ML19331A487

Coordinated Regional Bulk Power Supply Programs, Supplemental Matl, Vol 2

ML19331A487
Person / Time
Site:	Midland
Issue date:	04/01/1978
From:	EAST CENTRAL AREA RELIABILITY COORDINATION AGREEMENT-
To:
Shared Package
ML19331A488	List: ML19331A487 ML19354C322
References
NUDOCS 8007170758
Download: ML19331A487 (26)

Text

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j, VOLUME II r

i COORDINATED REGIONAL l

BULK POWER SUPPLY PROGRAMS (Supplemental Material) q ECAR Information Report I

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Pursuant to December 27, 1977, Request j

By U. S. Department o f line rgy Economic Regulatory Administration April 1, 1978 t t

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q EAST CENTRAL AREA RELIAOILITY COORolNATION AGREEMENT

VOLUME II t

COORDINATED REGIONAL BULK POWER SUPPLY PROGRAM k

k This volume contains the load and capability data provided by each of the reporting utilities in the region.

This is the information that was used to develop the ECAR Region Summary for Items 1 through 4.

The information is compiled in two groups.

The first grouping is for the ECAR Bulk Power Member Systems, and the second i

i is for the ECAR Liaison Member Systems.

The total for the Bulk L

1 Power Members includes data provided by the same group of systems L-that have been included in the ECAR Summary totals in previous responses.

The only change this year is that a response has been provided by each of the four systems that were formerly included j

in the response for the Kentucky-Indiana Pool.

The total for the Liaison Members includes data provided by the twelve."FPC designated" systems plus an accounting of the capacity which will be owned by the Wabash Valley Power Association.

For convenience, the reporting requirements and codes that appear in Volume I for Items 1 through 4 have been repeated here.

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ITEM 1 9)

ESTIMATED ENERGY AND PEAK DEMAND DATA FOR FIRST 10 YEARS i%

The reporting form for this item lists the following:

1.

Actual monthly peak hour demand and net energy data for calendar year 1977.

2.

Estimated monthly peak hour demand and net energy data for calendar years 1978 and 1979.

3.

Estimated summer peak hour demand data for each summer season during the period summer 1978 through summer 1987.

4 Estimated winter peak hour demand data for each winter season during the period winter 1978-79 through winter 1987-88.

5.

Estimated annual net energy data for each of the years 1978 through 1987.

The following definitions were provided by the U.S. Depart-ment of Energy for purposes of the report:

~ ~.

Peak Hour Demand is the maximum integrated clock hour demand reported on the same basis as Not Ener y.

Net Energy is the energy required from all power sources during the reporting period to satisfy the energy require-ments of customers and includes transmission system losses.

This data is reported in Gigawatt hours.

It includes the net energy from installed power sources and energy supplied by other sources such as interconnected utility systems and 9

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industrial sources.

Special attention must be given to the handling of energy sales for resale to avoid duplicate reporting with other systems.

Net Energy does not include

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energy required for pumping of pumped storage generating plants.

For reporting purposes, summer is defined as that period of the year between June 1 and September 30.

Winter is defined as that period between December 1 and March 31.

The period described as Winter 1978 begins on December 1, I

1978 and continues to March 31, 1979.

The data reported for ECAR was obtained by summing the data provided by each of the reporting utilities in the region.

(Refer to Item 8 for this data.)

The listing of these utilities follows:

Code Identification BULK ECAR BULK POWER MEMBER SYSTEMS t

APS Allegheny Power System AEP American Electric Power System CAPC0 Central Area Power Coordination Group CEI The Cleveland Electric Illuminating Company DLCO Duquesne Light Company OE Ohio Edison System TECO The Toledo Edison Company CGGE The Cincinnati Gas and Electric Company CSOE Columbus and Southern Ohio Electric Company DPGL The Dayton Power and Light Company EKPC East Kentucky Power Cooperative, Inc.

IPSL Indianapolis Power and Light Company KU Kentucky Utilities Company LG4E Louisville Gas 4 Electric Company MECS Michigan Electric-Coordinated System CP Consumers Power Company DECO The Detroit Edison Company NIPS Northern Indiana Public Service Company OVEC Ohio Valley Electric Corporation PSI Public Service Company of Indiana, Inc.

SIGE Southern Indiana Gas 4 Electric Company

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Code Identification

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LIAS ECAR LIAISON MEMBER SYSTEMS BIRI Big Rivers Electric Corporation BUCK Buckeye Power, Incorporated CLEV City of Cleveland - Division of Light and Power DPLD

' City-of Detroit - Public Lighting Department ESEC Edison Sault Electric Company t.

HAMI Hamilton Department of Public Utilities - Electric Div.

IIMPL llenderson Municipal Power 6 Light IIED Hoosier Energy Division of Indiana Statewide REC, Inc.

LBWL Lansing Board of Water and Light MMCP Michigan Municipal Cooperative Pool CONA Conalco GIILP Grand llaven Board of Light 6 Power IIART liart flydro Electric LLGP Lowell Light 6 Power NMEC Northern Michigan Electric Coop., Inc.

