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Omaha Public Power District1623 HARNEY a OMAHA. NEBRASKA 68102 m TELEPHON E 536 4000 AREA CODE 402

July 2,1981

Il,c' %:;

*'Mr. Robert A. Clark, Chief /

Office of Nuclear Reactor Regulation' (i 10U. S. Nuclear Regulatory Commission ("

.Ob 131981" 1.

._ ,

Division of Licensing '' Jd T, /Operating Reactors Branch No. 3 ,@. o .s.

Washington, D.C. 20555 W./ut D g/Reference: Docket No. 50-285

Dear Mr. Clark:

The Commission's letter dated May 13, 1981, forwarded questionsregarding the adequacy of Fort Calhoun Station's electrical distributionsystem voltages. Omaha Public Power District's response to thosequestions are attached.

Since ely,

'\h' ()'$W.

W. C. JonesDivisi n Manager,

Produ ion Operations

WCJ/KJM/TLP:jmm

Attachment

cc: LeBoeuf, Lamb, Leiby & MacRae1333 New Hampshire Avenue, N.W.Washington, D.C. 20036

Ohho!oOojs5 p6kPDR L

6' tt -

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Attachment

Question

(A) Tables 1 and 2 of attachment 9 provide transient voltage values during thesequenced starting of the engineered safeguard loads on buses 1A3 and 1A4.

1. What are the final (steady-state) voltagas at the 4160V and 480Vbuses, the 4160V, 4000V, and 460V motor tm ainals, and the 460V motorstarters when all safeguard loads are operacing for Cases 4, 5, and 6of Table 1 and Cases 3, 4, 5, and 6 of Table 2?

2. What are the lowest 4160V bus transient voltages for Cases 4, 5, and6 of Tables 1 and 2, attachment 9?

. Response

The intent of question (A), part 1., is apparently to determine if the 161 kVtap setting on the 161/4.16 kV transformers would adversely affect the steady-state voltages after all the engineered safeguard loads have started and becomeoperable. With this understanding, it is then apparent that, if the worst casemotor terminal voltage exceeds minimum operating limits, then all the othercases would also be acceptable. This is what is shown in tables provided byenclosure 1, where the worst case was taken to be the motor which provides thelargest load and cable impedence. For Table 1, the worst case gave a per unitvalue of 0.7494 which is 75% of 480 volts which exceeds the minimum acceptablelevel of 70% of 480 volts at the motor terminals.

Question

| (B) The voltages at buses 1A3 and 1A4 in Tables 1, 2, and 3 of attachment 5'

appear to be based on transformers T1A3 and T1A4 set on the 165kV tap (seesheet 2). What will the voltages be at buses 1A3 and 1A4 in Tables 1, 2,i

! and 3 if the transformers are on the 161kV tap?

Response

Some load flows were run to examine the effect of changing the taps on the| house service transformers at Fort Calhoun from 165 kV to 161 kV. Of primary, interest is the power flowing through the generator auxiliary transformer when' its secondary is tied to the secondary of the house service transformer. This

is a condition that exists momentarily during the normal transfer of stationservice loads between the 161 kV and the 22 kV sources. Buses 1A2 and 1A4 wereused in this analysis because they are more heavily loaded than buses 1A1 and

| 1A3. Enclosure 2, column VIA2, V1A4, demonstrates this effect.i'

Cases were run with the 22 kV bus voltage at .955 per unit (21.01 kV) and at1.023 per unit (22.5 kV). The transmission system used in the model was 1978summer peak load conditions, both with the system intact and with an outage of

1|

!

-,,

-2-

Response (Continued)

the Raun 345/161 kV transformer. Previous investigations have shown thistransformer outage causes the greatest difference in the voltage phase anglebetween the 22 kV and 161 kV buses at Fort Calhoun.

Under the condit h s studied, the 161 kV tap caused a slight decrease in thetransformer MVA loading. In all cases, the loading on the generator auxiliarytransformer (22 kV/4160V) was between 25 and 30 MVA.

