ML20098B773

Monthly Operating Rept for Aug 1984

ML20098B773
Person / Time
Site:	Grand Gulf
Issue date:	08/31/1984
From:	Cesare J MISSISSIPPI POWER & LIGHT CO.
To:
Shared Package
ML20098B759	List: AECM-84-0469, Forwards Monthly Operating Rept for Aug 1984 & Rev 4 to Offsite Dose Calculation Manual ML20098B773 ML20098B780
References
NUDOCS 8409260258
Download: ML20098B773 (8)

Text

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Attachment to AECM-84/0469 OPERATING DATA REPORT Page 1 of 6 DOCKET NO.

50-416 DATE 9/14/84 COMPLETED BY

.T. c. co=are

~ TELEPHONE 601-969-2585 OPERATING STATUS Notes

1. Unit Name: Grand Gulf Nuclear Station

2. Reporting Period: August 1984

3. Licensed Thermal Power (MWt): 191*

1372.5

4. Nameplate Rating (Gross MWel:

1250

5. Design Electrical Rating (Net MWe):

NA

6. Maximum Dependable Capacity (Gross MWe):

NA

7. Maximum Dependable Capacity (Net MWe):

8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report. Gise Reasons:

• The 3833 MWt license was issued on August 31, 1984

9. Power Level To Which Restricted.lf Any(Net MWe): NA

10. Reasons For Restrictions. If Any: as restricted by 0.L. NPF-13 as listed on 't.0 nhovo (Also see 8.0 above).

This Month Yr..to-Dat e Cumulatise 744 5856 8784

11. Hours in Reporting Period 800.3 1795.6

12. Number Of Hours Reactor has Critical 13. Reactor Reserve Shutdown Hours

14. Hours Generator On-Line 15. Unit Reserse Shutdown Houn 98,466 175.854

16. Gross Thermal Energy Generated (MWHI 17. Gross Electrical Energy Generated (MWH,.18. Net Electrical Energy Generated (MWHi

19. Unit Service Factor NA NA NA NA NA NA

20. Unit Availability Factor NA NA NA

21. Unit Capacity Factor (Using MDC Net)

NA NA NA

22. Unit Capacity Factor (Using DER Neti

23. Unit Forced Outage Rate NA NA NA

24. Shutdowns Scheduled Oser Next 6 Months (Type. Date.and Duration of Each t:

NA

25. If Shut Down At End Of Report Period. Estimated Date of Startup:

NA

26. Units in Test Status iPrior to Commercial Operationi:

Forecast Achieved 08/18/82 IN1114 L CRITICALITY 09/84 INITI A L ELECTRICITY COMMERCI AL OPERATION 04/85 8409260258 840914 PDR ADOCK 05000416 08/771 i

R pgg

O Attachment to AECM-84/0469 INSTRUCTIONS FOR COMPLETING OPERATING DATA REPORT Page 2 of 6 This report should be furnished each month by licensees. The name and telephone number of the preparer should be prosided in the designated spaces. The instructions below are provided to assist licensees in reporting the data consistently. The number of the mittuetten corresponds to the item number of the report format.

1. UNIT NAME. Self explanatory.

or of commercial operation, whichever comes last, to the end of the period or decommissioning, whichever comes

2. REPORTING PERIOD. Designate the month for which first. Adjustments in clock hours should be made in the data are presented.

which a change from standard to daylight-savings time (or vice versa) occurs.

3. LICENSED THERMAL POWER (MW )is the maximum t

thermal power, expressed in megawatts, currently auth.

12. NUMBER OF HOURS REACTOR WAS CRITICAL.

orized by the Nuclear Regulatory Commission.

Show the total number of hours the reactor was critical

4. NAMEPLATE RATING (GROSS MW,). The nameplate power designation of the turbine. generator in megavolt

13. REACTOR RESERVE SHUTDOWN HOURS. The total superes (MVA) times the nameplate power factor of the number of hours during the gross hours of reporting turbine generator.

period that the reactor was removed from service for administrative or other reasons but was available for

5. DESIGN ELECTRICAL RATING (NET MW,) is the operation.

nominal net electrical output of the unit specified by the utility and used for the purpose of plant design.

