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Latest revision as of 18:05, 15 March 2020
| ML19351C941 | |
| Person / Time | |
|---|---|
| Site: | 05000471 |
| Issue date: | 04/01/1980 |
| From: | James Smith BOSTON EDISON CO. |
| To: | |
| References | |
| NUDOCS 8010080401 | |
| Download: ML19351C941 (32) | |
Text
{{#Wiki_filter:. Applicants' Exhibit 22 l
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l NEPOOL FORECAST FOR NEW ENGLAND 1980 - 1995 l DOCKETNUMDER - me.cuam..j"9=.__E . .. . lI g 50 0 April 1, 1980 5*/ f 8010 0B o 401
NEPLAN
.Mw England Awar Planning 174 BRUSH HILL AVENUE WEST SPRINGFIELD, MASSACHUSETTS 01089 TELEPHONE (413) M-5871 JauEs R. sairn E 'D DIRECTOR Energy Facilities Siting Council 73 Trerront Street Boston, Massachusetts 02108 Gentlemen:
On behalf of Boston Edison Ccrrpany, New England Gas and Electric Association, New England Electric System Ccrnpanies, Northeast Utilities System, Eastern Utilities Associates, Fitchburg Gas and Electric Light Cmpany, and Massachusetts Municipal Wholesale Electric Cmpany, enclosed are fifteen cc'ies of a supolemental report entitled, "NEPOOL Forecast for New England - 1980-1995", which report is being jointly filed by said ccrnpanies as part of their long-range forecast of electric power needs and regtu.rements pursuant to Massachusetts General Iaws, Chapter 164, Section 69(i). The "NEPOOL Model for Iong Range Forecasting of Electrical Energy and Derrand" has been used to produce this regional forecast, incorporating, for the first tiJne, some load punagement concepts. Specifically, controlled storage-type electrical
- pace heating and water heating are assumed for the region resulting in about an 800 TM decrease in the otherwise expected 1995 winter peak. 'Ihe resultant annual compound growth rate for 1979 through 1995 is 2.0% for sumner peak, 2.7% for winter peak and 2.6% for energy. 'Ihis is a decrease in the growth rate of about 1.1% in l winter peak and energy and 1.7% in surmer peak frcrn the April 1,1979 report.
Adequate reserves are indicated for the expected peak loads through 1991/92, assuming all five "NEPOOL Planned" units are in service as scheduled, even though tm units do not, as yet, have construction permits._,. Additional capacity vill be required for 1992/93 and beyond. However, with aporoximately 60% of the existing capacity in oil-fired units, energy deficierries could occur in the mid 1980s. It is eswblly critical that all non-cil-fired capacity be built as scheduled and that conservation and load management efforts be continued to prevent energy deficiencies and to achieve the lowest possible price for electric energy. l
- 1 Sincerely, I n %
n L- ( James R. Smith, Secretary NEPOOL Planning Ccrimittee JRS:dv Attachment _m
g, t. NEPOOL FORECAST
- 1980-1995 N'S ENGLAND LONG-RANGE FORECAST OF ELECTRIC POWER NEEDS AND REQUIREMENTS
~
TABLE OF CONTENTS Page No. I
- 1. INTRODUCTION....................................... 1 II.
SUMMARY
i A. Le recasting............................... 1 B. Forecasting Methodology........................ 2 C. Generation..................................... 4 I D. Transmission................................... 5 E. Exhibits
- 1. Forecasting (a) Exhibit I - Peak Load, Energy Actual 1970-79, Forecast 1980-1995.... 6 -
(b) Exhibit II - NEPOOL Model Forecast Summary............................... 7 (c) Exhibit III - NEP00L Model Block Diagram............................... 8 (d) Exhibit IV - Economic / Demographic Module................................ 9 (e) Exhibit V - Residential Submodule..... 10 (f) Exhibit VI - Commercial Submodule..... 11 2 (g) Exhibit VII - Industrial Submodule.... 12 (h) Exhibit VIII - Total Energy and Peak
! Load Diagram..............m... ........ 13
- 2. Generation (a) Exhibit IX - System Capacity-1/1/80... 14 (b) Exhibit X - Rerated and Deactivated Capacity.......................... ... 15 (c) Exhibit XI - Retirement of L ". /... 16 (d) Exhibit XII - Additions to Cay...c:y... 17 (e) Exhibit XIII - Capacity Purchas5s & Sales 18 (f) Exhibit XIII-A-Legend f or Exhibits X-XIIIl9 (g) Exhibit XIV - Winter Capacity......... 20 (h) Exhibit XV - Summer Capacity.......... 21
- 3. Transmission (a) Exhibit XVI - Transmission Additions.. 22 -26 (b) Exhibit XVII - Transmission Maps...... 2 7 - 28 (c) Exhibit XVIII - 345 kV Additions...... 29 i .
a (1)
- - - _ _ _ _ _ _ _ _ _ _ _ - _ _ - _ _ _ _ _ _ _ = . -. _ _ _ _ _ _ _
4 NEPOOL FORECAST 1980 - 1995
- 1. INTRODUCTION The New England Power Pool (NEPOOL) Agreement is an agreement among electric utility systems in New England. The systems making up NEP00L own or control 99.6% of all New England generation.
The objectives of NEPOOL are:
- (a) to assure that the bulk power supply of New England and any adjoining areas served by Participants conforms to proper standards of reliability, and (b) to attain maximum practicable economy, consistent with such proper standards of reliability in the bulk power supply, and to provide for equitable sharing of the re-sulting benefits and costs.
"hese objectives are accomplisheu through joint planning; central dispatching; cooperation in environmental matters; coordinated con-struction, operation, and maintenance of electric generation and transmission facilities; and through effective ccordination with other power pools and utilities situated in the United States and Canada.
II.
SUMMARY
A. Load Forecast The current forecast of electrical power needs for New England is presented in Exhibit I. The forecast shnws coincident winter and , summer peak loads and net energy for the total New England area for the period 1980-1995. These values axclude self-generation by end-users of electricity. As shown in Exhibit I, the New England annual (winter) paa; load is forecast to increase at a compound annual growth rate oi 2.7% from the 1979/80 actual weather-corrected value to 1995/96. The summer peak load is forecast to increase at 2.0% per year from the weather-corrected 1979 actual value to 1995, while net energy is expected to increase at 2.6% per year from 1979 actual to 1995. The "NEPOOL Model for Long-Range Forecasting of Electric Energy and Demand" was completed in July, 1977 and has since undergone exten-sive revision, testing, and verification. This Model has been used to develop Exhibit I. In addition to seasonal peak loads and net energy, a forecast of electric energy sales to ultimate customers, and a forecast of a number of the more important demographic and economic indicators for New England are shown for each forecast year in Exhibit II.