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TCLP Traverse City Light 6 Power Department j'

WEC Wolverine Electric Cooperative ZBPW Zeeland Board of Public Works l

OMU Owensboro Municipal Utilities RPGL Richmond Power and Light l

NVPA Wabash Valley Power Association M,e l

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ITEM 2

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y A - EXISTING GENERATING CAPABILITY B - FU'TURE GENERATING CAPABILITY INSTALLATIONS AND REMOVALS C - CAPACITY EXCHANGES The reporting forms for this item provide:

A - A listing of existing generating capability in ECAR as of the beginning of calendar year 1978.

B - A listing of all generating capability installations, removals, and equipment upratings and deratings projected in ECAR during the period January 1978 through December 1987.

C - A listing of all scheduled imports and exports that

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involve electric systems which are not included iri the ECAR region.

The amount shown for each capacity exchange listed is the amount which is projected to be in effect at the time of the seasonal peak hour demand of the reporting ECAR utility for each summer and winter peak load season during the period summer 1978 through winter 1987-88.

Transactions have been

, reported only where both parties can be identified.

Additional transactions may be scheduled to acccmmodate l

a change.in conditions or requirements.

i The codes and abbreviations used for this item, as well as similar tabulations which are included under Item 8, follow.

Identification of ECAR systems - refer to listing of syst' ems under Item 1.

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N Identification of Non-ECAR Systems -

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Code Identification AGC

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i Alcoa Generating Corporation CPEL CIPS Carolina Power and Light Company Central CLOV Illinois Public Service Company

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CECO Cloverland Electric Cooperative DUKE Commonwealth Edison Company Duke Power Company EEI Electric Energy, Incorporated IPCO Illinois Power Company JSPR OH Jasper Municipal Electric Utility Ontario Hydro PIQ SEPA Piqua Municipal Power System Southeastern Power Administration UGI United Gas Improvement USCE UPPP United States Corps of Engineers VEPCO Upper Peninsula Power Company i

WIMI Virginia Electric and Power Company Wisconsin Michigan Power Company Unit Type Code -

3 1

I Item 2 Item 8 Identification ST STEAM Steam Turbine - Non-nuclear NB BWR Steam - BWR Nuclear NP PWR Steam - PWR Nuclear i

NH HTGR Steam - HTGR Nuclear-i IC INT.C Internal Combustion l

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GT COMB.T Combustion' Turbine i

HY HYDRO Conventional Hydro l

PS PSH Pumped Storage Hydro CA CC-STM Combined Cycle-Steam Portion-Auxiliary 1 CT CC-CT Combined Cycle-Combustion Turbine Portit JE JET Jet Engine i

UN UNKNOWN Unidentified I

l ZZ OTHER None of the Above - described in footno:.

Fuel Type Code -

i Item 2 Item 8 Identification COL COAL Coal (general)

NG NATGAS Natural Gas j

SNG SYNGAS Synthetic Natural Gas i

i F01

1. 1 OIL No. 1 Fuel Oil F02

1. 2 OIL No. 2 Fuel Oil f

j F04

1. 4 OIL No. 4 Fuel Oil i

F05

1. 5 OIL No. 5 Fuel Oil I

s F06

1. 6 OIL No. 6 Fuel Oil KER KEROSENd Kerosenc JF JET FUEL Jet Fuel I

CRU CRUDE Crude l

UR URANIUM Uranium I

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UNK UNKNOWN Unknown at this time Til TIIORIUM Thorium

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NONE None (for alternate fuel) i 2-ii

Principal Method of Transporting Fuel to the Plant Site -

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Item 2 Item 8 Identification i

WA WATER Water Transportation TK TRUCK Truck RR RAIL Railroad PL PIPE Pipeline CV CONVEYOR Conveyor XX UNKNOWN Unknown at this time None (for alternate fuel)

Status of Projected Changes -

Item 2 Item 8 Identification P

PLANNED Planned for installation but not authorized for construction L

PENDING Under design, or authorized, or construction.

license pending U

UNDERWAY Under Construction A

UPRATE Generating unit capability increased (rerated or relicensed)

D DERATE Generating unit capability decreased

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(rerated or relicensed)

M INACTIVE Generating unit in deactivated shutdown status S

RETURNED Generating unit returned to service from deactivated shutdown status i

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R REMOVED Generating unit permanently removed from any service l

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ITEM 3 A - RESOURCES, PEAK DEMANDS, AND MARGINS B - ASSESSMENT OF ADEQUACY OF ADJUSTED MARGINS o

The reporting forms for this item provide:

A - A tabulation of the estimated resources, peak demand, and margin for the ECAR region at the time of the pro-jected seasonal peak hour demand for each summer and winter season during the period summer 1978 through winter 1987-88.

The entries on lines of through 10 were.obtained by summing the data provided by each of the reporting utilities in the region (see Item 8).