14. HOURS GENERATOR ON-LINE.

Also called Service Hours. The total number of hours expressed to the near.

6. MAXIMUM DEPENDABLE CAPACITY (GROSS MW )

e est tenth of an hour during the gross hours of the re.

is the gross electrical output as measured at the output porting period that the unit operated with breakers terminals of the turbine. generator during the most re-closed to the station bus. These hours, plus those listed strictive seasonal conditions.

in Unit Shutdowns for the generator outage hours. should 7 MAXIMUM DEPENDABLE CAPACITY (NET MW ).

e Maximum dependable capacity (gross) less the normal

15. UNIT RESERVE SHUTDOWN HOURS. The total num.

station service loads.

ber of hours expressed to the nearest tenth of an hour

8. Self-explanatory.

during the gross hours of the reporting period that the unit was removed from service for economic or similar

9. POWER LEVEL TO WHICH RESTRICTED IF ANY reas ns but was available for operation.

(NET MW,). Note that this item is applicable only if

16. GROSS THERMAL ENERGY GENERATED (MWH).

restrictions on the power level are in effect. Short. term tiess than one month) limitations on power level need The thermal output of the nuclear steam supply system not be presented in this item.

during the :;ross hours of the reporting period, expressed in megawatt lors (no decimals).

Since this information is used to develop figures on capa-city lost due to restrictions and because most users of the

17. GROSS ELECTRICAL ENERGY GENERATED (MWH).

" Operating Plant Status Report" are primarily interested The electrical output of the unit measured at the output in energy actually fed to the distribution system. it is terminals of the turbine-generator during the gross hours requested that this figure be expressed in MWe. Net in of the reportmg period, expressed in megawatt hours (no spite of the fact that the figure must be derived from decimals).

MWt or percent power,

18. NET ELECTRICAL ENERGY GENERATED (MWH).

10. REASONS FOR RESTRICTIONS. IF ANY. If item 9 The gross electrical output of the unit measured at the is used, item 10 should explain why. Brief narrative is output terminals of the turbine-generator minus the nor-acceptable. Cite references as appropriate. Indicate mal station service loads during the gross hours of the whether restrictions are self. imposed or are regulatory reporting period, expressed in megawatt hours. Negative requirements. Be as specific as possible within space limi-quantities should not be used. If there is no net positive tations. Plants in startup and power ascension test phase value for the period. enter zero (no decimals).

should be identified here.

11. HOURS IN REPORTING PERIOD. For units in power

19. For units still in the startup and power ascension test ascension at the end of the period, the gross hours from

23. phase. items 19 23 should not be computed. Instead. enter the begmning of the penod or the first electrical produe.

N/A in the current month column. These five factors rion, whichever comes last, to the end of the period.

should be computed starting at the time the unit is de.

clared to be in commercial operation. The cumulative For units in commercial operation at the end of the figures m the second and third columns should be based penod the Fross hours from the beginning of the period on commercial operation as a starting date.

Attachment to AECM-84/0469

,19. UNIT SERVICE FACTOR. Compute by dividing hours the generator was on hne (item 14) by the gross hours in Page 3 of 6 the reporting period (item !1). Express as percent to the nearest tenth of a percent. Do not include reserve shut-down hburs in the calculation.

20. UNIT AVAILABILITY FACTOR. Compute by dividing

- the unit available hours (item 14 plus item 15) by the gross hours in the reporting period (item i1). Express as percent to the nearest tenth of a percent.

21. UNIT CAPACITY FACTOR (USINGMDC NET). Com-pute by dividing net electrical energy generated (item 18) by the product of maximum dependable capacity (item

7) times the gross hours in the reporting period (item 11).

Express as percent to the nearest tenth of a percent.

22. UNIT CAPACITY FACTOR (USING DER NET). Com-pute as in item 21. substituting design electrical rating (item 5) for maximum dependable capacity.

