ML19329A808
| ML19329A808 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 08/12/1970 |
| From: | Sampson G TOLEDO EDISON CO. |
| To: | Price H US ATOMIC ENERGY COMMISSION (AEC) |
| References | |
| NUDOCS 8001150704 | |
| Download: ML19329A808 (5) | |
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Mr. Harold L. Price Wr[d.flf, d.Q',%"bl s Director of Regulations
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Dear Mr. Price:
,-.y Under date of June k,1970, we requested an exe=ption from the provisions of Section 50 J7 (b) of 10 CFR Part 50 to allow certain vork on the Davis-Besse Station prior to issuance of a construction pemit.
On July 24, 1970 ve submitted additional requested infor=ation to support our exemption request.
We must emphasize the imediau eed for this exemption in order that construction may start no later than 5 *ptember 1 of this year so that an orderly construction schedule can be maintained to bring this unit into comercial ser rice by Dece=ber 1,19Th.
During the early schedule planning for this project, a date of
-August 1,1969, was established for submittal of the license application with a period ~of 14 months allowed for the necessary processing to provide for the issue of a construction permit about October 1,1970. Our application was submitted on August 1,1969, and it was felt that a review schedule could be maintained to meet our original schedule. However, it became apparent in June of this year that review of the application vould not be completed in time for a construction permit to be issued by October, and we requested an exe=ption.
To =cre fully justiff the need to have this praject in co=ercial service on Dece=ber 1,197h, we are attaching Tables I and II which show in detail the capability-and load situation in 197h and early 1975 Table I gives information concerning the Toledo Edison system and Table II con-cerns the CAPCO Group system. Both tables indicate the forecast situation during the peak lead veess in the su=mer of 1974, December 197h and January 1975 After commercial operating dates were established by the CAPC0 Group, for the = initial four pooled units (Davis-Besse is the fourth unit),
revised load forecast projections for 197h incressed to a point where a deficiency in reserves was indicated during 197h. It was considered impractical to advance the schedule for the Davis-Besse unit due to licensing requirements, and the installation of another major unit earlier than Davis-Besse was not prudent. Consequently, a 200 MW block of power was contracted for from the Michigan Pool to cover this short ters c.
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Page.2 Atigust -12,1970.
Docket No. 50-3h6 deficiency. This. short term purchase ends January 1,1975, and present indications are that this purchase cannot be extended due to prior commitment for this capacity to other areas.
In addition to the purchase of 200 MW to maintain suitable capacity reserve to cover an unforeseeable forced outage of a major generating unit, planned =aintenance of existing generating units has been necessarily deferred during this 197h critical period until the Davis-Besse unit is commercially available. Reliability of existing units will be reduced if maintenance outages continue to be deferred.
Complete data on capacity,. load forecasts, reserve margins,
deficiencies and the short term purchase of 200 MW to meet these deficiencies is clearly indicated on.the attached tables. These tables are taken from the projected week-by-week-forecasting schedule for the period 1970 through 1977 which is prepared by the CAPC0 Group for scheduling of capacity additions and planned =aintenance and it represents the best infor=ation available at this time.
We understand that there are no unresolved areas concerning the safety review of the Davis-Besse Station and the attached infor=ation should clearly veriff the need for an inservice data of December 1,197h.
We are hopeful that this provides you with all necessar/ infor=a-tion concerning this request, and that timely approval will be forthcoming.
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TABLE I DAVIS-BESSE NUCLEAR POWER STATION TOLEDO EDISON SYSTEM LOAD AND RESERVE FORECAST Megawatts (MW)
Summer 1974 Winter 1974-1975 Peak Load December Peak Load Week January Peak Load Week Line Week Wi th Without With Wi thout No.
Item Davis-Besse Davis-Besse Davis-Besse Davis-Besse_
1.
Net Demonstrated Unit Capability (1) 1 065 1 523(3) 1 065 1 523(3) 1 065 2.
Net Concurrent System Capability (1) 1 011 1 491 1 028 1 491 1 028 3.
Receipts and (Deliveries)-Other Systems AEP 100 100 100 100 100-CAPC0 175 OVEC 22 27 27 28 28 MICliIGAN POOL 200 200 200
-0 ~ CAPCO (Delivery)
(85)
(265)
(265)
(180)
(180)
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Available Capability 1 423 1 553(h) 1 090 1 439 976
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5 Scheduled Maintenance 26 26 I.
6.
Awailable Capability For Load 1 h23 1 553 1 090 1 413 950 f,
3 7
Forecast Peak Load 1 347 1 2q2 1 292 1 25h 1 254 8.
Reserve Over. Load 76 261 (202) 159
( 30 4)
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Normal Operating Reserve (2) 90 128 88 130 86 I
10.
Net Margin (14) 133 (290) 29
( 390 )
NOTES 1:
(1)
She net Demonstre.ted Unit Capability is the sum of the individual unit demonstrated capability. This value is reduced by a Condition Derating Factor to account for quality of fuel, unit condition, etc.,
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and a Seasonal Adjustment to account for temperature and other conditions, to arrive at Net System Capability.
(2)
Normal Operating Reserve is based on peak load with factors for larges t units in service and their forced outage rates.
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(3)
This figure includes Toledo Edison 458 MW share of Davis-Besse capability (52.5% of 872 MW).
(h)
Sys tem capability of 1,585 stated in June 4,1970 letter is sum or lines 1 and 3 with no allowance for reduction due to Condition Derating and Sensonal Adjustment.
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TABLE II DAVIS-BESSE NUCLEAR POWER STATION CAPCO GROUP SYSTEM LOAD AND RESERVE FURECAST Megawatts (MW)
Suncner 19716 Winter 1974-1975 Peak Load December Peak-Load Week January Peak Load Week '
'. Line Week With Without With Without.'
No.
Item Davis-Besse Davis-Besse. Davis-Besse Davis-Besse 1.
' Het Demonstrated Unit Capability (1) 11 795 12 702 11 830 12.762 11 890-2.
. Net Concurrent System Capability (1) 11 503 12 550 n 678 12 610.
11 738 3.
Purchase From Other Systems h59 536 536 338 338 1
Available. Capability 11 962 13 086(4) 12 214 12 948 12 076 6
5
. Scheduled Maintenance 1 36 834 8 314 769 769_
6.
Available Capability For Load '
.11 826 12 252 11 380 12 179 11 307-7
. Forecast Peak Load (2) 11 125 10 980 10 980 10 7h9' 10 Th9 R
8.
Reserve Over Load 70 1 1 272
-400 1 430 558 y;-
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. Normal Operating Reserve (3) 928 992 914 9 814 89; 10.
Net Margin (227) 280 (511) 446 (337) h 4
11.
Het Margin With Interruptible Credit 13 535' (259 )
701
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NOTES (1)
The net Demonstrated Unit Capability is the sum of the individual unit demonstrated capability. This value is reduced by a Condition Drating Factor to account for quality of fuel, unit condition, etc.,
- and a Seasonal Adjustment to account for temperature and other conditions, to arrive at Net System'
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Capability, j
(2)
Forecast Peak Load includes interruptible load in the amount of 240 MW during summer and 255 MW during
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g winter. Credit is given for this interruptible load in determining satisfactory Net Margin.
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(3)
Normal Operating Peserve is based on peak load with factors for largest units in service and their i
forced outage ratet W
21, 1970 letter is the sum of line 1 and 3 vith no allowance
$1 (1 )
Group capability of 13,238 stated in July 4
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for reduction due to Condition Derating and Seasonal Adjus tment.
.