Line 11, Scheduled Outage, provide > an indication of the level of planned maintenance expected in ECAR.

The estimate was prepared for purposes of this report fQg only and is based on the level of planned maintenance that is currently projected for the periods of heaviest load demand during the upcoming summer and winter

seasons, i.e.,

two percent of total installed capability during the summer of 1978 and five percent of total installed capability during the winter of 1978-79.

l B - An assessment of the adequacy of'the margins indicated

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for the initial five years of the reporting period.

The assessment is mot couched in terms of the adjusted margin because in the appraisal procedure employed by I

ECAR scheduled maintenance requirements are treated in l

l much the same manner as other facets of unavailability l

of generating equipment.

The overall load characteristic l

in ECAR is such that some amount of maintenance is l

scheduled throughout each month of the year.

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ITEM 4

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ESTIMATED DEMAND AND RESOURCES FOR Tilli 11 TO 20 YEAR PERIOD A

This item provides an estimate of the annual peak demand in the ECAR region for each year during the period 1988 through 1997.

It also provides an estimate of the total resources which are believed to be necessary to. serve that demand.

(Refer to Item 8 for data provided.by reporting utilities.)

The expected " mix" of the capability additions during this period, in percent of total additions, has also been indicated.

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ITEM 8 ADDITIONAL ?!ATERIAL FOR CLARIFICATION The U.S. Department of Energy Economic Regulatory Adminis-tration included this item so that each Reliability Council.would have the option to submit information in addition to that provided under Items 1 through 7 that is either deemed necessary for clari-fication or to present specific. characteristics of the region.

1 The material provided by ECAR lists the load and capability data that was provided by each of the reporting utilities in the region and which was used to develop the ECAR Region Summary that appears in Volume I.

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REGION ECAR PARTY MECS IIEM I ESTIMA1ED DEMAND & ENERGY FOR THE FIRST 10 YEARS f

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MICHIGAN ELECTRIC COORDINATED SYSTEM 1977 JAN.

FEB.

MAR.

APR.

MAY JUNE JULY AUG.

SEPT.

OCT.

NOV.

DEC.

(PREVIOUS YEAR)

LINE 01 PEAK HOUR DEMAND-MW 10235 9892 9265 9164 10554 10880 11923 10674 10437 9359 10138 10278 02 NET ENERGT-GWH 5939 5133 5459 5003 5414 5398 5921 5754 5335 5407 5438 5673 1978 (REPORTING YEAR)

LINE 03 PEAK HOUR DEMAND-MW 10292 10112 9751 9562 9863 11348 11989 11989 11057. 10103 10778 11028

. as 04 NET ENERGY-GWH 5950 5420 5755 5410 5465 5780 6040 6125 5645:

5865 5675 5865 5:

rn 1979 O

(NEXT YEAR)

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LINE 05 PEAK HOUR DEMAND-MW 10736 10510 10014 9722 10019 11595 12275 12275 11252 10199 11002 11304 06 NET ENERGY-GWH 4035 5450 5840 5470 5630 5825 6110 6250 5725 5990 5750 5895 1ST 10 YEARS 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1.INE 07 PEAK HOUR DEMANDS SUMMER-MW 11989 12275 13080 13671 14271 14812 15346 15960 16592 17246 08 PEAK HOUR DEMAND WINTER-MW 11028 11304 11953 12430 12907 13316 13753 14255 14759 15297 09 HET ENERGY-GWit 69000 70000 74700 77900 81300 84200 87200 90300 93700 97200 U

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REGION ECAR ITEM 2-A PARTY MLCS EXISTING GENERATING CAPABIL11Y

( AT THE BEGINNING OF CALENDAR. YEAR 1970) tt1CHILAN ELECTRIC COORDINATED SYSTEMS e

NET CAPADILITY--MW

--PRIMARY. FUEL---

ALTERNATE FUEL----

LOC UNIT TRANSPORT TRANSPORT DAYS SYSTEM STATION NAME AND UNIT NO CODE TYPE DEMON. SU.1MER WINTER TYPE METHOD TYPE METHOD USE NOTES 01 02 03 04 04.5 05 06 07 OG 09 10 11 12 CP uEADOCK 1 26017 STEArt 42 42 42 CRUDE PIPE NONE CP WEADDCK 2 26017 STEAM 42 42 42 CRUDE PIPE NONE CP WEADOCK 3 26017 STEAM 62 62.