It is important to recognize while examining the forecast data, that the NEPOOL Model is a long-term forecasting model and, therefore, is not designed to project short-term swings around a long-term trend. In addition, for the first time, the currant forecast includes some load management in the form of thermal storage devices for electric space and water heating. These and other details of the forecast and its basic assumptions are pre- ' sented in a report entitled "NEPOOL Model-Base d Forecast of New England Electric Encrgy and Peak Load 1980-1995", copies of which will be available to regulatory bodies from NEPLAN or the indivi-dual NEPOOL Participants. B. Forecasting Methodology The NEPOOL electric energy and peak load forecasting Model is a dynamic simulation model composed of two maj or sectors: an economic /demograpnic sector, and a power sector. The incorpora-tion of an economic / demographic secter in the Model provides the internal capability to develop forecasts of the basic factors which determine the growth of electric energy use for a geographic region. The following description of the sequential steps per-formed 'o y the Model is presented in the interest of creatint a basic comprehension of the Model. Exhibits III through VII; provide a visual description of the Model structure. The Model is initialized (i.e., all variables assigned beginning values) at a given point in time, namely the year 1970. For each year after 1970, the levels of population, labor force and employ-ment are determined in the demographic / economic sector of the Model. (Actual values are used for key Model " variables" from 1970 to the latest date for which data is available. In calculating values for these items, it is assumed that the geographic region's economy and demography will not, in the long run, maintain a separate existence but, rather, the region's economy will function at a level of acti-vity that will just support the population levels, and vice versa. Therefore, the population forecast is not only based upon expected future birth and death rates, but also upon net migration. It is the net migration component of the population growth logic in the Model which links the demographic subsector with the economic sub-secter. The Model treats the demographic subsector is the source of labor supply and the economic subsector provide.= the demand for labor. In broad terms, when the demand for labor exceeds supply, the migration logic simulates the movement of people into the re-gion, and out of the region when labor supply exceeds demand. The population forecast developed in the demographic subsector is used to produce a forecast of the number of households via applica-tion of national projections of household formation trends. In addition, household income is determined from the employment fore-casts and forecasted future wage rates. The household and income projections are combined with income / appliance saturation functions to yield residential appliance saturations and the total number of appliances for most appliance types. Energy consumption by appliance type is determined using the number of appliances, average unit con-nected load and appliance daily load profiles. Other factors included
in the residential energy consumption calculations are federal appliance efficiency standards, electricity price, heating oil price, price elasticity, and long-term (30 year average) expect-ed temperature conditions (for heating and cooling type loads). It is important to note that the Model is driven by national em-ployment growth rates by industry for the forecast period. The forecasted national employment growth rates currently used to drive the Model are secured from Wharton Econometric Forecasting Associates. Employment is forecasted in two separate components-- manufacturing and nonmanufacturing. Manufacturing employment is forecasted based upon the national j employment growth rates by industry modified by a regional cost j index. The cost index measures the cost of doing business in a state relative to the United States. The manufacturing employment
< projections developed in the economic subsector are transformed into dollars of value added by industry using regional productivi-ty growth rates and production employee information. Industrial electric energy consumption (excluding self-generation) is calcu-lated using-value added and electric energy use per dollar of value added by industry. Electricity prices and price elasticity factors are also included in the calculation.
Nonmanuf:ccuring employment is forecasted as a function of state population levels (from the demographic subsector) and expected national employment and population trends. Nonmanufacturing em-p l oym en t from the economic subsector is used as the measure of energy activity in the commercial class of service. The number
, of employees, the electric energy use per employee, electricity 1
prices, price elasticitics, heating oil and gas prices and long-term temperatures are used in calculating commercial electric energy consumption. Total electric energy consumption is determined by summing usage in the residential, industrial, commercial, and miscellaneous classes. Seasonal (summer and winter) peak loads are forecasted by specifying a long-term peak temperature-profile for a day-type and month, and then summing the forecasted load for each of some 50 end-use components for each hour of the day (Exhibit VIII). Annual system load factor is calculated directly from the fore-casted energy (including line losses) and forecasted peak load. A more detailed description of the Model and its development is presented in the " Report on a Model for Long-Range Forecasting
. of Electric Energy and Demand" by NEP00L and Battelle Columbus Laboratories, June 30, 1977. In addition, Model documentation on Model changes since June, 1977 is available to the NEPOOL Participants for distribution to the agencies who received the original report.
.w, - - , - -, , - - - , - , , - - - .
w- . . C. Generation The current New England generation mix (as a percentage of total capacity) for the winter of 1979/80 and the projected generation mix for the winter of 1995/96 are as follows: 1979/80 1995/96 - MW % MW % Base Load (not capable of daily on-line/ off-line cycling) Conv. Steam-Oil 2356 1714
-Coal 337 978 Nuclear 4314 8926 Subtotal 7007 31.9 11618 42.8 Intermediate Cveling Conv. Steam (&CC)-Oil 9669 9280
-Coal 119 1208 9788 44.5 10488 38.7 Hvdroelectric Peaking Conv. & Pumped Storage 2919 13.3 2975 11.0 internal Combustion Peaking Gas Turbines & Diesels 1717 7.8 1860 6.8 Firm Purchases Net Purchases-Sales 539 2.5 179 0.7 Total Capacity 21970 100.0 27120 100.0 The current long-range economic generation planning guidelines as a percentage of system capacity remain the same as reported in 1978 &
1979. The guidelines are: 56 to 62% - Base Load Capacity (all additions to be nuclear) 16 to 20% - Intermediate Cycling Units (fossil-fired) 8 to 11% - Hydroelectric Peaking, Including Pumped Storage 9 to 12% - Internal Combustion Peaking As indicated in these tabuintions, New Enginnd wLil niet have a c h i e v eil its generation mix guidelines by the winter of 1995/96. Further 27,120 MW is not sufficient capacity to maintain ' system reliability in that year. More coal fired capacity capable of daily on-line/off-line cycling is under study by the member companies to meet the 1995/96 system load. The winter and summer rating of the existing system capacity as of Janu.ary 1. 1980 is shown in Exhibit IX . The scheduled recatings, retire ~ ments, authorized additions, purchases, and sales which are projected to occur during the period beginning January 1, 1980 and ending with the Winter of 1995/96 are shown in Exhibits X through XIII-A. Exhibits XIV and XV each respectively reflect the New England generation re-sources to meet forecasted winter and summer seasonal demands for the period 1980 through the winter of 1995/96. ; l l w-
D. Transmission Shown in Exhibit XVII is the backbone of the New England bulk power Transmission system, a network of 230 and 345 kV transmission lines. The New England 345 kV grid is interconnected to the rest of the United States with two 345 kV ties to New York, one from Massachusetts and one from Connecticut, and an additional 230 kV tie *to New York from Massachusetts. These ties to New York are further augmented by four 115 kV ties, three in Vermont and one in Connecticut. A 345 kV tie from Maine to New Brunswick connects the New England grid with the Maritime Power Pool in Canada. Transformers interconnect the 345 kV grid to the underlying lower voltage grid at numerous locations throughout New England. Future 345 kV additions are listed on Exhibit XVI and are shown geo-graphically on Exhibit XVII. These lines are required to satisfy three general criteria as follows: 1
- To provide transmission capability to deliver output of ;
new generation to the transmission grid. l
- To fulfill the need to supply power to load growth areas.
