ML20002E099
| ML20002E099 | |
| Person / Time | |
|---|---|
| Site: | Vogtle  |
| Issue date: | 01/22/1981 |
| From: | Ehrensperger W GEORGIA POWER CO. |
| To: | Tedesco R Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 8101260396 | |
| Download: ML20002E099 (34) | |
Text
{{#Wiki_filter:-- Georgia Power Ccmpany Post Office Box 4545 230 Peacntree S:reet. N W At:anta. Georgia 30302 Teiepncre 404 522-6060 W. L Ehrensperiger Sector Vice Presicent Power Suppfy January 22, 1981 Mr. Robert L. Tedesco Assistant Director for Licensing Division of Licensing United States Nuclear Regulatory Commission Washington, DC 20555 RE: -Request for Information to Assess the Need for Power from Vogtle Nuclear Power Plant. Units 1 and 2.
Dear Mr. Tedesco,
I am enclosing on behalf of Georgia Power Company a verified response to t.he Request for Information transmitted with your letter to me dated December 19, 1980. , Please contact me should you have any questions concerning this response. Sincerely, w. W. E. Ehrensperger cc w/ enclosure.: L. T. Gucwa R. A. Thomas J. A. Baily G. F. Trowbridge G. R. Flack il. s b i
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VERIFICATION W. E. Ehrensperger, first being duly sworn, deposes and says: that he is senior vice president of Georgia Power Company; that he has read the foregoing document and is familiar with the contents thereof; that he is authorized to file such document on behalf of Georgia Power Company; and that the statements of fact contained therein are true and correct to the best of his knowledge, information and belief.
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.c :- s-a W. E. EHRENSPERGER Sworn to and subscribed before me this. day of . , 1981.
e a NOTARY PUBLIC , e
- A-ie . !. . Cecrg:a, ?,taic et L qe P/ Cwimini:n Espiros r.:4rc.4 22,1931 i
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- 1. A, B and C.
A. Schedule on-line commercial operating dates for each Vogtle unit: Unit No. 1: May 1, 1985 Unit No. 2: Nov. 1, 1987 Expectations for meeting these dates: Certain phases of construction activities are up to eight months behind schedule. It is our present intention to 1 make up this deficit so that it will have no effect on expected dates for commercial operation. B. Latest official capital cost estimate for the plant:
$ 2,741,000,000 (exclusive of AFUDC)
$ 3,644,000,000 (including AFUDC as though GPC owned 100%
of Plant Vogtle) C. Total expenditures to date (through Nov., 1980): Construction expenses at the site (Note 1) . . . $ 286 million Permanent plant equipment ................... $ 266 million Eng ine e ring . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2 0 2 millio n Other (Note 2) .............................. S 66 million TOTAL ....................................... $ 820 million Note 1: Includes contract labor, field non-manual, bulk materials, distributable field costs, supply and erection subcontracts. Note 2: Primarily AFUDC attributable to GPC's 50.7% owner-ship interests. This amount does not include any amounts attributable to the 49.3% of Plant Vogtle owned by Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, or the City of Dalton, Georgia. Elements of total cost to date that would not be recovered if construction were halted: We have not performed a detailed study of this question. ) We easume that a portion of the cost of some plant equip-ment, certain bulk materials not yet incorporated in the plant, and certain temporary facilities could be recovered via resale. Such recoveries would have to be off-set with cancellation charges not included above.
1.D ESTIMATES OF FUEL, OPERATION, & MAINTENANCE COSTS FOR PLANT V0GTLE UNITS 1 & 2 OPERATION AND MAINTENANCE FUEL COST VARIABLE FIXED UNIT GWH $/MM K$ $/MG K$ S/KW/ YEAR M Vogtle 1 4701.2 (1985 Dollars) 13.02 61,210 2.41 11,330 25.32 19,412 (1980 Present Worth) 7.64 35,935 1.41 6,652 14.86 11,396 Vogtle 2 7051.8 l (1988 Dollars) 15.49 109,200 3.10 21,861 32.80 37,720 (1980 Present Worth) 6.60 46,573 1.32 9,324 13.99 16,087
- 1) Commercial Operation of Vogtle 1 is 5/85, therefore the figures sliown represent 8 months of operation in 1985. (approx. 70% capacity factor)
- 2) Commercial Operation of Vogtle 2 is 11/87, therefore the figures shown represent 12 months of operation in 1988. (approx. 70% capacity factor)
- 3) All present worth calculations are done using an 11.24% rate.
- 4) Estimates shown are the . result of dispatch modelling using generation expansion plan 80P1, which is based on the Georgia Power Company Ioad Forecast of August,1980.
- 5) Estimates of Operation and Maint mance expenses escalate at approximately 9% per year, compound. Estimates of Fuel. Cost vary in an irregular fa'shion, therefore an escalation rate is not readily applicable.
l WDC/cs l 1/13/81 l l l ' l - _ _ _ _
- 2. As o f 11 80, estimates of the generation by fuel type from Georgia Power Company generating resources to meet Georgia territorial energy requirements are as follows:
Ilydro 2,019,746 MW!i Gas 85,188 MWH Coal 38,458,261 MWH Oil 11,415 MWil Nuclear 8,085,016 MWH These numbers are approximate because Georgia Power Company's share of transactions through the Southern Company Pool are not identified by fuel type.
Integrated Territorial Territorial
- 3. Year Peak llour Sales MW MWH 1973 8,212 38,414,546 1974 8,745 38,605,396 1975 8,795 39,176,805 1976 9,150 41,823,696 1977 9,631 45,124,879 1978 , 10,173 47,038,554 1979 10,213 47,322,809
'980 11,154 49,895,060 Note: All numbers are actual 1
l 4. In response to Question 4, attached please find:
- 1. annual peak demand and energy sales for the Georgia territory for the years 1981-1995.