62 CRUDE PIPE NONE CP WEADuch 4 26017 STEAM 62 62 62 CRUDE PIPE NONE CP WEADOCK'5 24017 STEAM 72 72 72 CRUDE PIPE NONE 26017 STEAri 72 72 72 CRUDE PIPE HONE CP WEADOCK 6 7

blATION TOTAL 320 320 320 1

3:

N CP WEADOCK 7 26017 STEArt 165 163 165 COAL RAIL NONE Y*

CP WEADOCK 0 26017 STEAM 165 163 165 COAL RAIL NONE N

CP WEADOCK A 26017. COMB.T 21 19 21 NATGAS PIPE NONE STATION TOTAL 351 345 351 CP car.PBELL 1 26139 STEAM 267 267 267 COAL RAIL NONE CP CAMPBELL 2 26137 STEAM 372 372 372-COAL RAIL NONE CP CAMPIELL A 26139 CoriB.T 21 19 21 31 OIL TRUCK NONE STATION TOTAL 660 658 660 CP hARN 1 26017 STEAM 275 275 275 COAL RAIL NONE CP AARN 2 26017 STEAM 275 275 275 COAL' RAIL NONE CP hAFN 3 26017 STEAli 500 500 500 C6 OIL RAIL HONE 2

CP hARN 4 26017 STEAM 500 500 500 C6 OIL RAIL NONE 2

STATION TOTAL 1550 1550 1550 CP COBB 1 26121 STEAM 68 67 48 COAL WATER NONE CP CubB 2 26121 STEAh 68 67 68 CUAL WATER NONE.

CP CCd8 3 26121 STEAM 68 67 68 COAL WATER HONE CP COBB 4 26121 STEAM 150 157 158 CDAL WATER NONE CP COBD 5 24121 SIEAli 167 16o 167 COAL WATER HONE ST ATION 10T AL 529 524 529

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CP WITING 1 26115 STEAM 106 106

-106 COAL HAIL NONE x

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REGION ECAR ITEM 2-A Pt.RTY'MECS EXISTING GENERATING CAPABILITY (AT THE 14EGINNING OF CALEt4DAR YEAR 1979)

- - -MICHIGAN ELECTRIC COORDINATED SYSTEMS NET CAPABILITY--MW LOC UNIT

--PRIMARY FUEL---

-ALTERNATE FUEL----

SYSTEM STATION NAME AND UNIT NO CODE TYPE DEMON.

SUrit1ER - WINTER TYPE METHOD TYPE HETHOD USE NOTES TRANSPORT TRANSPORT DAYS 01 02 03 04 04.5 05 06 07 08 09 10 11 12

= _ _. ---- ------

CP WHITING 2 24115 STEAM 106 106 106 COAL HAIL NONC CP

-WHITING 3 26115 STEAM 133 131 133 COAL RAIL NONE CP WHITING A 26115 COMB.T 21 19 21 31 DIL TRUCK NONC STATION TOTAL,

366 362 366 CP MORROW i 26077 STEAN 41 41 41 46 OIL 1 RUCK NATGAS PIPE 4

CP MORROW 2 26077 STEAM 41 41

.41 46 OIL 1 RUCK NATGAS PIPE 4

x CP MORROW 3 26077 STEAM 60 60 60 46 OIL TRUCK NATGAS PIPE 4

E CP MORROW 4 Y

24077 STEAM

'4R 68 68 G6 OIL TRUCK NATGAS PIPE 4

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SUB TOTAL 190 190 190 CP -

HORROW A&B 5

26077 COMB.T 30 30 38 NATGAS PIPE NONE STATION TOTAL 220 220 228 CP PALISADES 26159 PWR 730 635 730 URANIUM TRUCK NONE CP BIG ROCK POINT 26029 BWR 61 61 61 URANIUM TRUCK.

NONE CP THETFORD 1-4 26049 COMB.T 168 148 168 NATGAS PIPE NONE CP THETFORD b-9 26049 COMB.T 110 90 110 42 OIL TRUCK NONE STATI0t4 TOTAL 278 238 278 CP GAYLORD 1-5 26137 COMB.T 97 79 97 NA1 GAS PIPE 42 OIL TRUCK 4

CP STRAITS 26047 COMP.T*

20 24 28 NATGAS P1PE NONE CP HYDRUS HYDRO 134 134 134 NONE 3

CP LUDINGTON (CP SHARE) 26105 PSH 954 ~

954 9b4 NONC CP TOTAL 6286 4104 6206 DECO ST. CLAIR l' 26147 STEAM 163 163 163 COAL WATER 46 OIL WATER e

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I REGIDH ECAR ITEM 2-A PARTY MECS EXISTING GENERATING CAPABILI TY (AT THE BEGINNING OF CALENDAR YEAR 1970)

MICHIGAN E.ECTRIC COOFDINATED SYSTEMS 1

NET CAPABILITY--MW

--PRIMARY FUEL---

---

ALTERNATE FUEL----

LOC UNIT TRANSPORT TRANSPORT DAYS S) STEM STATION NAME AND UNIT NO CODE TYPE DEMON. SUMMER WINTER TYFE METHOD TYPE METHOD USE NOTES 01 02 03 04 04.5 05 06 07 03 09 10 11 12 DECO ST. CLAIR 2 26147 STEAM 162 162 162 COAL WATER 06 OIL WATER LECO ST. CLAIR 3 26147 STEAM 162 162 162 COAL WATER 46 OIL WATER DECO ST. CLAIR 4 26147 STEAM 163 163 163 COAL WATER 06 OIL WATER DECO ST. CLAIR 5 26147 STEAM 300 300 300 46 OIL WATER NONE LECO ST. CLAIR 6 26147 STEAM 315 315 315 COAT WATER NONE DECO ST. CLAIR 7