- To maintain system reliability standards throughout the expanding transmission system. ,
The lines, listed on Exhibit XVI are cross-referenced in Exhibit XVIII, i which lists the major reason for their need. When a line provides more than one function, it is listed under more than one category. The planned system provides an integrated transmission grid, which is ne-cessary for NEP00L operations, with resulting benefits such as: reserve sharing, economy interchange and mutual assistance during emergencies. l
__ m DQlIBIT _I New EnglaM Seasonal Ibak loads and Ehergy Ibjuirments Actual Pktered vs. Ptdel Derived and Wather Corrected seer nter Ms Vs. M1 mrwast Net thergy Sismer Pea'. toads (M Winter twak rmw (m for Inad (Gel) 3/InftGET Actml 3/1R9 & del Heather 3/1/79 ftxlel 3/. 77 Actual 3/1/79 ttxlel Weather Ebrecast (brrectal Actual Ebrecast tetered Calibration Cortected Actual Actual Ebrecast stered Calibration (8) (9) (10) (4) (5) (6) (7) 11183 (1) (2) (3) 11643 11052 11708 60402 10305 10972 10596 10674 12115 1970 61470 12135 11730 12514 10915 10966 10856 11069 12979 1971 65208 63343 13548 13013 13629 68638 11837 10963 11987 11918 12624 1972 70587 12852 12333 12770 13079 13119 13167 12741 12677 1973 76202 73585 12891 12406 13376 12141 12399 12821 12143 1974 73216 71531 13908 13912 13812 13614 12842 12573 12514 12161 14379 1975 73700 71470 14739 14395 14859 77000 13116 13320 13575 13125 15364 1976 78310 14846 14930 15363 81589 14234 14523 13712 13918 16037 1977 79781 15111 15500 32500 14458 14588 14954 148 % 16595 1978 67375 15311 15750 84000 14341 14150 15569 1979 91861 4/1/80 4/1/80 FtreeAst 4/1/80 Ebrecast Ebrecast 16110 86220 14190 1980 16250 14210 . + 1981 87240 14400 16590 1982 89090 16 % 0 14630 1983 91130 17390 93480 14910 17870 1984 15180 1985 95830 18420 15530 1986 98530 18960 15920 1987 101490 19500 16300 1988 104410 20040 16660 1989 107300 g 20650 17020 1990 110200 21280 17420 1991 113310 21930 17850 1992 116670 22620 18300 1993 120150 , 23370 18770
- 1994 123820 24170 19280 1995 127750 Omsourd Annual Gmwth Rates (%) Winter Peak Energy Sismer Iwak 7.5 1970/71-72/73 7.9 1970-1973 7.4 2.0 1973/74-79/80 3.6 1974-1979 2.8 2.0 1979/80-95/96 2.7 1979-1995 2.6 hic and weather data; sources: Cols.1, 3, 5, ,, 9 are frun IEtuL rewards; Cols. 4 and 8 are frun tE2uL Model run with actual economic, disawjral (bls. 2, 6,10 are frun NEIOOL Model runs with expectal loryl-tenn peak matler ocn11tions.
D0i! BIT II IMEL FLIEL f0 RECAST SO9WW,1980-1995 Omgani Annual Gruwth Rates Ebrecast 1979- 1980-~ Acttal 1987 19B M 999 1990 1991 1I92 1993 1994 1345 1995 1995 151 0 77 1980 1981 13H M M7984 iM5 1986 Coincident Itak Inad (PW) Fbocrdad: Winter
- 15111 15311 Suprer 14458 14341 hther (a) 2.71 2.74 Correctal: Winter
- 15500 15750 16110 16250 16590 16960 17390 17970 18420 18 % 0 19500 20040 20650 21280 21930 22620 23370 24170 1.95 2.06 Stamer 14954 14150 14190 14210 14400 14630 14910 15180 15530 15920 16300 16660 17020 17420 17850 18300 18770 19280 Dergy Sales to Ultimate Custmers (G41) 2.66
%tal 75289 n/a 79100 80040 81730 83600 85760 87920 90400 93110 95790 98440 101100 103960 107030 110230 113500 117200 2.36 flesidential 28813 Wa 29620 29970 30650 31460 32350 33190 34070 35030 35940 36770 37570 38370 39250 40130 41050 42050 3.08 Industrial 20740 Wa 22700 23450 24080 24630 25240 25850 26580 27400 28250 29200 30200 31200 32260 33350 34540 35770 2.60 Comunercial & Misc. 25736 Wa 26780 26620 27000 27510 28170 28880 29750 30680 11600 32470 33330 34390 35520 36750 38010 39380 h tet DertJy for toad 2.65 2.66 (Gel)(b) 82500 84000 86220 87240 89090 91130 93480 95830 985301014901044101073C0110200113310116670120150123820127750 Annual Inxi Factor (t) (c) 60.76 60.88 61.10 61.29 61.30 61.34 61.36 61.22 61.06 61.11 61.12 61.12 60.92 60,78 60.73 60.64 60.48 60.34 E%onrnic/thsrxJraphic 0.62 0.61 Ibgulation (000's) 12267o l2291"12380 12470 12570 12690 12800 12910 13020 13120 13200 13270 13340 13390 13440 13480 13520 13570 1.50 lbusdolds (000's) 4257 va,4380 4479 4560 4660 4750 4850 4930 5010 5090 5160 5230 5290 5340 5390 5430 5480 0.93 1.11 E>ploynent (000's)(d) 5575 5758' 5660 5710 5790 5870 5960 6040 6130 6210 6280 6340 6400 6460 6520 6570 6630 6680 0.05 Manufacturirvj (000's) Wa Wa 1440 1460 1460 1460 1460 1460 1460 1460 1460 1460 1470 1470 1470 1460 1460 1450 1.45 Rxsnanufacturirvj (000's) Wa Wa p4200 4230 4310 4390 4480 4560 4650 4730 7.4 4800 4860 7.2 4910 7.0 4970 6.8 5030 6.5 5090 6.2 5150 5.9 5210 5.7 Unemployment Rate (t) 5.7p 5.5 8.2 8.4 8.2 8.0 7.9 7.7 7.6 7.5 2.53 tursonal Incum (mil.$69) 54424 Wa 52560 54160 55760 57450 59160 60900 62560 64180 65730 67250 68770 70270 71800 73320 74870 76470 Wa - R>t Available ts P - Prelimirury U '
* - Winter Lejinning s (a) Inad correction tasal on long-tenn historical teak weatler oxulltions. "
(b) a2 sol on energy sales to ultimate cuatrmers and nine percent transinission and distribution line losses. (c) Based on weathererrected pad. locul. (d) ht.31 mploynont includes agproxinutely 21 tjussarwl jobs outside New Dvjland (i.e., New York arul Canada).