23. UNIT FORCED OUTAGE RATE. Compute by dividing the total forced outage hours (from the table in Unit Shutdowns and Power Reductions) by the sum of hours generator on line (item 14) plus total forced outage hours (from the table in Unit Shutdowns and Power Reductions).

Express as percent to the nearest tenth of a percent.

24. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE. AND DURATION OF EACH). Include

. type (refuehng. maintenance, other) proposed date of start of shutdown, and proposed length of shutdown.

It is recognized that shutdowns may be scheduled between reports and that this item may not be allinclusive. Be as accurate as possible as of the date the report is prepared.

This item is to be prepared each month and updated if appropriate until the actual shutdown occurs.

25. Self. explanatory.

26. Self explanatory. Note, however, that this information is requested for all units in startup and power ascension test status and is not required for units already in com-mercial operation.

TEST STATUS is dermed as that period following ini.

tial criticality during which the unit is tested at succes-sively higher outputs. culminating with operation at full power for a sustained period and completion of war.

ranty' runs. Following this phase. the umt is generally considered by the utihty to be availab!e for commercial

~

operation.

Date of COMMERCIAL OPERATION is defined as the j

date that the unit was declared by the utility cwner to l

be available for the regular production of electricity.

j usually related to the satisfactory completion of quali.

l Ocation tests as specified in the purchase contract and to the accounting policies and practices of the utilit).

l l-g4~~l

9 Attachment to

- i AVERAGE DAILY UNIT POWER LEVEL AECM-84/0469

]

Page 4 of 6 1

l DOCKET NO.

50-416 UNIT I

DATE 9/14/84 COMPLETED BY J. G. Cesare TELEPHONE (601)969-2585 MON 111 August, 1984 DAY AVERAGE DAILY POWER LEVEL DAY AVER /.GE DAILY POWER LEVEL (MWe-Net)

(MWe-Net)

NA i

g 2

Ig 3

Ig 4

20 5

21 6

22 7

23 8

24 9

25 10 26 II 27 12 28 13 29 0

14 30 15 31 16 i

INSTRUCTIONS 1

On this format list the average daily unit power lesel in MWe Net for each day in the reporting month. Compute to the nearest whole megawatt.

1 (4/77 )

It

50-416 o

UNIT SHUTDOWNS AND POWER REDUC 110NS DOCKET NO.

um UNIT NAME 1

u DATE 9/14/84 COMPLETED BY

.T.c. cesare REPORT MONTH Auenst. 1984 TELEPHONE (601T964-?sRR aen 5$a

, aae E

E

.$ ?

3 yY3 Licensee 5%

E",,

Cause & Corrective No.

Date g

3g g

jg5 Event u?

83 Action to

$E jig Report 2r iNU jU H

Prevent Recurrence c5 9

07/25/84 F

744.0 F

1 NA NA NA Adminstratively shutdown when 3 IRM's f ailed. This left 2 operable in Trip System B and 3 IRM's oper-able in Trip System A.

No shutdown was required by Technical Specifi-cations. The failed IRM's were replaced but the outage continued to conduct feedwater check valve local leak rate testing.

1 I

2 3

4 F: Forced Reason:

Method:

Exhibit G-Instructions S: Scheduled A Equipment Failure (Explain)

I-Manual for Preparation of Data B-Maintenance or Test 2-Manual Scram.

Entry Sheets for Licensee C Refueling 3 Automatic Scram.

Event Report (LER) File (NUREG-D-Regulatory Restriction 4-Osher (Explain) 01611 E-Operator Training & License Examination F Administrative

• In accordance G-Operational Error (Explain t Exhibit I Same Source (9/77) llother (Explain) with Nureg 1022

c Attachment to UNIT SHUTDOWNS AND POWER REDUCTIONS Page 6 of 6 INSTRUCTIONS This report should describe all plant shutdowns during the in accordance with the table appearing on the report form.

report period. In addition,it should be the source of explan-If category 4 must be used, supply brief comments.

ation of significant dips in average power levels. Each signi.

ficant reduction in power level (greater than 207r reduction LICENSEE EVENT REPORT #.