• 26147 STEAM 465 465 465 COAL WAIER NONE LEsa Si. LinIk 11 2o14/ COnb.T 23 20 23 42 U1L 1RULA NAIGAS PIPE

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I.ECO ST. CLAIR 12 26147 INT.C 5

5 5

42 OIL TRUCN HONE x

E STATION TOTAL 1758 1755 1758 P

DECD TRENTON CHANNEL 7 26163 STEAM 140 135 140 COAL RAIL NONE DECO TRENTON CHANNEL 8 26163 STEAM 117 115 117 COAL RAIL NONE SUB TOTAL 203 203 203 10 UECO TRENTON CHANNEL 9 26163 STEAM 505 505 505 COAL RAIL NONC STATION TOTAL 708 700 700 DECO RIVER ROUGE 1 26163 STEAM 206 199 206 46 OIL WATER NONE DECO RIVER ROUGE.2 26163 STEAM 262 257 262 COAL RAIL 36 OIL WATER DECO RIVER RGUGE 3 26163 STEAM 308 301 300 56 OIL WATER NONE DECD RIVER ROUGE 26163 INT.C 11 11 11 02 OIL TRUCh NONE STATION TOTAL 787 768 737 DECO CONNERS CREEK 8 26163 STEAM 34 32 34 32 OIL WATER NATGAS PIPE DECO CONNERS CREEK 9 26163 STEAM 33 31 33 32 OIL WATER NATGAS PIPE bECO CONNERS CREEK 10 26163 STEAM 34 32 34 32 OIL WAIER NATGAS PIPE DECO CONNERS CRLEK 12 26163 STEAM 46 63 66 42 OIL WATER NATGAS PIPE DECO CONNERS CREEK 13 26163 STE AM 66 63 66 C2 OIL WATER NATGAS PIPE DECO CDt4H1 3 LHELK 14 26163 STEAM 66 63 46 32 OIL WATLR NATGAS PIPE DFCO CONNEh5 LREFN 15 26163 SILAN 129 125 123 COAL WAltR NONE DECO COUNLRS CREEh 16 26163 STEAM 128 125 128 COAL WATER NDHE SUB IOTAL 395

~370 395 1

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EXISTING GENERATING CAPABILITY (AT THE BEGINNING OF CALENDAR )E6R 1970)

MICHIGAN ELECTRIC CODRDINATED SYSTEMS NET CAPABILITY--hW

--PRIMARY FUEL- --

---

ALTERNATE FUEL----

LOC UNIT SYSTEM STATION NAME AND UNIT NO CODE TYPE der.ON. SUMMER WINTER lYPE METHOD TYPE METHOD USE NOTES TRANSPORT TRANSPORT DAYS 01 02 03 04 04.5

-05 06 07 08 09 10 11 12

_ = - -

DECO CONNERS CREEK 26163 INT.C -

-5 5

5 32 OIL WATER NONE-

_ STATION TOTAL 400-383 400 DECO DELRAY 11 26163 STEAN 54 54 54 36 OIL WATER NATGAS PIPE-DECD DELRAY 12 26163 STEAH 54 54 54 46 OIL WATER NAIGAS PIPE DECO DELPAr 13 Y

26163 STEAM 54 51 54 26 OIL WATER NATGAS PIFE SUD TOTAL 151 151 151 n

Y 1400 DELHAf 14 26163 STEAM B4 84 84-26 OIL WATER NATGAS PIPE 6

DECO DELRAf 15 26163 STEAN' 84 84' B4 46 OIL WATER NATGAS PIPE DECO DELRAY 16 26163 STEAN 04.

04 84 46 OIL WATER NATGAS PDE SUB TOTAL 235 235 235 6

STATION TOTAL 386 386 306 DECO MONROE 1 26115 STEaN 750 750 750 COAL RAIL NONE DECO MONROE 2 26115 STEAM 750 750 750-COAL RAIL NONE DECO MONROE 3 26115 STEAM 750 750 750 CDAL RAIL NONE DECO MONkOE 4 26115 STEAH 750

-750 750 COAL RAIL NONE DECO MONRUE 26115 INT.C.