- 2. Georgia Power Company Territorial System Expansion Plans for the years 1981-1993, including capacity at the time of the system peak, unit power and non-firm sales, and system reserve margins.
- 3. Supplemental data for the Georgia territorial system showing system reserve margins under these contingencies- the con-tingency forecast of territorial peak demand prepared by Data Resources, Inc.,; the proposed sale of 16.57. of Plant Vogtle to non-territorial entities; and the elimination of oil-fired generation from territorial capacity.
- 4. Southern Electric. System Expansion Plan for the years 1981-1993.
- 5. Supplemental data for the Southern Electric System showing system reserve margins under three contingencies: the con-tingency forecast of Southern Electric System peak demand prepared by Data Resources, Inc.; the proposed sale of 16.5%
of Plant Vogtle to non-territorial entities; and the elimina-tion of oil-fired generation from Southern Electric System capacity.
- 6. Projections of Georgia Power Company's share of coal-fired unit power sales and non-firm power sales for the years 1981-1993.
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1 4- A & B l 1 GEORGIA POWER COSTANY 1980 BUDGET FORECAST ; 0F
, GEORGIA TERRITORIAL INTEGRATED HOUR PEAK DE!WW AND
^. 0rAL TERRITORIAL REQUIREEl:TS PEAK DEMAND TERRITORIAL REQUIPE!CITS YEAR MW ME 1981 10238 49,490,137 1982 10470 51,117,558 1983 10942 53,278,446 1984 11421 55,648,722 1985 11898 57,668,451 1986 12294 59,713,928 1987 12698 61,656,940 1988 13117 63,734,953 1989 13591 65,915,236 1990 14113 68,157,388 1991 14665 70,437,986 1992 15242 . 72,798,931 1993 15856 75,215,924 77,690,508 l 1994 16502 1995 17186 80,252,339 l
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- 4. c cnd e JANUARY 13,1981 GEORCIA POWER COHPANY REPORT 130. 1 Territorial PAGE 1 SYSTEM EXPAHSIOt1 PLAN PLAN 80P1-WITil SALES 1981 - 1993 N ET ---t RESERVES---
UNIT DATE ADJUST. SYSTEM HH LOAD MW RESERVE % RESERVE IF NON F1ht .%LE CAPACITY CAPACITY PROJECTED ADDED TJ lt/M.D INITIAL GENERATION 12/31/80 14398.7 TOTAL 8/51/81 14398.7 10247.0 4151.7 40.52 36.72 SCllERER 1 800 FC ( 8.4% GPC? 2/82 800.0 800.0 SEPA IlYDRO ADJUST 2 TENT 6/82 -41.4 -41.4 SEPA PREFERENCE ADJUSTMENT 6/82 41.4 41.4 TOTAL 8/31/82 15206.7 10479.0 4727.7 45.12 39.92 UttIT POWER SALES TOTAL 490 MW 8/83 -450.0 -450.0 TOTAL 8/31/83 14756.7 10951.0 3805.7 34.75 29.77 ATKIllSON 1 RETIRE 1/84 -54.5 -54.5 ScalERER 2 808 FC ( 8.4% GPC) 2/94 808.0 800.0 TVA It1TERCIIAtIGE ADJUCTHENT 6/84 -54.0 -54.0 UNIT POWER SALES TOTAL 473 MW 9/84 -23.0 -23.0
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TOTAL 8/31/04 15433.2 11430.0 4003.2 35.02 30.26 RUSSELL DAM SEPA IlYDRO ? ? '84 150.0 150.0 VOGTLE 1 1150 230 CLEAR ' e 85 1150.0 1150.0 UNIT POWER SALES TOTAL 500 MW 6/85 -27.0 -27.0 TOTAL 8/31/95 - 16706.2 11907.0 4799.2 40.31 35.73 GASTON A RETIRE (50%) 1/86 -7.9 -7.9 DARTLETTS FERRY HYDRO ADDITION 1/86 100.0 100.0 UNIT POWER SALES TOTAL 507 HW 8/86 -7.0 -7.0 TOTAL 9/31/86 16791.3 - 12303.0 4488.3 36.48 32.05
JANUARY 13,1981 CEORGIA POWEP, COMPANY REPORT NO. 1 PACE 2 SYSTEM EXPAtlSION PLAN PIAN BOPI-WITil SALES 1981 - 1993 NET ---t RESERVES--- UNIT DATE ADJUST. SYSTEM MW LOAD MW RESERVE % RESERVE IF NON FIRH SALE CAPACITY CAPACITY PROJECTED ADDED TO LOAD l i TOTAL 8/31/86 16791.3 12303.0 4488.3 36.48 32.05 ARialRIGilT 1 RETIRC 1/87 -41.7 -41.7 , ATKI:ISON 2 RETIRE 1/87 -61.5 -61.5 RUSSCt.L DAH SEPA P/S 1/87 150.0 150.0 SCllERER 3 808 FC (75.0% CPC) 2/87 800.0 606.0 l ROCKY tloutlTAIN 1-3 PUMP STOR 0/87 675.0 675.0 U231T POWER SALES TOTAL 1015 MW 8/87 -508.0 -500.0 l TOTAL 8/31/87 17611.1 12707.0 4904.1 38.59 38.59 I WOCEERR2 1150 11/87 1150.0 1150.0 ARKWRIGitT 2 RETIRE 1/88 -43.0 -43.0 UtitT POWER SALES TOTAL 1154 MW 8/88 -139.0 -139.0 TOTAL 8/31/88 18579.1 13126.0 5453.1 41.54 41.54 ARI:HRIGil? 3&4 RETIRE 1/89 -88.8 -88.8 HITCllELL 1&2 RETIRE 1/89 -39.7 -39.7 COAT ROCK llYDRO ADDITION 1/89 67.0 67.0 , SCllERER 4 fl0fl FC (75.0% GPC) 2/89 800.0 606.0 1 UNIT POWER SALES TOTAL 1376 MW 8/89 -222.0 -222.0 , TOTAL 8/31/89 19901.6 13600.0 5301.6 38.98 38.98 L ARKWRICIIT SAESB RETIRE 1/90 -26.1 -26.1 U241T POWER SALES TOTAL 1372 MW . 8/90 4.0 4.0 TOTAL 8/31/90 18879.5 14122.0 4757.5 33.69 33.69 , ATKINSON SALSD RETIRE 1/91 -62.6 -62.6 1 ATKINSoff 3&4 RETIRE 1/91 -130.4 -130.4 Ut!IT POWER SALES TOTAL 1347 MW 8/91 25.0 25.0 i TOTAL 9/31/91 18711.5 14674.0 4037.5 27.51 27.51 I flCDONOUGli 3A&3D RETIRE 1/92 -62.6 -62.6 HITCilELL 4A-4C RETIRC 1/92 -94.0 -94.0 BOWEN 6A RETIRE 1/92 -31.3 -31.3 UNIT ROWER SALES TorrAL 132i, < =s 8/92, 18 0 18.0 , TOTAt. 8/31/92 18541.6 15251.0 3290.6 21.58 21.58 0
