to unanticipated

" 'or unavoidable circumstances, personnel say be required to work overtime to comply with the shif t crew staffing requirements. in the event that overtime must ce used (excluding extended periods of shutdown for refueling, major maintenance or major plant modifications), che following overtime limitations for plant staff performing safety related functions shall be followed:

4.1.1.1 An individual shall not be permitted to work more than 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> straight.

Note: This limitation does not include shift

, turnover time.

4.1.1.2 There shall be a break of at least 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (which can include shift turnover time) between all work periods.

4.1.1.3 An individual shall not work more than 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> in any 7 day period.

4.1.1.4 An individual should not be required to work more than 14 consccutive days without having 2 consecutive days off.

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CPSES ISSUE DATE PROCEDURE NO.

STATION ADMINISTRATION MANUAL STA-615 STAFF WORK HOURS REVISION NO. O PAGE 3 0F 3 4.1.2 Deviations from-these limitations may be authorized by the Manager, Plant Operations, his designee, or.a higher level of management. The cause for any such deviation shall be documented.

4.1.3 If a licensed operator or senior licensed operator has

  • been working more than 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> during periods of extended shutdown (e.g., at duties away from the control board),

such individuals shall not be assigned shift duty in the control room without at least a 12-hour' break preceding such an assignment. ,

4.1.4 If a reactor operator is required to work in excess of 8 .

continuous hours, he shall be periodically relieved of primary duties at the control board, such that periods of duty at the board do not exceed about 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.at a time.

4.1.5 The cognizant supervisor shall assure that overtime

- limitations procedure.

are controlled in accordance with this 5.0 Refe rences 5.1 NUREG-0,737,Section I.A.1.3

~

6.0 Attachments None

TDf-81339 TEXAS UTILITIES GENERATING COMPANY OFFICE MEMOR ANDUM Ty Distribution Gen Itcee. Texas August 20, 1981  ;

Subject Ooerator Guidelines The attached guidelines are provided for the operator who monitors equipment outside of the Ccuerol Room. These are minimum guidelines which should be used to ensure that the equipment is checked properly and consistently.

The parameters provided are subject to change as the plant nears completion.

The guidelines will be expanded as more systems come under the control of the Operations Department.

,m If you have any comments or questions, please contacti Bob Hill.

4. 2. U M R.R. Wistrand RRW/ /Im
  • Attachments Distribution:

Messrs. T.E. Sain L.G. Barnes R.L. Fortenberry G.D. Lytle J.W. Purdy ec: Messrs. R.B. Seidel J.J. Allen R.D. Bird N.L. Terrell ARMS

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4

. . s Operator Guidelines -

General Area Inspection Notes I. Area Glemnliness A. No excessive amounts of oil buildup.

B. No trash piled in unauthorized area.

II. Plant Tours A. look

1. Valve packing leaking.
2. Fluid on the floor or equipment.
3. Excessive vibration in pipes or equipment.
4. Smoke.
5. Charts running and at the proper time.

B. Listen

1. Abnormal noise levels.
2. Change in noise level could indicate a change in equipment status.

C. Small

1. Electrical equipment overheating.
2. Smoke.

D. Touch

1. Exces 1ve vitration.
2. Heat - If you can only hold your hand on 1. _

about 10 seconds, it is about 1200F.

3. If in doubt about an electrical component, do not touch it with the op.n side of your hand.

i

l Operator Guidelines Equipmen: Inspection Notes I. Battery Charger Rooms A. Batteries on float.

1. Float voltage should be between 125-135 volts.
2. If the chargers are supposed to be on equalize, the voltage should be between 134-145 volts.

B. Verify that the Charger AC and DC low voltage lights are on.

The lights go out if a low voltage condition exists.

C. Ensure that there are no blown fuses on chargers.

D. DC switchboards. *

1. Test for ground.
2. Check for:
a. Ground Protection relay lights.
b. Undervoltage relay lights.
c. Overvoltage relay lights.

E. Verify proper room temperature and ventilation. Room temperature should be between 500F to 1200F.

II. Battery Electrolyte, check for:

1. Level in the individual cells.
2. L akage out of a cell.
3. Any splattering on the top of cells.
4. Proper room ventilation and a room temperature between 600 and 900F.

Page 2 Rev. 0

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III. Instrument Air Compressors A. Cooling Water Pressure ,

1. Unit trip temporarily set at 20 psig.
2. Max. pressure should not cr: sed 75 psig.

B. 011, check for:

1. Oil level.

j

' 2. Oil pressure shouic. be between IJ to 40 psig.

Unit trips below 5 psig.

C. Inlet Air Filter D/P indicator should normally be yellev in color.

t It turns to red on high D/P.

D. Cooling Water Temp. on head discharge should be 10 to 150F above inlet air temp. (Thermometers are being installed to meet this requirement)

E. Check Aftercooler moisture trap for excessive moisture buildup.

F. Perfor glamp check on Control Panel.

G. Verify Instrument Air header press. of about 95 to 100 psig.

H. Check Instrument Air Receivers for excessive moisture buildup.

IV. Instrument Air Dryers A. Profilter and afterfilter D/P.

1. Profilter high D/P alarms at 7 psid. -
2. After ft .er high D/P alarms at 10 paid.
3. Check prefilter automatic moisture drain for excessive moisture.