EX111 BIT III NEPOOL MODEL ___ ! DEMOGRAPHIC Z,_-h'-""-~N EMPLOYMENT l 1 P l $ 1 P HOUSEHOLDS : HOUSING 0 INCOME CO 1 i P i P 1 P i P ) l POWER
. . . . . . . . . . a. . . . . . . . . . e. . . . . . . . . . . . . . . . . . . . .
8
- 3 5 i g 5 RESIDENTIAL l COMMERCIAL i INDUSTRIAL'Il MISCELLANEDU g
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EX111 Git IV l Economic and Demographic Module nso HATIONAL L3 .{a.RTHRAiES
;_ _ _ _ _ _ _ .;(DEATIt P.MES l=g; o - _ .; _ _ _ _ _ _ _ _ _ , .
"- l g,pME,o NATIONAL pg j .ms m,m i l l 9 e 9 r l "^**=* mST
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- v ' ' I I b HATIONAL MIGRATION mm a
'"g UNEMPLDfMENT RATES OF LADOR
(=== - mRTEMON k'" SENIOR FORCE nggs RATES CITIZENS s EMPIDfMENT
+ BY 900UST2f
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e pg i I 4r 9 r PERSONAL NCOME ( EARNED INCOME PER EMPLDfEE g r d OR A HOlfillOL DS uAss (= INCOME MTHM g RATES g h Pft9ARY , H0tEnDS N DWELLING TYPE - VACANCY RATES 4 HOUSING * ' TM b BY INCOME CLASS , e s d i TOTAL gy g SECOND HOMES 4 HOUSNG HOUSNG N g i i M
- g REMOVAL RATES U M
i EXHIBIT V l
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EX111IIIT VI l Commercia Submodu e No.Of En.ployees , By Commercial Business Category ; 9 Electric Space Htr. Base Load And AirConditioning KWH/knhs By Saturations Business Category
+ +
h Weather Sensitive Annual Energy Price of KWH/ Employees Sy -+ Consumption By 4-- Electricity Business Category Business Category 4 . _ _
+
Daily Load Hourly Demands By p Profiles By Weather 4 Business Category Business Category g a t1 5
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y Y $b b : l
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l t IXIIII3IT VIII Total Energy Consumption . and System Peak Loads l l c a.a, l Industrial - W (industries) Electric I Energy I Commercial' , Consumption (8"Si"*S8 " and Hourty m Peak categories) , Miscesaneous (streetsght, 4 moods, l @ l Line Losses,Etc.) y e
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l i EXilIBIT IX C01POSITIO1 OF NEN DEINJD SYSIM CAPACITY 10R JANUARY 1980 (N) . SLMIER RATItG WIPf!ER RATI?G EXISTING SYSIM 12,010.37* 12,274.53* Conventional '1hermal 4,228.47 4,313.70 tAaclear 1,156.04 1,459.20 Gas Turbines Ccmbined Cycle 183.00 206.00 250.93 258.20 Internal Gmbustion 1,269.77** 1,286.57** Conventional Ilydro 1,632.60 1,632.60 Ptmped Storage 1 20,731.18 21,430.80
'Ibtal Existing System:
CAPACITY PUICIIASED: Within New England 1.00 1.00 5 Boston Edison Co. (From M.D.C.) 4.50 4.50
' Central Maine Power Co. (Frun Industrials)
Outside New England Maine Public Serv. Co. (Fran Me. & 31.00 IEEPCo. , IIID) 31.00 Maine Elec. Pwr. Co. (Eb N.B. Pwr. 400.00 Cam.-C. Cove) 400.00 Vermont Group-Citizens (Frun Ilydro Quebec) 24.50 24.50 Vermont Group (Fran P.A.S.N.Y.) 147.50 147.50 Vernont Group (Fran Ontario Hydro) 30.59 30.59 639.09 639.09 ~
'Ibtal Purchases:
0 100.00 CAPACITY (SAIES): t'l 21,370.27 21,969.89
'IUTAL NEW DEIRO SYSTEN CAPACITY 5H
- Contains units in deactivated 291.07 reserve totaling: 300.50 M
** Contains a unit in deactivated 5.00 5.00 reserve rated:
DGIIBIT X . MTI1DRIZED PERATI!O OF EXISTIIC NIM E2MI/JO GE2JERATItG CAPACITY A?O IDE2(rIFICXTIrti OF UI11'IS IN DF/CTIVA'ITD RESEINE (Jantury 1980 tiuuugh Jarunry 19%) STATIOt3 UNIT EUEL CllANGES IN , SYS11N & UNIT 'IYPE8 TYPERI MAX. CIAIMD M4 EFFE171VE DNIE
. - WI M mi-mY-YFAR Authorized Reratinos New Englarxl Electric System Bellows Falls 33 IIY -
+1.00 +1.00 March 1, 1980 New Englartl Electric Systen Wilder 52 IIY -
+2.00 +2.00 m rch 1, 1980 Fitchburg Gas & Electric Light 57 Gr E02 10.31 +2.40 thy 1, 1980 tbrtheast Utilities 'Ibrners Falls IIY -
+0.60 +0.60 May 1, 1982 Vernont Yankee -