JANUARY 13.1981 GEORGI A POLIER COMPANY REPORT NO. 1 PAGE 3 SYSTEM EXPANSION PLAN PLAN BOP 1-WITil SALES 1981 - 1993 N ET ---% RESERVES--- UNIT DATE ADJUST. SYSTEH 11W LOAD MW RESERVE % RESERVE IF NON FIRr4 SALE CAPACITY CAPACITY PROJECTED ADDED TO LOAD TOTAL 8/31/92 18541.6 15251.0 3290.6 21.58 21.58 HCMANUS 3A-3C RETIRE 1/93 -124.9 -124.9 GASTott 15.2 RETIRE (50%) 1/93 -257.8 -257.8 PUMPED STORAGE IlYDRO 450 MW 2/93 450.0 450.0 UNIT POWER SALES TOTAL 0 MW 8/93 1329.0 1329.0 TOTAL 8/31/93 19937.8 15865.0 4072.V 25.67 25.67 NOTE: Tile MW ' LOAD PROJECTIONS FOR YEARS 1961-1993 IIAVE DEEN ADJUSTED BY 9 HW TO ACCOUNT FOR Tile SEPA PREFERENCE CUSTOMER DELIVERY TO CRISP COUNTY WilICil WAS NOT INCLUDED IN Tile GEORGIA POWER COMPANY PEAK DEMAND FORECAST OF AUGUST, 1980. e e
'4. (c) - cnd (o)
Supplemental Data Georgia Power Company Territorial System Expansion Plan Reserve Contingencies Col. 1* Col. 2** Col. 3***
% Reserves % Reserves % Reserves 198-1 39.10 40.52 27.51 1982 40.50 45.12 32.40 1983 30.79 34.75 22.58 1984 32.66 35.02 ?3 84 1985 37.47 38.71 29.57 1986 31.03 34.94 26.16 1987 30.20 37.10 29.09 1988 31.23 38.65 32.34 1989 28.35 36.19 30.10 1990 22.89 31.00 25.32 1991 17.15 24.93 20.77 1992 13.15 19.08 16.32 1993 19.11 23.28 21.41
- Georgia Power Company, through Southern Company Services, develops a contingency forecast of territorial peak demand. Data Resources, Inc. is utilized to develop this forecast. Column 1 provides the reserves that are determined by using this forecast. These numbers do not include the non-firm power sales as added load.
** Georgia Power Company currently plans to sell 16.5% ownership in each of the Vogtle units to non-territorial entities. Using Georgia Power Company's primary forecast of territorial peak demand and with 16.5% of the capacity of each Vogtle unit excluded as a territorial resource, the territorial reserves are as indicated in Column 2.
These numbers do not include the non-firm pcwer sales as added load.
*** Georgia Power Company had, at the end of 1980, L 333 MW's of oil fired generation. As a corporate objective the Company is attempting to utilize these resources at an absolute minimum. Column 3 provides the reserve numbers utilizing the Company's primary forecast of territorial peak demand, with oil-fired capacity excluded from reserves, assuming the additional 16.5% sale of each of the Vogtle :
units does not materialize. These numbers do n L fuelude the non-firm power sales as load. NOTE: The reserve amounts shown above are not cumulative; i.e., no column reflects the impact on reserves should more than one contingency occur. For example, the reserves shown in Col. 2 would be lower if they were instead based on the contingency l forecast used to develop the reserves shown in Col. 1. i
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I
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.1 0 0934 4 5 419 3,6 8
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'IESEltVlis Alti! e.nl tied lC !.) Fun Lu 4G-Test!I Po..Est SALES PEA < ilotlU CtP. Pill.lTY, .fliSEf VES. A10 Co unsIllo.4 of CAPAHil.ITY (IssCLtl.IlllG SI:PA PI:EFEHEHCE CH310'IER LnAD)
't;f ANil %DF LOAD 19 56 CtP4!!ILITY CilAeiGES:
ALA r;A3f:ht A (PETlifE) (504) 'I 'lif COTI Tigrrt
'I t flAttfLEeiS FEhitY INC I 0) l1:1 IlYDito GA GASlotl A (REIll?'!) (504) -3 fit 8 Cil:l!! TilRil
- 0 GA' HSPS SALES A!)JilSTI'Eilf -7 :41 HSPS d G'lLF alSPS SALES ADJtlSfalEelf IISS E/ To.3 1 (is iT illE l 7 't.1
-24 'lif 11 spi FOSSI L NM 'lISS d A I Soil 4 (!!E ll RE ) -31 ." rf CUTl 1URit AI.411/JtA CHo!!'il A Gtil.F MISS SYS1E?l f G, ................