14 14 14 42 OIL TRUG NDHE STAIION TOTAL 3034 3014 3014 DECO MARYSVILLE 6 26147 STEAN 52 49 52 COAL WATER NONE DECD HARTSVILLE 7 26147 STEAM DB D4 08 COAL WAIER NONE DECO NARfSVILLE 8 26147 STEAM 88 04 48' 00AL WATER

.NONE-STATION TOTAL 146 146 146 6

' DECO FERHI I 26115 SIEnn 161

.161 161

't2 OIL TPUEA NONE DECO FERHI 11 26115 Curiu.T 79 50 77 12 Olt Ikbd NONE i

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REGION ECAR liEM 2-A PARTY MECS EXISTING GENERATING CAFABILITY (AT THE LEGINNING OF CALENDAR YEAR 1978)

MICHIGAN ELECTRIC 000RDINATED SYSTEMS NET CAPABILITY--nW

--FRIMARY FUEL---

---

ALTERNATE FUEL----

LOC UNIT TRANSPORT TRANSPORT DAYS SYSTEM STATION NAME AND UNIT NO CODE TYFE DEMON. SUMMER WINTER TYPE METHOD TYPE HETHOD USE NOTES 01 02 03 04 04.5 05 06 07 OG 07 10 11 12

=-_ ---- -----

STATION TOTAL 240 219 240 DECO HARBOR BEACH 1 26063 STEAM 110 110 110 COAL WATER NONE DECO HARBOR BEACH 26063 INT.C 4

4 4

12 OIL TRUCK NONE SIAT10N IOIAL 114 114 114 LECO FENNSALT 26163 STEAM 14 14 14 COAL WATER C2 OIL WATER 8

R DECO BEACON 26163 STEAM 21 21 21 NATGAS PIPE 22 OIL TRUCK OECO PORT HURON PAPER 26147 STEAM 5

5 5

COAL TRUCK 42 OIL TRUCK 9

LECO FORT HURON PAPER 26147 INT.C 5

5 5

42 OIL TRUCK HONE STATION TOTAL 10 10 10 DECO PUTNAM 26157 INT.C 14 14 14 02 OIL TRUCK HONE LECO NORTHEAST 11 260?? ConB.T 80 53 80 NATGAS PIFE NONE LECO NORTHEAST 12 260?? COMB.T 26 20 26 32 OIL TRUCK NATGAS PIPE LECO NORTHEAST 13 260?? COnB.T 40 37 40 42 OIL TRUCK HONE STATION TOTAL 154 117 154 DECD HANCOCK 11-12 26125 Cohb.T 194 151 194 NATGAS PIPE NONE LECO SUPERIOR 11 26161 COMB.T 00 53 80 32 OIL TRUCK NONE DECO PLACID 11 26125 INT.C 14 14 14 32 OIL TRUCK HONE DECO FLACID 12 24125 INT.C 14 14 14 42 OIL 1 RUCK NGHE

$1ATION TOTAL 23 20 23 LECO COLFAX 26093 INT.C 14 14 1t 42 OIL TRUCA NONE LECO OLIVER 26063 INT.C 14 14 le 22 OIL 1 RUCK NONE

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REGION ECAR ITEM 2-A PARTY MECS EXISTING GENERATING CAPABILITY (AT THE BEGINNING OF CALENDAR YEAR 1978)

HICHIGAN ELECTRIC COORDINATED SYSTEM 3 NET CAPABILITY--nW

--PRIMARY FUEL---

ALTERNATE FUEL----

LOC UNIT

=-

TRANSPORT TRANSPORT DAYS SYSTEM STATION NAME AND UNIT NO CODE TYPE DEMON. SUnMER WINTER TYPE NETHOD TYPE METHOD USE NOTES 01 02 03 04 04.5 05 06 07 08 09 10 11 12

. _ = = = -

DECU SLOCUM 26163 INT.C 14 14 14 32 OIL TRUCK NONE DECO WILMOT 26063 INT.C 14 14 14 42 OIL TRUCK HONE DECO DAYTON 26115 INT.C 10 to 10 42 OIL TRUCK NONE Y

. DECO LUDINGTON (DE SHARE) 26105 PSH 918 918 918 NONE ri i

DECO TOTAL 9052 0090 9052 4

q NECS GRAND TOTAL 1533a

'14994 15338 NOTES j

1-BOILER LIMITED 9"

2 INITIAL RATING 3 35 UNITS LOCATED IN NORTHERN AND WESTERN LOWER HICHIGAN GROUPED IN THE FOLLOWING LOCATIONS COUNTY CODE NO. OF UHITS NW 26001 2

0 a

26005 3

3

'i 26067 2

3 26069 10 30 26101 3

21 26107 4

6 26123 7

41 26135 2

4 26165 2

10 TOTAL 35 134 4 NO CHANi>E IN CAPABILITY, UNITS CAN OPERAIE OH' AllLRNAT'E FUEL INDEFINITELY LUBJECT ONLY TO FUEL AVAILABILIT(.(GAS CURRENlLY NOT AVAILABLE)

J 5 SN0hE LINITnTION

REGION ECAR Ilth 2-A PARTY nCCG EXISTING GENERATING CAPABILITY (AT THE BEDINNING OF CALENDAR YEAR 1978) oICHIGAN ELECTRIC COORDINATED SYSTEMS o CUSTOMER LIMITATION 7

TOTAL OF FIVE BOILERS, ONE BURNS COAL OR 42 OIL, ONE DURNS DAS AND THREE BURN GAS OR 42 OIL.

(PORT HURON PAPER) 8 SEE NOTE 84 AND 46 9 SEE NOTE 86 AND #7.