NB UR +12.00 +12.00 tbv. 1, 1982 Fitchburg Gas & Electric Light -- 57 GT ED2 -1.10 -0.50 tbv. 1, 1984 Fitchburg Gas & Electric Light -- 86 ST E06 +0.70 +2.10 Nov. 1, 1986 Fitchburg Gas & Electric Light - 57 Gr ED2 -1.00 -1.50 Nov. 1, 1986 Fitchburg Gas & Electric Light - 87 Gr F02 +2.10 +2.00 lbv. 1, 1989 Fitchburg Gas & Electric Light - 87 Gr ED2 -1.10 -0.50 Nov. 1, 1993 Deactivated Reserve Units (Incltried in 'Ibtal Capability) Eastern Utilities Associates Sanerset il Sr ED6 36.50 37.50 May 1, 1976 5 Sonerset 52 ST E06 40.90 44.00 my 1, 1976 y Smerset 83, 4 ST E06 61.20 64.77 Jan. 1, 1980 IW36 146.27 United Illu tinating Cmpany Steel Pt. 81-8, 10 ST E06 105.80 105.80 Jan. 1, 1976 & Aug. 12, 1977 New England Gas & Electric Co. Cannon St. 57 ST E06 16.40 17.90 July 1, 1977 Fitchburg Gas & Electric Light 96 ST ED6 20.70 21.10 Nov. 1, 1978 tbrtheast Utilities l'Ibrners Falls IIY 5.00 5.00 May 1, 1975 Braintree Electric Light Dept. Allen il Sr ED6 10.00 0.00 Dec. 1, 1979 Allen 83 ST E06 9.00 0.00 Dec. 1, 1979 19.00 0.00
'Ibtal Deactivated Reserve (1/1/80) 305.50 2 % .07 Deactivated Units Returtal to Service tbrtheast Utilities Turners Falls IIY 5.00 5.00 my 1, 1982 Fitchburg Gas & Electric Light 56 ST E06 20.70 21.10 tuv. 1, 1986 Q 5
Deactivated Units Petired a 16.40 17.90 Nov. 1, 1982 x New England Gas & Electric Conpany Canron St. 87 Sr F06
DGIIBIT XI RETIRDiE2frS OF 23EM DEIRO GE23ERATI?U CAPACITY (January 1980 through January 1996) CilAtEES IN F13EL MAX. CIADED N EmCTIVE DNIE STATIOt1 U[JIT POTI1HRY-YEtW
& UtiIT TYPES 'IYPEI B SUtNER - WINIER SYSIU1 2.90 3.70 March 31, 1980 Farmingdale Gr FD2 Central mine Power Ccmpany 13.00 13.50 May 1, 1980 W. Ibward 1-3 Sr FD6 tkvport Electric Cmpany 0.00 4.50 tev. 1, 1981 Graham GP , F02 Bangor ifydro Electric 4.00 4.00 tbv. 1, 1981 ST ED6 Vermont Group Milton 4.54 5.55 tbv. 1, 1981 Rutland i1 Gr F02 Vermont Group 0.75 0.75 tuv. 1, 1982 Iludson Municipal Light Dept. Cherry St. 85 IC FD2 1, 1982 ST FD6 16.40 17.90 Nov.
New England Gas & Elec. Assoc.
- Cannon St. 97 4.80 4.80 Nov. 1, 1983 Cabot 89 Sr FD6 lblyoke Gas & Electric Dept.
4.67 5.85 tbv. 1, 1984 Verwont Grr.;up Rutland 92 Gr FU2 4.50 6.00 Dec. 31, 1986 Danielson il GT FD2 Northeast Utilities 3.80 5.20 Dec. 31, 1986 , 'Ihanpsonville #1 GT FD2 e tbrtheast Utilities 'Ihanpsenville 82 GT F02 4.50 6.10 Dec. 31, 1986 i Northeast Utilities 21.40 22.90 tbv. 1, 1987
$4ason 41 ST ED6 Central thine Power Conpany FD6 50.00 52.00 Dec. 31, 1987 Devon f4 Sr 31, 1987 tbrtheast U (11 ties Sr FD6 48.00 51.00 Dec.
tbrtheast Utilities Demn #5 l FD6 22.20 22.80 lbv. 1, 1992 Mason 52 ST Central Maine Power Cmpany FD6 13.50 16.00 tev. 1, 1992 New England Gas & Electric Assoc. Blackstone fi Sr 2.90 Nov. 1, 1992 Blackstone #3 ST E06 1.80 New England Cas & Electric Assoc. F06 2.00 2.90 Nov. 1, 1992 Blackstone #4 Sr New England Gas & Electric Assoc.
- Deactivated Reserve Unit Retired E
5 Pl s
EX111 BIT XII NJIllORIZED NDITIGS TO NEW F2CINO GE24ERATItG CAPACITY (Januarf 1980 throorih January 19%) NOMINAL STATIO3 UNIT EUEL CAPABILITY - IM EFHX.TIVE DNIE . TYPE 8i SLP9ER - WINIER P0tfl11-DAY-YFAR SYS7Di & UNIT TYPE 9 1.50 1.50 Jan. 1, 1980 Northeast Utilities IMight 82-4 IlY - - Feb. 1, 1980 Barkers !!ill IIY - 1.50 1.50 Central mine Power Conpiny 1, 1980 Bantam IlY - 0.32 0.32 June Northeast Utilities II, 2, 3 IC F02 8.25 8.25 lbv. 1, 1980 Chicopee Municipal Light Plant t, 17.00 17.00 July 1, 1981 New England Electric System Iawrence il & 2 ItY - Nov. 1, 1981 CC ED2 279.00 341.00 Mass, m nicipal Miolesale Electric Stony Brook 6.00 6.00 lbv. . 1, 1981 Public Serv. Co. of New llanpshire Garvins il & 2 fiY - Brunswick /Ibpsham IlY - 12.00 12.00 mrch 1, 1982 Central Maine Power Cappany GP F02 130.00 170.00 Nov. 1, 1982 tilss. Municipal Wiolesale Elec. Stony Brook 1150.00 1150.00 Apr. 1, 1983 Public Serv. Co. of New Ilanpshire Seabrook 01 NP UR 15.00 15.00 June 1, 1983 Northeast Utilities .Iladley Falls 02 11Y UR 1150.00 1150.00 Feb. 1, 1985 Public Serv. Co. of New Ilanpshire Seabrook 82 NP 7 Pilgrim #2 NP UR 1150.00 1150.00 Dec. 1, 1985 Boston Edison C m ' Millstone Pt. #3 NP UR 1150.00 1150.00 my 1, 1986 tbrtheast Utilities ST COL 568.00 568.00 Nov. 1, 1989 Central Maine Power Company Sears Island i 5* H
EXIIIBIT XIII CllA!ES 'IO NB4 DUIMO CAP /CI'IY PUlulASES & SAIES (January G 80 through Jantury 1996) trtu;nVE DA'IE, SUPPLYItG ' NIT FUEL PEP CAPABILITY REI EIVItG TYPEGI SLMER - WINIER f(NIN-DAY-YEAR SYSH24 ' PER SYS'IDI , IUTCIASES
-2.50 -2.50 Jan. 1, 1980 PASIN PP 1, 1980 Vernont Group So. Canada (IF)) PP +4.60 +4.60 feb.