LuiD 'i.e fi236 12303 1403 16?9 23337 aiutt.E 4*l -?la 1614 26*t t 0 0 4302 1 16.24 14.01 0.0) 0.00 14.f33
% FodSII. lee 4
6137 61.75 11634 49.2d 199/, 103.60 1981 94.19 21 6751 lu. r.'s PriAM I .f;* W COM:t fth.H -1.3 4 U.45 4S 966 9.73 l.61 31 31 1.34 1013 3.!d) llY0.to -il.e l e.0's 9tK) 0 0 2SO's 7 16.th 3.36 0.tXs 0.tX) ti. I's SEPA .lYato - 1.1 310 1990 3tt 69 1501 3.12 6.49 1.07 3.43 4.91 fitTAI. *l.s 1963 2996 69 100 Sof?! 4 19.75 l1.60 3.3H 4.91 16.59 4 f Held e Italli'i'IP l.O -?l.1 2 11 0 0 0 2II IVA - 81.8 13 21 3 3 40
. ASPS - l.a 0 -50F -143 0 -650 '
a'u l' AL .' b . 224 -4tl6 -140 3 -3CV 2.2S -2. !!? -7.27 0.15 -1.30 fol'AL CAPAIT -:1.5 903H 16702 1925 2014 30660 ItESERVd3 - 11 .8 1102 44519 5 22 315 7332
. 20.67 36.49 31.28 18.54 31.42
.............a.. ........ ....... ....... ....... .......
01/12/H1 15.50 O b e
t i . . . . E . 5 . 2027 22337'l 23 I 00 07 .25 .! 0 9 5 w 5.0 4..31 3 . ts 5
. 1 I 4 3o I
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( lilCl.IIDI 40 SiTA PilEFEREtiCE C'l3Tir4ER LOAD) fill Alla :*.0F LOAD 19 lft C%PAIIILITY CllA JGES: AIA IIA. illy Aall (IIETIltE) -4s ;41 Ctritt TURil r----U GA Al:Ka910.lf 2 (IlEFIRE) -43 lid FOSill g GA GA Vor;fLE 2 i4SPS SAI.ES ADJtiST!!Ei4T 1890 14:1
-130 flif tillCLEAR
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't I SS EA104 2 (llEfIflE) -26 *1ri FUSS IL Q
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ALAllAllA GEODGIA Gliff ill SS SYS1EAl C l_HAD
-48 flu lu 11126 1500 1776 24650 M iltlCI.E A'l - Alif 1614 3ft3'l 0 0 5452 1( 16.41 2d.66 0.00 0.tX) 17.(X)
FOSSIL -!I.1 68)7 7 12093 219fi IH54 22222 O PdAKI4Gs
,C 61.F0 65.09 127.49 96.26 69.38 u Coilli Illifil -14 0 9 46 31 0 097 Y 0.tx) 8.i.20 1. ?lo 0 .tX) 3.11
.lYDl!O -ilif 160'l ISTS U 0 317 3
. *: 16.3S 51. 4 fl 9.00 0. fy) 9.93 SEPA !lYDilo -!!.I 310 1240 38 69 16S7 4 3.15 6.6T 2.20 3 . 5 84 5.17 TOTAL -il.1 191 tl 11841 69 49 S'l3 7
% 19.31 20.3S 4.00 3.5H 18.21 OIlllip s liei EriJP I.0 - 1.s 211 0 0 0
- 2II fVA -!41 13 21 3 3 40 ilSPS *.l .1 0 -1154 -946 0 -1100 (OTAL -el.s 224 -1933 -5 13 3 -1449 4 2.29 -4.10 -3I.50 0.16 -4.32 TOTAL CAPAll -!!.1 9H33 IIS79 1724 1926 32062 If ri3EllVE3 -;11 1263 5453 224 ISO 7412 ,
4 I4.14 41.54 14.93 fl.45 30.07 01/12/U1 15.50 e
GlillEstAl lthi .iXP A ISIO:4 i'L 4 3 'l0P l 9 PIM)POSl?J lill i js:dl G:iled.f A l lfl.1 Aiul filhas ( IPil-l Wi l Cthilliatilil8CY PLAll (IVV2-2005) 11:411 PO .E.1 SALES ALI.0CATED TO GEnitGI A Alli) Gill.F tillTS liESFitVES A:#E seul REHoccio FOR IJNPi-1EIPt s'tW!Est SALES PE%K litMilt CAPA.llLI1Y HESEstVES. ANJ CO'tPOSITIO.4 0F CAPAllILITY (IHCL'JolisG SEP4 PilEFERENCE CUSIO'.lER l>lAI)) fire AHO 20F LOAD 1939 CAPAllll.IlY CllA.4G*iS8 Al.A itILLiili 3 6S4 ft;f FOSill r;A Als .e4 IG.lf 3?.4 (liEIlllEl -T1 141 FOSSIL y tiA GA GOAI HOC < INC SClltillEli 4 ( 7b?.) 67 11;1 605 4tf HYa);lo FOSSIL. GHLF SCIIEllEli 4 (25'4) 202 rtW FOSill GA sabPS sal.ES ADJilSfaENT GalLF ASPS SALES ADJUSTME.41
-222 :t.1 222 'lii
.4SPS (4SPS GA (IllC:lELL I A2 (HiiTIRei) -39 el.f FOSS il.