Reference the applicable in average daily power level for the preceding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />)

'eportable occurrence pertaining to the outage or power should be noted, even though the unit may not have been reduction. Enter the first four parts (event year, sequential l

shut down completely. For such reductions in power level, report number, occurrence code and report type) of the five the duration should be listed as zero, the method of reduction part designation as described in item 17 of Instructions for should be listed as 4 (Other), and the Cause and Corrective Preparation of Data Entry Sheets for Licensee Event Report Action to Prevent Recurrence column should explain. The (LER) File (NUREG 0161). This information may not be Cause and Corrective Action to Prevent Recurrence column immediately evident for all such shutdowns, of course, since should be used to provide any needed explanation to fully further investigation may be required to ascertain whether or describe the circumstances of the outage or power reduction.

not a reportable occurrence was involved.) If the outage or power reduction will not result in a reportable-occurrence.

NUMBER. This column should indicate the sequential num.

the positive indication of this lack of correlation should be ber assigned to each shutdown or significant reductionin power n ted as not applicable (N/A).

for that calendar year. When a shutdown or significant power SYSTEM CODE-The system in which the outage or power reduction begins in one report period and ends m another, reduction originated sh' uld be noted by the tw'o digit code of an entry should be made for both report periods to be sure o

all sliUiIdowns or significant power reductions are reported.

Exhibit G Instructions for Preparation of Data Entry Sheets Until a unit has achieved its first power generation, no num-f r Licensee Event Report (LER) File (NUREG,0161).

ber should be assigned to each entry.

Systems that do not fit any existing code should be designa-ted XX. The code ZZ should be used for those events where DATE. This column should indicate the date of the start a system is not applicable.

of each shutdown or significant power reduction. Report as year. month, and day. August 14.1977 would be reported COMPONENT CODE. Select the most appropriate component as 770814. When a shutdown or significant power reduction from Exhibit I - Instructions for Preparation of Data Entr>

beginsin one report period and ends in another, an entry should Sheets for Licensee Event Report (LER) File (NUREG-0161).

be made for both report periods to be sure all shutdowns using the following critieria:

or significant power reductions are reported.

TYPE. Use "F" or "S" to indicate either " Forced" or " Sche-duled," respectively, for each shutdown or significant power B.

If not a component failure, use the related component:

reduction. Forced shutdowns include those required to be e.g., wrong valve operated through error: list valve as initiated by no later than the weekend following discovery component.

of an off normal condition. It is recognized that some judg.

ment is required in categorizing shutdowns in this way. In C.

If a chain of failures occurs, the first component to mal-general, a forced shutdown is one that would not have been function should be listed. The sequence of events.includ.

completed in the absence of the condition for which corrective ing the other components which fail, should be described action was taken.

under the Cause and Corrective Action to Prevent Recur-rence column.

DURATION. Self-explanatory. When a shutdown extends beyond the end of a report period. count only the time to the Components that do not fit any existing code should be de-ead of the report penod and pick up the ensuing down time signated XXXXXX. The code ZZZZZZ should be used for in the following report periods. Report duration of outages events where a component designation is not apphcable.

rounded to the nearest tenth of an hour to facilitate summation.

The sum of the total outage hours plus the hours the genera-CAUSE & CORRECTIVE ACTION TO PREVENT RECUR-tor was on hne should equal the gross hours in the reporting RENCE. Use the column in a narrative fashion to amphfy or penod.

expla n the circumstances of the shutdown or power reduction.

The column should include the specific cause for each shut.