Vernont Group -18.80 -18.80 March 3, 1980 Ontario ifydro #2 PP 1, 1980 Vermont Group Ontario flydro #1 PP +1.96 +1.96 tbv. Vernont Group
-9.20 -29.10 Jan. 1, 1981 So. Canada (10) PP 1, 1981 Vernent Grotp Ontario ifydro il PP +1.97 +1.97 tbv.
Vernont Group
+1.60 0.00 May 1, 1982 So. Canada (10) PP 1, 1982 Vernont Group Ontario ifydro il PP +1. % +1.96 tbv.
Vernont Group -1.00 -1.00 Nov. 1, 1982 Nine Public Service Gmpany Me.&tEETCo, UID PP
+1.60 0.00 May 1, 1983 So. Canada (10) PP 1, 1983 /, Vernont Group +1.96 1.96 Nov.
Vernont Group Ontario ifydro 81 PP m i
+1.70 0.00 May 1, 1984 So. Canada (10) PP 1, 1984 Vermont Grote Ontario ifydro il PP -19.64 -19.64 tbv.
Vernont Group
+2.30 0.00 my 1, 1985
.O. Canada (10) PP Vernont Grotp -1.75 -1.75 July 1, 1985 PP Vernont Group l PASNY F06 -200.00 -200.00 lbv. 1, 1985 N.B.E.P.C. PP feine Electric Power Capany
+1.50 0.00 thy 1, 1986 So. Canada (10) PP 1, 1986 Vernont Grote PP E06 -200.00 -200.00 tbv.
thine Electric Power Capany N.B.E.P.C.
-1.00 -1.00 Nov. 1, 1987 Me.&NBEPCo, UID PP Maine Public Service Ompany
-1.00 -1.00 Nov. 1, 1993 Me.&NBEPCo, L'ID PP Maine Public Service Ompany [
SALES E06 0.00 100.00 By Jan.1, 1980 N.Y.S.E.&G. tbrtheast Util. SP 0.00 -50.00 Nov. 1, 1980 g tbrtheast Util. SP F06 N.Y.S.E.&G. 0.00 +92.00. Nov. 1, 1981 Northeast Util. SP F06 x N.Y.S.E.&G. E06 0.00 -142.00 April 30, 1982 . N.Y.S.E.&G. Northeast Util. SP
- _ .- - _ _ . . = . .
EX1tIBIT XIII-A ,
. IH72D i Description of abbreviations usal under UNIT TYPE PP = Purchase Power SP = Sale of Power ST = Steam turbine - non-nuclear GP = Crmbustion Wrbine IC = Internal Canbustion (Diesel)
IP = Steam-IMR thclear tB = Steam-IMR Nuclear CC = Cmbined Cycle EC = Fuel Cell llY = Conventional Ilydro e PS = Ptmped Storage Hydro H I il Description of codes used under EUEL TYPE ODL = Coal (general) REF = Refuse (solid waste) OIL = Oil (general) FDL l
= tb. 1 Fuel Oil ED2 = tb. 2 Ph31 Oil ED6 = No. 6 Fuel Oil JP = Jet Ftual UR = Uranitsu W = MJOd N
=
H H e
>4 H
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I DQllBIT XIV 20412K2#O G2fEATION Rf3UCES 10 W futEOST [DWO wntIER - W 1980/81 1981/02 1982/83 1983/84 1984/85 1985/86 1986/87 1987/S8 1988/89 1989/90 1990/91 1991/92 1992/93 1993/94 Existirr; Gneratim III 21435 21435 21447 21447 21447 21447 21447 21447 21447 21449 21449 21449 21449 21449 21449 21449
%8 0 0 0 0 0 0 364 182 1165 0 2300 1150 0 0 Arumaal Miltions(2) 12 5741 5741 5741 5741 5741 5741 5741 376 558 1723 1723 4023 5173 5173 1573 omulative Mlitions 12 (0) (0) (0) (0) (45) (0) (0) (0)
(17) (14) (19) (5) (6) (0) (17) (126) Annual Retiremmts (204) (204) (204) (204) (248) (218) (248) (248) omulative petirammts (17) (31) (50) (55) (61) (61) (78) (204) 180 180 180 180 179 179 179 600 601 603 583 381 181 180 180 rwity Purduses 598 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Capacity Sales (50) (142) 1btal Available Capacity' I 21977 22237 22556 23718 23692 25790 26723 265 % 265 % 27166 27166 27166 27122 27120 27120 27120 Projectal Peak Imh 16110 16250 16590 16 % 0 17390 17870 18420 18 % 0 19500 20040 20650 21280 21930 22620 23370 24170 7636 7096 7126 6516 5886 5192 4500 3750 2950 5867 5987 5%6 6758 6302 7920 8303 Nserve Capacity 40.3 36.4 35.6 31.6 27.7 23.7 19.9 16.0 12.2 36.4 36.8 36.0 39.8 36.2 44.3 45.1 Reserve capacity n I (1) Includes Reratings (2) Autlnrized Units only W2s, tim sun of the runted capabilities may differ frun the irulicatal totals. (3) All figures are shown rounlal to the nearest Wole rutier. I k N
. y e
o
, DCilDIT XV f4M 12GN8) Q2aFATICN RESUIES TO PGLT fY)RETAST OtNPN)