ALAllA!lA CEnefGI A GULF #4155 SYS~l E81
'M ................
LOAD -:4.4 TP105 13406) 1553 1H83 25440 lillCLE Af P .'t.4 1614 J H3'3 0 0 5452
% 15.39 20.30 0.00 0.00 16.29 Q FOSSIL -M .1 6731 64 . 111 12572 66.51 2400 111.73 1964 96.26 23 % 1 70.40 PEAKI4'i s g Co itt IllRil - 1.1
% 0.00 0 966 5.ll 1.44 31 0.00 0 997 2 . 9 51 ilYlh!O - Je#
160*3 1642 0 0 3250 4 15.33 't . 69 0.00 0.00 9.71 SEPA .lYu'in -i4:1 310 1240 3!I 49 1657 4 2.96 6.56 1. 11 3.54 4.95 IUTAL - 31 11 191H .1943 49 69 5004
% 18.29 20.36 3.25 3. *i'i 17.64 0isliflie ~
f ell'EdllP l.J 't.1 211 0 0 0 211 IVA - 4.8 13 21 3 3 40 *
.3SPS - lit 0 -1316 . -324 0 -17to IllT A L -!11 224 -1356 -321 3 -1449 4 2.14 -7.11 -14.04 0.16 -4.31 TOTAL CAPA'l -il.1 104di 19003 2148 1926 .13464
!E.iERVd3 't,8 Il>U2 5303 595 183 H024
- 7. 19.10 3's.99 38.31 6.23 31.54 01/12/H1 15.50 S h
GEtlFil Al litil '!yP hlSitha PL A I M)P19 Pit 0 POST!.) I!!'!73-iT OlitlH"A f 10.1 A11JI i lo IS ( 1941-l991) Othe fleaGHilCY PIAI ( l 992-203S) 8J.111 Ponfl!.t sal.liS ALLtM:ATED TO GE0;i11A At10 GflLF 04ITS IFESE.tViin Altli reof titilHICl-0 FOR Lo lG-lElt:1 PI).1ER 54LE3 P4AK litHfl2 C \l'I':II.Il Y I<ESE'tVES. 4.41) CtrlPOSITioil 0F CAPA11tl.ITY ( IrvCL'lulesti SliPA PlaiFERENCE C'ISitP4ER LOAO) flu Atel) %0F LO4D IWO CAPA8tILI1Y CilA foliS GA Al'K.l!IG.if SAA5:1 (llETil4El -26 ?til Co.l's T3fRil Q GA ASPS SAI.ES 40JilSr.ElT GilLF HSPS SALES ADJ'JSTME.4f 4 41
-4 4N e4 5.'S siSP3 k Gill.F C.t I S T I t h El itlE)
GilLF Citt.iT 2 (t?ETIPE)
-22 ;4.1
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FOS'ill GIILF CitiST 3 (elf l I.lE) -31 fl.1 Fu5:1II. GUI.F Scal 0LZ 142 flifiTIllEl -9 3 't.f FOSSIL
- llSS EA fo.1 3 (elEflilEI . -24 .l61 FOS 3 II.
ALAllAllA ClitHttil A Gill.F MISS SYSitia [,;i5""" "J.i.i ";57,5- i;;33- "i;,6;- "iil;;- 3;i3i- - seflCLEAR -8. lid 1614 3H39 0 0 5452 C FOSSIL l.1 19.39 6731 20.33 12 S72 0.00 2226 0.00 IH30 16.40 233S9 D .s 64.1H 66.S9 112.99 96.21 70.27 Q PdAKIt318 Co.'.llt filR!! -L1 0 940 31 0 971 1 0.tx) 4 . o'l 1.57- 0.9) 2.92 IlYlhto 'l.3 l(el 1642 0 0 32SO 4 15.J3 4. TO O.00 0.00 9.19 SI PA ilYDfl0 -11.1 310 1240 38 69 1%I A 2.96 6.51 I.93 3.63 4.?n 10l AI. -We 1988 J'f 22 69 69 S 9 751
.; ifl.29 20.24 3.50 3.63 1 1. 671 OlllFR t I:4TE.lilP l.0 - 1.1 218 0 0 0 2 fl fvA - 41 13 21 3 3 40
.4SPb . iei 0 -1372 -32!I 0 -1700 f0TAL -13 224 -1351 -325 3 -1440
*: 2.14 -7.14 -16.S0 0.16 -4.34 -
TOIAL CAPAH -%1 10437 19mit 19/0 1902 33240 IlESERvli3 - 11 1407 4159 363 49 6919
% 1S.30 33.70 22.59 2.64 26.29 01/12/f tl 15.50 e
l . . . . E' . 4 . 2933 700S724H I 00000 .69 .I 0 l . 4 . S1 .F l 0 7 01 I 40437 25 .H5 S .2 . 4 9 6. 25 (. % 9. 7 . 2 74 5 4 ./ Y .7 S . 2 .. 56 127 3' 0 2391 451 I143 3 432 25 1
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CHilf f tiGiii.CY PLAia ( 1992-200S) fl.ill purit!.i SAI.lis AI.I.0CAI.id fu Gain tGI A A;IO ntil.F 11:4I13 illiSERVES AetE Hua HEI)lCEJ Fu,i L u.e ;- lEs:Il P o.tE u S ALlis PE1K llo'lh CAP A.III.IlY. 'isSE'lVliS A.lU Co lPnSITio.1 or CAPAlill.IlY (IllCl.llell;lO SEP A PHEFEREdCE C'ISTo..ll!R LnAl') itH Alld *.0F LnAD r 9 IW2 CAP AllILI1Y Cl!A.lGES: AI.A CillCKASAit 3 (.lEIIREl -41 .lif Fi 'l Al.A YAFES I icilli ASl! 30 tt:1 llYO.eu 7g AI.A 1l1:1I11.03 l uCl?EASli 4 0 't.f IlYD'io Al.A GO.iGAS 6 (Illil litti) -100 Mit l'OSSIL d q GA flu.lFri 6% (Riil illli) - 11 :l.1 Co.ll! Tilftil
> GA PCart.JOUG!I 3A'.315 ( RE fil?ti) -6 3 'lli Carpi IllRil lllCilELL 4 A-4C (HEl lRE)
GA " 74 't.1 Co ll Tilitsi t b , , G% .tSPS S Al.ES AuJUST81E.4T (iJl.F siSPS SALiiS Al>JilST;1E.4T 19 .l.1
-In slet dSPS HSPS IISS Srfs!A rt 1 (IIE1 [HE) -4 7 titt FnS$ 18, 6 % ................ LOAD -?41 ALAllAflA 957f t GlinelG I A IS2SI GilLF 1723 flI SS 1932 SYSlEnt 2Hl23 f
y ................