For the case where 161 kV is transferred to 165 kV directly, it was determinedthat voltages were higher for the 161 kV tap. Column VIA1 of enclosure demon-strates this effect and it is expected that the same effect would be seen forall buse:

Question

(C) The FSAR and attachment 6 indicate that provisions exist to start up theplant from the 345kV source. Can this source be used tn safely shut theplant dows. under LOCA conditions if the 161kV source is not available? If

so, how soon would the 345kV source be available?

Response

Yes. If the 161 kV source were not available and a LOCA were to occur, theoperator would open the motor operated disconnect switch DS-T1 (generator'

disconnect switch), and close the two 345 kV breakers 3451-4 and 3451-5. Thetime required would be the time necessary for the equipment to operate.

Question

(D) What is the service factor for the 4160V, 4000V, and the 460V safeguardsmotors?

Response

Enclosure 3 provides a partial listing of motor service factors. Additionalinvestigation is required for the remaining motors and this information will beprovided by August 15, 1981.

Question

(E) The NRC letter of August 8,1979, requires a test be performed to verify >

your analytical results. The latest guidelines required that this testshould be performed by:

(a) Loading the station distribution buses including all Class 1E busesdown to the 120/208V level, to at least 30',

(b) Recording the existing grid and Class 1E bus voltages and bus loadingdown to the 120/208 volt level at steady state conditions and duringthe starting of both a large Class 1E and non-Class IE motor (not

-.

,

-3-

Question (Continued)

(Note) To minimize the number of instrumented locations (recorders),during the motor starting transient tests, the bus voltages andloading need only be recorded on that string of buses which previouslyshowed the lowest analyzed voltages.

(c) Using the analytical techniques and assumptions of the previousvoltage analyses and the measured existing grid voltage and busloading conditions recorded during conduct of test, calculate a newset of voltages for all Class 1E buses down to the 120/208 voltlevel.

(d) Compare the analytical derived voltage values against the testresults.

With good correlation between the analytical results and test results, thetest verification requirement will be met. That is, the validity of themathematical model used in performance of the analysis will have beenestablished. In general, the test results should be within + 3% of theanalytical results; however, the difference between the two -hen subtractedfrom or added to should never provide values that would allow operation ofthe Class IE equipment outside of rated voltage ranges.

Please provide a test description and date by when test results will beavailable.

Response

During 1978, the District did some testing to verify the electrical distributionsystem voltages. The 1978 test data is still being evaluated to determine thecorrelation to present guidelines, and determine further testing.

The District expects to provide our response by August 31, 1981.

||

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Enclosure 3 -9-, , , .

GSE-8-2-2 FORM Motor Terminal VoltagePREPARED BY Calculations01 =

REVISION CHECKED BY SH 1 CONT. ON SH 3AUG 011975 APPROVEDDATE(D REV DATE OMAHA PUBLIC POWER DISTRICT\._) TASK NO FC-77-40 GENERATING STA ENG.

1) One Line Diagram: (Refer to Fig. 8.4-1 FSAR)

6 lib 1291

y fi M6 \A2,

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I| MVA i \MVA iMVA/ (i)

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2= 63'/o ! 2 = 9.3*/. E = 5.37. MMb|h ,IS 61-1Bh 4c.gog g LOAb 8 MW @

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(1) - 1st Group of Sequence Starting Motors

(2) - 2nd Group of Sequence Stacting Motors

(3) - 3rd Group of Sequence S*.arting Motors

s_ % y_._

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I

Enclosure 3 -10-. . . . .

GSE-B-2 2 FORM flotor Terminal VoltagePREPARED BY Calculations01 *

REVISION CHECKED BY SH 2 CONT. ON SH. 3AUG 011975 APPROVEDDATE

OMAHA PUBLIC POWER DISTRICTi REV' DATEN TASK NO GENERATING STA. ENG.

1) One Line Diagram: (Refer to Fig. 8.4-1 FSAR)

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f

(1) - 1st Group of Sequence Starting Motors

(2) - 2nd Group of Sequence Starting Motors

(3) - 3rd Group of Sequence Starting Motors

f S e c v e'c.e Facfers m(w) ye.e. n .

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