C. Verify proper purge air flow of about 125 CFM.

D. Check for bypass air flow through the humidistat.

E. Check tower in regeneration for overheating. Heaters must be reset on control panel if heaters have tripped out on

  • overtemperature.

Page 3 Rev. O P

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V. Service Air Compressor A. Check the Inlet air filter D/P.

1. Normal about 2 to 3 paid.
2. High D/P exists at 6 paid.

B. Check the cooling water discharge temperature.

C. Oil, check for:

1. Oil Level.
2. Oil Pressure.

a.

18 psig decreasing, the W41ary Lube Oil Pump starts.

b. 15 psig decreasing, the unit trips.
3. D/P across the oil filter.
a. Normal D/P about 2-3 psi.
b. Max. D/P of 20 psi indicates filter is dirty and should be changes.
4. Oil Temperature, at 125*F increasing the unit is tripped.

D. Verify that the Service Air header pressure is about 100 psig.

E. Check the air cooler moisture traps for excessive moisture buildup.

F. Perform a lamp check on control panel.

G. Check the Service Air Receiver for excessive moisture buildup.

VI. TPG, check for:

A. Pump oil levels.

B. Pump bearing slinger ring. '

C. Pump gland leakoff.

D. Pump bearing and gland temperature by touch.

E. Motor oil levels.

F. Motor inlet cooling air filters.

G. IPG heat exchanger cooling water level.

3 Page 4 Rev. 0

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VII. Condenser Sump, check for:

A. Sump level.

B. Proper operation of sump pumps.

VIII. Fire Protection Headers, check the:

A. Isolation valves open.

B. Header pressure.

II. Normal 6.9 KV Switchgear, ensure that the:

A. Breaker position and spring charged lamps are lit on P.hz service breaker .

y .A B. Lockout relay circuit supervisory lamps are lit.

l C. Potential transformer' fuse lamps are lit.

I. Normal 480V Switchgear, check for:

l '

A. 6.9K7 to 4807 transformer control panels for temperature and alarm indications.

B Ground detection lamps.

C. Relay . flags dropped.

II. Safeguards 6.9K7 Switchgear, ensure that the:

1 .

l A. Breaker position and spring charged lamps are lit on in j service breakers.

l 1

B. Lockout ralay circuit supervisory lamps are lit.

l Page 5 Rev.0

III. Safeguards 480V Switchgear, check for:

A. 6.9KV to 480V transformer control panels for temperature and alarm indication.

B. Ground detection lamps.

C. Relay flags dropped.

XIII. 138KV Startup Transformer IST1, look for:

A. Arcing. *

1. Air switches.
2. Connectors.
3. Insulators.

B. Oil leaks.

C. Oil level.

D. Temperatures.

1. Liquid temperature alarms at 90 C.
2. Winding temperature alarms at 1200C.

E. Nitrogen Bottle Compartment.

1. Nitrogen bottle pressure. Boti::e should be changed if pressure is down to about 200 psig.
2. Transformer nitrogen blanket pressure should be about 2 to 4 psig' depending on ambient temperature and transformer load.

F. Transformer combustible gas compartment.

1. Combustible gas reading. Alarm setpoint is 1%.
2. Sample pump rimning.
3. Sample flow. Normal reading is .2 to .3 LPM.

Page 6 Rev. G

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XIV. Circulating Water Intake A. Screen wash pump, check for:

1. Motor oil level.
2. Pump gland leakoff.
3. Header pressure.
a. Normal pressure about 135 to 140 psig.
b. Mav4== pressure is 150 psig.

B. Surface water makeup pump, check for:

1. Motor oil level.
2. Pump gland leakoff.

'IV. Service Water Intake A. wrvice water puinps, check for: -

1. Motor oil level. .
2. Pump gland leakoff.
3. Cooling water flow.

B. SSW pump house vent exhaust fans should be on.

IVI. Switchyard, look for:

A. Arcing.

1. Air switches.
2. Connectors.
3. Insulators. -

B. Relay house batteries for clenn14 ness and electrolyte leakage.

. C. Battery on float.

1. Float voltage should be between 125 to 135 volts.
2. If the chargets are rapposed to be on equalize, the voltage should be between 134 to 145 volts.

D. Battery Chargers, check for:

1. B?own fuse indi ators.
2. AC & DC low voltage lamps lit.
3. Annuniciator switch on for the in service chargers.

Pass 7 Wbvn @)

\. ., . - . _ . _ ..

t

j. E. DC switchboard panels for ground lamp indication.

! i 7. Emergency shower and eye wash station to see if l

if is pressurized.

XVII. Demerator A.

Demerator transfer pumps, check for:

1. 011 level.
2. Pump gland leakoff.
3. Motor and pump bearing temperature by touch.

! 3. Verify seal water flow for the Desarator vacuum pumps.

i C. Demerator tank Icvel the setpoint on the meter face.

XVIII. Domineralized Water Transfer Pumps, check for:

A. Oil level.

B. Pump gland leakoff.

C. Motor and pump bearing temperature by touch.

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