% N lCI li A.i -;41 4
1614 14.S9 3939 20.70 0
- 0. tx) 0.00 0 24S2 16.35 FOSSIL -i t .'s 7239 12442 2226 I l'13 236H6
% 6%48 41.10 117.41 96.12 71.01 Pd Al' I .I'i t COMit fillif) -;4.. U 6'19 0 0 41 9
.. 0.00 3. 12 0.00 0.00 2.07
,1Yl:PO -4.i 167H 1642 0 0 3.120 7 IS.I7 81 . 9 6 0.00 0.00 9.9S SFPA ;1YDrin *.t.s :sl o 1240 .Rt 69 I N.T 1 2.90 4.49 2.(O 3.72 4.97 loTAL S666
- id 1 9 '881 3 S 11 3!s 49 P. I1.97 19.25 2.00 3.12 16.90 HillEst: .
Ise fli itlP LO -'ini 2II O O O 2II IVA -44 13 21 3 3 40 ASPS -:1.s 0 -1329 -371 0 -1700 folAL -101 224 -13tl -343 3 -1449
;( 2.03 -1.05 -19.41 0.14 -4.34 fol AL CAPAll -:41 11041 1tS43 1396 ,
19S5 33 b5 fiESERytis -:.W. 141s2 3292 173 -11 5232
't IS.4H 21.59 10.04 -3.99 18.60 Ol/12/fl 15.50
( lile!!al AT ithi I? yP A.cilosi PLA I 'MPIO l' linen:iE.) litfl> bil fili;4littA I l'ha A Dal f10 IS ( 174l-194I ) ( m flWilien:Y Pl.Ad ( I W2-2005 ) flillT I"l;i' .tdSALES ALIJ) cal.ii) 10 GEU !GI A Asid Gill.F trillTS IliiSE.tVliS A.<F 110T llED'ICEi) FOR Loil';-fi iill Pfhlli.! sal.liS PaiAl( llo'll' CAPA til.IIY, idESE.IVES. Ad0 Co tPOSillo.4 0F CAPAltiLITY ( lalCl.tlul:63 SEPA Pl?EFEllEHCE CtlS10'tEli LUAU) 101 Atid x0F LOAD 1973 CAPAl!!LITY Clit4GES: ALA Ut.LOCAlsiU Al 7*t3 tirl FOSSIL 4 ALA Pil# STO.I llVD.10 4SO I4'1 elYJiG d Al.A AI.A CASi~0!I 142 (litiTillEl (S0%) Guir;AS /(. dell.fli)
-25'l ;1rf
-I ll s'W FOSS il.
FOSS il. 7M GA CAS A'Ol4 1.t2 ('tET lilEl ( 50:' l -2S't :14 FOS'ill ( H Pil'.lP Sla:t flYiAlu 4 30 .'Atl llYoitu @ GA GA
;4C;4AilllS 3A-3C (l>ErlilEl ilSPS SALES ADJtlSir4E.41
-125 f1N 1329 14.1 Co t:1 Ttilti ilSPS e
g orlLF .iSPS SALES Al3JilSil4E IT 3FI 'l.8 t4SPS j b ................ ALAl:A!44' GFul1GIA GilLF FISS SYS1 tilt LOAl) .4.f 9Hl4 158tSS 1794 1913 ?vo65 (
.1'ICLE A.t 't.1 1614 3ttrl 0 0 S452 .
(C) FOSSIL -;4n
- 13.93 7649 19.25 121H4 0.00 2226 0.tM I 1 13 15.15 2.1:54 2
?. 64.14 61.11 94.19 96.12 66. 2*>
PEAK ilVi8 Col'It I'llWI 'til 0 944 0 0 5/4 4 0.00 2 .'13 0.00 0. tM I.S7 ilYllito -Elil 212fl 2092 0 0 4220 1 17. tt4 10.49 0.00 0.00 11.73 SEPA IlYD6tu *.ld 310 1240 30 69 1651
- r. 2.60 6.22 1.6H 3.72 4.60 10 TAI. 'I.i 2430 3H96 3'l 69 6448 4 20.44 19.54 1.4H 3.12 17.90 0 filEP lill E.l'IP LD - 4.e 211 0 0 0 2II fvA - t.a 13 21 3 3 40 10TAL -'t . a 224 21 3 3 251 1C 1. *M 0.11 0.13 0.16 0.70 l'O l'Al. CAP A't 111 18025 19939 2247 1955 3598 5 It'i.iEif VES -i4 W 2111 4014 493 -IIH ^'721 3 21.91 25.59 27.'07 -S.9ff 23.t'l ,
15.S0 , s C
, 4". (c) and (o)
Supplemental Data The Southern Electric System Expansion Plan Reserve Contingencies Col. 1* Col. 2** Col. 3***
% Rese rves % Reserves % Reserves 1981 43.17 41.43 30.73 1982 41.38 41.48 31.09 1983 33.70 33.30 23.31 1984 33.01 31.56 22.18 1985 34.98 35.01 26.96 1986 30.00 30.60 23.13 1987 26.96 29.56 22.70 1988 25.57 28.53 22.88 1989 26.65 30.05 24.58 1990 20.92 24.84 20.06 1991 18.19 22.19 18.39 1992 14.46 17.25 14.55 1993 20.93 22.50 20.32
*The Southern System, through Southern Company Services , develops a contingency forecast of system peak demand. Data 3esources, Inc.