St79ER - P4d 1931, 1989 1990 1991 1992 1993 1994 1995 1980 J2HL J291 J28], Jgli. 1995, J986_ _{988_ DcistirrJ Generatim III 20733 20733 20734 20746 20746 20744 20744 20744 20144 20744 20746 20746 20746 20746 20745 20745 2300 0 0 0 568 0 0 0 0 0 Amual Miltions(2) 3 25 297 1295 0 1150 1621 2771 5071 5071 5071 5071 5639 5639 5639 5639 5639 5639 Osrulative M3iticms 3 29 326 1621 (5) (0) (13) (119) (0) (0) (0) (0) (40) (0) (0) Amual Retirarents (16) (0) (9) (17) (5) onrulative Retirerents (24) (42) (46) (51) (51) (64) (183) (183) (183) (183) (183) (223) (223) (223) (16) (16) 621 624 627 608 410 210 209 209 209 209 209 209 208 208 Caprity Purchases 625 618 0 0 0 0 0 0 0 0 0 0 0 0 Capacity Sales 0 0 0 0 "Ibtal Available capacity II 21345 21363 21656 22948 22947 24072 26174 25 % 1 25840 25840 26410 26410 26410 26371 26369 26369 14190 14210 14400 14630 14910 15180 15530 15920 16300 16660 17020 17420 17850 18300 18770 19200 Pro} ectal Peak Imds 8037 8892 10644 10041 9540 9180 9390 8990 8560 8071 7599 -7089 : Neerve Caprity 7155 7153 7256 8318 50.3 50.4 56.9 53.9 58.6 68.5 63.1 58.5 55.1 55.2 51.6 48.0 44.1 40.5 36.8 Reserve Capacity n 50.4 (1) Incliales Herattrujs. i (2) Autlerized Units Only. (3) All figures are shre russial to the nearest winle rmader. 1hus, tJe stsu of the tusukxl capsbilities ney dif fer frun the italicated totals. U T.
-e
AREA: nee ENGLANO OATEs JANUANv 1, 1980 SCNEDULEO AND PR06 08ED CHANGES TRAN8 MISSION LINES SIGN!FICANI TU INTERCONNECTED UPERATION JANUARY 1. 1980 . DELiMutR 31, 1989 CueREMI SCMEDULED OR IERMINUS PROPUSE0 MAP CUMPANY OR PROM TU STATU5 CIRCUIT CONOUCT04 OATE DF MEY COMPANIES 8]AflON
- 10mN STATION + IUwN 8 VULTAGE circuli 8 MILE 8 SIZE SERvlCE NU CHESTNCT JCI. SLACM PUND JCT. A M100LETONN, CT MERIDEN, CT P 345 av i 7.5 2=95eACSR 6/88 MMWEC STONYSROOK STA. LUptow 8/8 P 3e5 av s.1 2=lll3ACSN 9 88 5 LUDLon, MA Luoton, MA i P8NM SEABROOn STATIUN NENINGTON STATION SEASROUme NH NEWINGTON, NH A 345 My 1 18.5 2=lll3ACSR P 'il C NU NU. PLOUMFIELD 8/5 MEEnv!LLE JCf. 2 959ACSM D SLDUMF!ELDe CT MANCMESTEN, CT P 3sl nv i it.? g/88 NEP TEMES8UR f 8/8 GULDEN HILLS 8/5 TEhK88Utt, MA SAUGut, MA A(e) 345 RV l 17.3 2 1598AC8R 5/02 E river CRUSSING REPL UVENHEAD NU SCUvlLL RUCE 8/S MIDDLETOWN, CT EAST MAMPfuN, CI P 3sl RV 2 .F 3508CUCAWLE 6/82 P l
Nu MILL 8 TUNE STA. MILLSTONE N/R g/82 G NATERFORD, CT uATERFORD, CT S 345 Av i 4 2=95 SAC 8N PSNH SEAURLH4 STAT 10N NH/MA STATE LINE N SEABROUM. NH SOUTH MAMPTON, NH P 3s5 MW 1 F.3 2 2356AC84 7/82 IEmM880RY 8/8 2=1590ACSR NEP NH/MA STATE LINE I AME86URY, MA TEnn88URY, MA A 345 Av 1 38.9 2=dl56AC8R 7/82 s STATUS AUlHUNIZED [A) . APPHOWED BY UTIL11Y MANAGEMENT PLANNkD (P) . FACILlllES nHICH HAVE BEEN PudLICLT ANNOUNCEO UNDER STUDY 18) . PAClLIllES IN THE PLANNjNG STAG [8 q
$5
":1 2x m ;! ,
O AREAS NEa ENGLAND DalEt JANUARY 1, 1980 SCMEDULED AND.PROPUSED CMANGES IRANSMISSION LINES SIGNIFICANT TO INTERCONNECTED UPERATIOM JANUARY le 1980 . DECEMBER St. 1989 CURRENT SCME00 LED OR TERMINUS PRODOSED MAP COMPANT OR FROM TU STATUS CIRCUIT CONDUCTON DATE Of REY COMPANIES STATION + TonN STATlHN + TonN s WOLTAGE CIRCUlTS MILES S!IE SERV]CE PSNM CEA8RU0m STATION SC081E PUND S/S SEABROUm, NH LONDONDERRY, NM P 345 KV 1 28.8 2 2156ACSR e/84 J PSNM SCUSIE PUND S/S NM/MA STATE (INE LONDONUERNY, NH PELHAM, NH P 345 av i 18.1 3=1598ACSM g/84 A NEP NN/MA STATE LINE TEnNSSURY S/S En ORACUTe NA TEmm88URYe MA P 345 KV I 4.6 3 1990ACSR g/se m Y BE JURDAN 4U40 MOLBROOK S/S PLYMOUTM, MA MOL8 ROOK, Ma P 345 NV 1 33.2 2 1594ACSR lapse M NEP TEWMS8URY S/S GULDEN MILLS S/S TEmmBOURVe MA SAUGUS, MA P 345 MV i IT.3 3 1590ACSR 5/85 N BE we aALPOLE S/S NEECHAM S/S 2.!!!34CSN mALPOLE, Ma NEEDMAMe MA P 345 RV i 19.T !=2500CU 6/05 0 Nu MEENVILLE JCT. ! MANCHESTEN S/S MANCHESTEd. CT MANCHESTEN, CT P(l) 345 MW l 2.3 2 954ACSR g/85 P Nd MAMPDEN JCI. AG4WAM S/S HAMPDEN, MA AGanAM, MA P 345 av i 14,5 2 95aACSN g/85 0 Nu MANCNESTEN 3/3 MUNTS8ROUR JCT. MANCPESTEH, CT MUNTv!LLE, CT P 345 Av 1 38.0 2 12T2ACSM 1o/85 R s STATUS AUTHONIZED (A) . APPROVED SY OT!LITY MANAGEMENT PLANNED (P) . FACILIIIES mHICM MavE WEEN PUBLICLY ANNUUNCED UNDER STUDY (S) . FACILillES IN THE PLANNING STAGES gm