10 SEE NOTE il AND 46 e

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ITEM 2-B FARTY MECS,

FUTURE GENERATING CAPABILITY INSTALLATIONS AND REMOVALS (AFTER THE BEGINNING OF CALENDAR YEAR 1978)

MICNIGAN ELECTRIC COORDINATED SYSTEMS NET CAPABILITY IN MW --PRIMARY FUEL--

-ALTERNATE FUEL-LOC UNIT TRANSPORT

.. SYSTEM STATION NAME AND UNIT.NO CODE TYPE DEMON. SUMMER WINTER TYPE ~

METHOD TYPE. TRANSPORT EFFECTIVE METNOD.

DATE-NOTES STATUS 01 02-03 04 04.5 05 06 07 08 09 10 11 12 13

=--_--

1978 CP CAMPBELL 1 26139 STEAM

-4

-4

-4 COAL RAIL NONE FEBRUARY DERATE CP BIG ROCK POINT 26029 BWR 4

4 4

URANIUM TRUCK NONE FEBRUARY UPRATE CP PALISADES 1 26159 PWR 10 0

10 URANIUM. TRUCK NONE APRIL UPRATE CP KARN 3 26017 STEAM 144 131 144 46 OIL RAIL NONE JUNE UFRATE o.

CP KARN 4 26017 STEAM.

163 152 163 46 OIL RAIL NONE JUNE OPRATE 1978 TOTAL 317-283 317 1979 DECO GREENWOOD 1 26147 STEAM 780 780 780 46 OIL

. PIPE NONE APRIL UNDERWAY 1979' TOTAL

' 780 780 780 1980 CP CAMPBELL 3 26139 STEAM 791 791 791 COAL RAIL NONE MAY UNDERWAY DECO

.ENRICO FERMI 2 26115 BWR 1093 1093 1093 -URANIUM TRUCK NONE DECEMBER UNDERWAY 1980 TOTAL 1884 1884 1884 1981 0

m p6 wir

['

REPN ECAR ITEM 2-B PARTY MECS

_ = _ -

FUTURE GENERATING CAPABILITY INSTALLATIONS AND REMOVALS (AFTER THE BEGINNING OF CALENDAR ' TEAR 1978)

MICHIGAN ELECTRIC COORDINATED SYSTEMS NET CAPABILITY IN MW --PRIMARY FUEL--

-ALTERNATE FUEL-LOC UNIT

- = -

TRANSPORT TRANSPORT EFFECTIVE SYSTEM STATION NAME AND UNIT NO CODE TYPE DEMON. SUMMER WINTER TYPE NETHOD TYPE METHOD DATE NOTES STATUS 01 02 03 04 04.5 05 06 07 08 09 10 11 12 13

- - ------ =

== --

CP PALISADES 1 26159 PWR

-740

-635

-740 URANIUM TRUCK NONE MARCH 2 INACTIVE CP MIDLAND 2 26111 PWR 805 805 805.

URANIUM TRUCK NONE MARCH UNDERWAY CP KARN 1 26017 STEAM

-4

-20

-4, CDAL RAIL NONE JUNE 1

DERATE CP EARN 2 26017 STEAM

-3

-15

-3' COAL RAIL NONE JUNE 1

DERATE

a. CP WEADOCK 1-6 26017 STEAM

-4

-19

-4 CRUDE PIPE NONE JUNE 1

DERATE CP WEADUCK 7-8 26017 STEAM

-4

-19

-4 COAL RAIL NONE JUNE 1

DERATE vs; 1981 TOTAL 50 97 50 o

1982 CP MIDLAND 1 26111 PWR 530 530 530 URANIUM TRUCK HONE MARCH UNDERWAY 1982 TOTAL 530 530 530 1983 DECO PELLE RIVER 1 26147 STEAM 676 676 676 COAL WATER tiONE MARCH UNDERWAY CP PALISADES 1 26159 PWR 740 635 740 URANIUM TRUCK NONE MARCH RETURNED' CP MORROW 1 26077 STEAM

-33

-38

-38 46 OIL TRUCK NATGAS PIPE MAY REMOVED dh g y....

.7

4 g)

• .}

l.

.GION ECAR ITEM 2-B PARTY MECS FUTURE GENERATING CAPABILITY-INSTALLATIONS AND REMOVALS (AFTER THE BEGINNING OF CALENDAR YEAR 1978)

=

MICHIGAN ELECTRIC COORDINATED SYSTEMS NET CAPABILITY IN MW --PRIMARY FUEL--

-ALTERNATE FUEL-LOC UNIT TRANSPORT TRANSPORT EFFECTIVE SYSTEM; STATION NAME AND UNIT NO CODE TYPE DEMON. SUMMER WINTER TYPE METHOD TYPE METHOD DATE NOTES STATUS 01 02 03 04 04.5 05 06 07 08 09 10 11 12 13

- =.