is utilized to develop this forecast. Column 1 provides the reserves that are determined by using this forecast. These numbers do not include the non-firm power sales as added load.
** Georgia Power Company currently plans to sell 16.5% ownership in each of the Vogtle units to non-Georgia territorial entities.
Using the System's primary forecast of system peak demand and with 16.5% of the capacity of each Vogtle unit excluded as a System's resource, the System rescrves are as indicated in Column 2. These numbers do not include the non-firm power sales as added load.
***The Southern Sys tem had, at the end of 1980, 2,095 MN's of oil fired generation. As an objective the System is attempting to utilize 4
these resources at an absolute minimum. Column 3 provides the reserve numbers utilizing the System's primary forecast of System peak demand, with oil-fired capacity excluded from reserves, assuming the addi-tional 16.5% sale of each of the Vogtle units does not materialize. These numbers do not include the non-firm power sales as load. NOTE: The reserve amounts shown above are not cumulative, i.e.,no column reflects the impact on reserves should more than one contingency occur. For example, the reserves shown in Col. 2 would be lower if they were instead based on the contin-gency forecast used to develop the reserves shown in Col. 1. l 1
1
. 4. d GEORGIA POWER COMPANY PROJECTION OT i FIRM AND NON-FIRM OFF SYSTEM SALES UNIT POWER NON-FIRM SALES-COAL POWER SALES YEAR MW MW 1981 390 1982 546 1983 450 546 1984 473 546 1985 500 546 1986 507 546 1987 1015 1988 1154 1989 1376 1990 1372 1991 1347 1992 1329 1993 N0rES: The Unit Power Sales shown are not finalized. However, these 1 figures represent Georgia Power Company's portion of the pro- i posed sale. Letters of intent verifying these figures have been received, and Georgia Power is optimistic that negotiations can be finali*ed within 90 days. Additional preliminary dis-eussions are currently underway with other utilities which would result in these sales increasing.
l The Nonfirm Power Sales shown are 52 percent (Georgia Power j Company's load ratie) of the Southern System sale. These figures include 208 IG (Georgia Power's share of 400 W) for which only letters of intent are now available. Georgia Power is optimistic that negotiations f or the additional sale can be finalized within 90 days. Due to their nature, Nonfirm Power Sales do not impact any reserve calculations.
5.
. Status of Scheduled Generating Unit Additions to the Georgia Territorial System CPC Dwnership only Actual Expenditures Thru 11-30-80 -- K$
Unit -- GPC Ownership Type Status Code I Completion Direct Plus AFUDC Scherer 1 -- 8.4% Coal C 82.9 86,693* Scherer 2 -- 8.4% Coal C 32.7 13,332* Scherer 3 -- 100.0% Coal C 1.4 -8,051* Scherer 4 -- 100.0% Coal C 0.6 3,465* Vogtle 1 -- 50.7% Nuclear C 32.5 367,624 Vogtle 2 -- 50.7% Nuclear C 13.3 75,265 Russell Dam SEPA Ilydro B -- -- Bartletts Ferry 5 & C -- 100.0% liydro C 1.7 868 Rocky Mountain 1-3' -- 100.01 Ilydro C 5.6 23,884 Goat Rock 7 & 8 -- 100.0% Hydro C 0.05 16 1993 Ptsnped Storage -- 100.0% llydro A - -- s
- Includes CPC ownership of 23.5% of the Scherer Common Facilities associated with each respective unit.
(1) % Completion based on the ratio of expenditures-to-date to total estimated cost, both on a 100% CPC basis. (2) Status Codes are as follows: A -- Early Planning Stage at which the site and energy source has not yet been identified. B -- The Plant site is known and engineering design for the plant has begun but no construction has started. C -- The Plant is currently under construction. 1-12-81
- 6. Our current planning objective is to maintain a minimum reserve l
level for the territory served by Georgia Power Company of 20%- l 25% for reliability purposes. This planning objective is subject to periodic review in light of changes in, among other things, proj ected load growth, economic and financial conditions, system operations, and governmental requirements. The concept of minimum system reliability is itself fluid, depending in part on the cost of attaining a specified level of reliability and the customers ' willingness to pay for such level of reli-ability. i The purpose of maintaining a minimum level of reserves is to protect against unscheduled outages of generating units and to provide a margin for contingencies in future load growth. The forced outage of only one large unit on the Georgia Power system at the time of the system peak demand would reduce available reserves by approximately six to eight percentage points. Georgia Power will have as many as 14 such units on its system during the time period under study. The need to make allowances for contingencies in future load growth is especially important in view of the lead time required to construct new generating units and the relationship between Georgia Power's forecast of future load growth and the projected rate of economic growth in the State of Georgia. For example, if the projected rate of load growth is one percentage point too low, the error in the projected load would reduce a planned reserve margin of 25% to less than 18% in only five years. l l
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The adequacy of a minimum reserve level, for reliability purposes, of 20% to 25% is predicated on a number of assumptions. First, it assumes that Georgia Power will not perform scheduled i maintenance on generating units during the peak summer months. Thus far Georgia Power has not had to schedule planned mainte-nance for that period, but may have to do so at some point during the 1980s as the number of units on the system increases, or if load during the heating season increases as a result of fuel switching by customers. In either case, year-round mainte-nance would result in some capacity being unavailable to reserve the system during the summer peak period. Second, Georgia Power's forecasts of future peak demands assume that the weather ; j at the time of the peak will be normal; i.e., that it will be i typical of temperatures during previous years' peak demands. This assumption is significant because Georgia Power has a - large, weather-sensitive air conditioning load during the summer. For example, during the unusually warm summer of 1980 the maximum peak demand on the Georgia Power territorial i system was 11,154 MW, which exceeds the projected peak demand for 1981 by over 900 MW. Third, the adequacy of a 20%-25% level of raserves assumes that the availability of generating units will equal or exceed the industry average. Unit avail-ability could be adversely affected by changes in regulatory requirements applicable to coal and nuclear power plants, pre-l mature failure of components, and other instances of force majeure.