$5 "3
3x J
AREA 8 NEN ENGLAND DATES JANUARY le 1988 SCHEDULED AND PROPOSED CHANGES TRANSNISSION LINES SIGNIFICANT TO INTERCONNECTED UPERATION JANUARY l, 1988 - DECENGER 31, 1989 CURRENT SCMEDULED OR TERMINUS PROPOSED MAP COMPANY OR PROM TO STATUS CIRCUIT CONDUCTOM Datt De mEV O!2E STAfluN + ToaN STATION + Town s WOLTAGE CIRCUITS MILES SERV!CE COMPANIES ......... ....... .... NU HUNTSSR004 JCT, MILLSTONE S/S NONTVILLEe CT w&TERPORDe CT P 345 AV 1 Set 2 1272ACSR IS/85 R DE MYSTIC STATION LINCOLN ST. S/S EVERETTe M4 SOSTONe MA P 345 RV 1 4.8 25SSCASLE 6/86 T
) BE NOSURN S/S SURLINGTON/SILLERICA Town LINE NOSURN, MA SURLINGTON/SILLERICA P 345 av 1 4.2 2=llt?AC84 6/86 U 8 T0wN LINE, MA NEP SURLINGTON/SILLERICA TENNSSURT S/S TonN LINE SURLINGTON/SILLERICA TEmMSSURY, MA p 345 Av i 6.6 2 954ACSR 6/88 U TOWN LINE, MA NQ PONTLAND JCT. SERLIN S/S PORTLAND, CT l SERLIN, CT P 345 MW $ 8,8 2 12T2ACOR 6/86 W VELCO Cout!DGE S/S h, RUILAND S/S 4 RUTLAND, VT P(2) 345 Av 1 28.8 2 95eACSM 11/86 X CAVENDISHe WT MELCO .. RUTLAND S/S CHA" PLAIN S/S WuTLAND, MT .!LLISTUN, WT S 3e5 Av i 42.5 2 954&CSM 1g/86 Y h.
BE h0 BURN S/S aALTHA* 5/8 muuuRh, Ma m<HAM, MA P 345 av i 13.4 2.lll3ACSM 6/ST I s STATUS AUINUH! LED (A) . APPROVE 0 SY UTILITY MANAGEMENT PLANNED (P) - FACILITIES WHICH HAVE SEEN PUBLICLY ANdOUNCED gn UNDER STUDY (8) . FACILITIES IN THE PLANNING STAGES
$5 "4
3-
AREAS NEu ENGLAND . DATEI JANUARY le 1980 SCHEDULED AND PROPOSED CHAmEES TRANSMISSION LINES SIGNIFICANT TO INTERCONNECTED UPERATION JANUARY le 1980 . DECEMWER 31, 1989 CURRENT SCHEDULED 04 TENMINUS PROPOSED MAP COMPANT OR PROM TO STATUS CIRCUlf CUw0UCTOW D ATE OF REY COMPANIES $1AT10h e T0aN STAi!DN . 10nN s WOLTAGE CIRCu!TS MILES SIZE SERV!CE NU SERLIN 8/5 SOUTHINGION 8/5 AA BERLIN, Cf 80UTHING10N, CT P 3e5 MW 1 18.6 2*954ACOR 8/0F DE NEEDHAM 8/8 NEdiON NEEDMAM, MA NEuTON, MA P 3e5 MW 1 8' /ST SD PSNH DEERFIELD 8/8 WE88TER 8/8 DEERFIELO, NH FRANELINe NH P 3e5 MV l 38.5 2.g 33ACOR 38/87 CC NARN SHERmAN HQ. 8/3 SIG RIVER JCT, BURRIv!LLE, RI w e GREENWICH, RI P 3e5 MW 1 33.0 2=95eAC84 g/88 00 NARM SIG RIVER JCI. MENT COUNTY 8/8
- w. GREENhtCH, RI wARnICKe RI P 3e5 MV I 9.8 a.95eACSR g/88 EE NU 8LACu PONU JCT. u. DEVON JCT. 8/8 HERIDENe Ci STRATFDHDe Cf 8 3e5 av i 38.3 2=954AC8N g/88 FF i
NU E. MALLINGPUND JCI. TOTonET JCT.e NORTH MALLINGFUND, CT SRANFORD, CI 8(5) 3e5 av i F.6 2*95eAC84 g/88 GG UI TUTonET JCT.e NURTH EAST SMUNE 8/5 SRANFORD. CI NEW HAVEN, CT 8(5) 345 av i 6.1 2-95eaC8N g/88 GG LMP 8' SEARS ISLAND STATION UR00n3 8/3
$ EAR 8PURTe ML BROOK 8, ME P 345 RV I 15.8 2=95eAC84 ag/88 II s STATUS AUIHUMIZED (A) . APPNUVED BY UTILITV MANAGEMENT PLANNEU (P) = FACILI!!ES uMICH HAVE SEEN PUBLICLT ANNOUNCED gg (8) . FACILIIIES IN THE PLANNING STAGES nm UNDER STUDT O
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4 EXHIBIT XVIII Additicms to 345 kV Transmission Grid 1980-1989 (Refer to Exhibit XVI for cross reference with " Map Key No.") A. Lines W to provide L.cuandssion c=emh414ty to deliver output of new perat.icn to the L.ar =4 ==4m grid: B, C, H, I, J, M, R, II, B. Lines needed to supply incramaad load: D, E, G, N, P, 0, Q, T, U, W, X, Y, AA, BB l CE, DD, EE, FF, GG, l ! C. Lines needed to maintain systan roliah41ity standards throughout ; th expanding transmission system: A, F, K, U, W, Z, EE, FF, JJ, KK, LL. 1 1
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