CP MORROW 2 26077 STEAM

-30

-38

,-38 86 OIL TRUCK NATGAS PIPE MAY REMOVED 1983 TOTAL 1340 1235 1340 1984 DECO BELLE RIVER 2

.26147 STEAM 676 676 676 COAL WATER NONE MARCH UNDERWAY a.

1984 TOTAL 676 676 676 1985 tn HO ADDITIONS OR REMOVALS 1986 DECO UNASSIGNED STEAM 650 650 650 COAL RAIL NONE APRIL PLANNED 1986 TOTAL 650 650 650 1987 CP MORROW 3 26077 STEAM

-54

-54

-54 46 OIL TRUCK NATGAS PIPE JANUARY REMOVED CP MORROW 4 26077 STEAM

-60

-60

-40 46 OIL TRUCK NATGAS PIPE JANUARY REMOVED CP CAMPBELL 2 26139 STEAM 53 b3 53 COAL RAIL NONE MARCH UPRATE i

LECO UNASSIGNED PWR 1208 1208 1200 URANIUH 1 RUCK NONE MARCH PLANNED

-1987 TOTAL 1147 1147 1147

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REGION c.C 1

PARTY MECS

[

i ITEM 3-A ESTIMATED RESOURCES, DEriAND & MARGIN FOR THE 1 TO 10 YEAR PERIOD MICHIGAN ELECTRIC C00RDIN41ED SYSTEM

~

LINE 1978 1979 1980 1981 1982

===_

RESOURCES IN MW SUM.

WIN.

SUM.

WIN.

SUM.

WIN.

SUM.

WIN.

SUM.

WIN.

=

01 NET CAPABILITY 15277 15655 16057 16435 16848 18319 18038 18369 18568 18899 02 SCHEDULED IMPORTS 620 20 20 20 20 218 270 278 292 292 03 SCHEDULED EXPORTS 624 624 624 624 684 903 1077 1077 1175 1175 04 TOTAL RESOURCES 15273 15051 15453 15831 16184 17634 17239 17570 17685 18016 05 INOPERABLE CAPABILITY 0

0 0

0

. 0 0

0 0-0 0

06 OPERALLE RESOURCES 15273 15051 15453 15831 16184 17634 17239 17570 17685 18016 DEMAND IN MW 07 PEAK HOUR DEMAND 11989 11028 12275 11304 13080 11953 13671 12430 14271 12907 08 INTERRUPTIDLE DEMAND 0

0 0

0 0

0 0

0 0

0 s.g-09 DEMAND REQUIREMENTS 11989 11028 12275 11304 13080-11953 13671 12430 14271 12907 m

O.

==

=

.p.4 p,(

d,l p-

1. ,g p

MARGIN IN MW

'3 9

t,.

10 MARGIN 3284 4023 3178-4527 3104 5681 3568 5140 3414 5109 LINE 1983 1984 1985 1986 1987' RESOURCES IN MW SUM.

. WIN.

SUM.

WIN.

SUM.

WIN.

SUM.

WIN.

SUM.

KIN.

===- _ ------ -..--

01 NET CAPABILITY 19803 20239 20479 20915 20479 20915 21129 21565 22276 22712 02 SCHEDULED IMPORTS 256 256

-220 220 179 179 134 134 99 99 03 SCHEDULED EXPORTS 1175 863 863 863 863 863 863 863 863 863 04 TOTAL RESOURCES 18884 19632 19036 20272 19795 20231 20400 20836 21512 21940 05-IHOPERABLE CAPABILITY 0

0 0

0 0

0 0

0 0

0 06 OPERABLE RESOURCES 18884 19632 19836 20272 19795 20231 20400 20836 21512 21948 DEMAND IN MW 07.

PEAK HOUR DEMAND 14812 13316 15346 13753 15960 14255 16592 14759 17246 15297 08 INTERRUPTIBLE DEMAND 0

0 0

0 0

0 0

0 0

0 09 DEMAND REOUIREMENTS 14812 13316 15346 13753 15960 14255 16592 14759 17246 15297

%,f p.'l q),0 y

MARDIN IN MW 3

7 10 MARGIN

.4072 6316 4490 6519 3835 59/6 3808 6077 4266' 6651 1

y ee ITEM 4 REGION ECAR PARTY MECS ESTIMATED PEAK DEMAND AND RESOURCES FOR THE 11 TO 20 YEAR PERIOD--MW P

p i

L MICHIGAN ELECTRIC COORDINATED SYSTEM i

PEAK RESOURCES HOUR TO SERVE DEMAND DEMAND 01 02 d

1988 18000 21700 1989 18000 23000 1990 19500 23200 1991 20200 24200 f'

1992 20900 24900 f

1993 21800 26000 l

l 1994 22600 26800 1995 23400 27900 1996 24100 29000 1997 24900 30300 STATEMENT OF PROJECTED CAPABILITY ADDITIONS DURING THIS PERIOD.

UNKNOWN OR HYDRO NUCLEAR FOSSIL OTHER TOTAL I

PERCENT 0

72 28 0

100

(

(

L 8-MECS-14