l Reserves on the Georgia Power system are currently higher than the minimum reserve level of 20%-25%. This situation has resulted from the reduced load growth experienced between 1974 and 1979 (3.15% per year compared to 8.9% for the previous 5 years). The current level of reserves provides an additional margin of safety in the event of the occurrence of contingencies described in the preceding paragraph. In addition, the current level of reserves has resulted in. minimal use of oil-fired generation to serve the Georgia territory (as of December 31, 1980, 1,333 MW of Georgia Power's reserves were oil-fired) . We believe that the long-term reliability of the Georgia Power system is enhanced to the extent the system is not vulnerable to interruptions in the supply of oil.
- 7. Continuation ,f Georgia Power Company's current construction program is desirable for reasons of reliability, economics, and national energy policy. As mentioned previously, maintaining reserves above the minimum level required for minimum system l reliability provides a margin of safety for such contingencies as abnormal weather conditions. In addition, the Cc'pany is able to minimize the use of oil-fired capacity to serve load.
Finally, in the event Georgia Power has underestimated the long-term rate of growth in demand (see, eg. , the results of the contingency forecast of territorial peak demand submitted in connection with Question 4.e.), the system will more easily be able to accomodate the additional load. It is axiomatic that to delay the completion of units under construction increases the cost of such units due .co additional AFUDC accruals and the impact of inflation on con-struction costs. Rather than delaying the completion of these units, Georgia Power has instead elected to build the units on the current schedule and, to the extent the capacity is not immediately required by its territorial customers, sell unit power from the higher-cost coal-fired units at Plant Scherer to other utilities to displace oil-fired generation on those utili-tie's systems (see response to Question 8 for details of those transactions). In this way Georgia Power's territorial customers will receive the benefit of current construction costs without having to pay the carrying costs of the units involved until such i units are required to serve his requirements. The unit power sales benefit the purchasing utilities by permitting them to displace oil-fired generation with coal-fired generation. i
- 8. Georgia Power Company, along with the other operating affiliates of the Southern Company, have entered into non-firm long term capacity sales agreements as follows:
Name Amount Maturity Florida Power & Light 100 MW 12-31-86 . Florida Power Corporation 200 MW 12-31-86 l Jacksonville Electric Authority 100 MW 9-15-85 i Savannah 100 MW 5-31-82 Mississippi Power & Light 200 MW 12-31-86 The operating affiliate companies are also currently negotiating the following ,non-firm long term capacity sales: Name Amount Maturity Florida Power & Light 200 MW 12-31-86 Jacksonville Electric Authority 200 MW 12-31-86 Tallahassee 50 MW 12-31-86 \ The Company believes these contracts will be executed within the next 90 days. The Company has also offered non-firm long term capacity to Florida Power Corporation, South Carolina , Electric & Gas, and Mid-South Utilities. GPC's load ratio
; share of all these sales is approximately 52%. The outcome of these offers cannot be determined at this time.
The company, as one of the operating affiliates of the Southern Company, is currently negotiating firm unit power sales agree-ments with Florida Power & Light and Jacksonville Electric Authority as follows: Approximate Year FP&L JEA GPC Amount 1983 350 300 450 1984 350 300 473 1985 350 300 500 1986 350 300 507 1987 650 700 1,015 1988 1,000 700 1,154 1989 1,000 700 1,376 1990 .__.1,000 _ . _ . . 700 . . 1, 3 7 2 . . 1991 1,000 700 1,347 1992 1,000 700 1,329 The Company is optimistic that these agreements will be , executed within the next 90 days. i The Company has also offered firm unit power to Florida Power i Corporation, South Carolina Electric & Gas, Mid-South Utilities , Savannah Electric Power Company, the City of Orlando, and ' Seminole Electric. The outcome of the offers cannot be deter-mined at this time. !
l
- 8. (Cont'd.) j 1
The principal objective of all these sales efforts is to main-tain the current construction schedule and therefore to avoid the cost of delaying units where contracts with co-owners allow delay, to recover the full cost of all units committed to firm power obligations, and to structure maturities to ensure a reliable system and lowest economic cost to its territorial customers. The obvious national benefit of these sales is the tremen-dous amount of oil displaced on the system of the purchasers. GPC estimates that the 1700 MW's of unit power to be sold to peninsula Florida will displace more than 157 million barrels of oil over the life of the Agreement. GPC estimates that the Southern System will have the capability to make additional sales of firm, non-film and economy capacity and energy to inter-connected utility systems which could displace, at a minimum, an additional 50 million barrels of oil between 1983 and 1992. t
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