REASON. Categorite by letter designation in accordance down or significant power reduction and the immediate and with the table appearing on the report form. If category 11 contemplated long term corrective action taken, if appropn-must be used. supply bnet comments-ate. This column should also be used for a description of the ma. tor safet> related corrective maintenance performed dunng METHOD OF SHUTTING DOWN THE REACTOR OR the outage or power reduction including an identification of REDUCING POWER. Categon/e b) nuinber designation the entical path activity and a report of any single release of radioactivity or sinF e radiation exposure specifically associ-l INote that this ditfers from the Edison Eleetne Institute ated with the outage which accounts for more than 10 rncent l

(EFH definitions of " Forced Parnal Outage" and " Sche, of the allowable annual values T

duled Painal Outage. I or these terns I i i uses a shange of For long textual reports continue narrative on separate paper 30 M% as the break point. For larpei power reactors.30 MW and reference the shutdown or power reducuan toi thn j

is too small a shange to wanant esplananon.

narrative-i f

M (9

MONTHLY OPERATING REPORT SUPPLEMENTAL INFORMATION

SUBJECT:

Grand Gulf Nuclear Station (GGNS) Offsite Dose Calculation Manual (0DCM), Revision 4 Changes made in the GGNS ODCM, Revision 4 are outlined belos:

o Page: 1.0-15 Affected Areas: Lines 2, 3 and 4 Revision: Lines 2, 3 and 4 were changed to read "the essential components of the liquid radwaste system are indicated below by an asterisk (*)."

Justification: GGNS Radiological Effluent Technical Specification (RETS) 3/4.11.1.3 has been changed with regard to demonstrating operability of the liquid radwaste treatment system.

If the concentration and dose requirements of GGNS RETS Sections 3.11.1.1 and 3.11.1.2 are being achieved, the essential components of the liquid radwaste treatment system have either been demonstrated operable or are not required. Consequently, since operability of the system is now associated with the dose requirements it is not necessary to operate the system essential components a minimum amount of time as previously required by RETS 3/4.11.1.3.

o Page: 2.0-35 Revision: In paragraph 2.5 the essential components of the Gaseous Radwaste Treatment (Offgas) System required to demonstrate the operability requirement of GGNS RETS Specification 3/4.11.2.4 have been deleted from the text and associated figure. They were replaced by the instruments required to be checked to ensure that the Offgas System is functioning properly.

Justification: GGNS RETS 3/4.11.2.4 has been revised and now requires instrument checks every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> instead of component operation every 92 days.

The ODCM change was made to specify which instruments had to be checked and the frequency for these checks. GGNS RETS 3/4.11.2.4 was revised to provide a more reliable means to check the operability of the Offgas System.

18 Ray:1

e Page: 3.0-2 Affected Areas: Lines 13, 17, 21 and 24 Revision: Asterisks indicating RETS requirements were deleted from AS-4 GJ0E and AS-9 GGMP and added to AS-6 RS and AS-8 WR.

Justification: As a result of GGNS RETS changes, required air sampling locations are now dependent on the locations having the highest deposition rate (D/Q) whereas previously air sampling locations were based on those locations having the highest atmospheric dispersion rate (X/Q).

Deposition rate is a more important consideration than atmospheric dispersion when selecting locations which have the highest potential for material deposition, o

Page: 3.0-3a Affected Area: Lines 16 through 25 and 30 Revision: A vegetation sampling location in Meteorological Sector R was added to the Vegetation Section of Table 3.0-2 and two optional locations at Lake Claiborne Willis Garden and Nelson Truck Farm were deleted from Table 3.0-2.

Also, the species of fish required for sampling was changed from catfish to comercially or recreationally important specifies in the Fish Sample Section of Table 3.0-2.

Justification: GGNS RETSs now require sampling two garden locations in the meteorological sectors having the highest calculated deposition rate. GGNS RETSs also permits fish sampling to be performed on commercially and recreationally important species other than catfish. The changes to RETSs were necessary to allow adequate sample volume to be collected from appropriate locati6ns in a timely manner.

Significant Hazards Category Revision 4 to the ODCM involves no changes to the safety-related equipment at GGNS.

It does not introduce a significant reduction in the margin of safety and does not involve a significant increase in the probability or consequences of an accident previously evaluated.

It does not create the possibility of a new or different kind of accident from any accident previously evaluated nor does it reduce the accuracy or reliability of dose calculations or setpoint determinations. Thus there are no significant hazards involved.

18 Ray:2