Text

Carroll County Nuclear Station Alternate Transmission Assessment Rept, Revision 1
	ML20032C757
Person / Time
Site:	05000599, 05000600
Issue date:	09/30/1981
From:	; ENERGY, DEPT. OF
To:	;
Shared Package
ML20032C756	List: ML20032C755; ML20032C757;
References
	NUDOCS 8111110645
	Download: ML20032C757 (82)
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{{#Wiki_filter:, CARROLL COUNTY NUCLEAR STATION ALTERNATE 3 TRANSMISSION ASSESSMENT l (REVISION #1 SEPTEMBER 1981) 8:11110645 811023 PDR ADOCK 05000599 i A pop

[ 2 FORWARD At the request of the NRC staff, the DOE staff, specifically from the Division of Utility Systems and Emergency Communications, initiated a review of the projected costs and right-of-way requirements for the transmission network additions needed to fully transmit the net power output of two 1,100 MW generating units from the proposed Carroll County Station and several alternate sites. Reference material included: o Carroll County Station - Site Suitability - Environmental Report (CCS-SS-ER), submitted by the Commonwealth Edison Company to the NRC (April.h 1979 with revisions). o MAIN Regional Reliability Council Coordinated Bulk Power Supply Program, submitted by the Mid-America Interpool Network to the U.S. Department of Energy ( April 1, 1981). o Carroll County Alternative Site Selection Study, prepared for the NRC by the Argonne National Laboratory ( April 2, 1980). The specific ownership agreements for the proposed Carroll County Station, Units 1 and 2 are as follows: Commonwealth Edison Company (CECO) 75% Interstate Power Company (ISP) 15% Iowa-Illinois Gas & Electric Company (IIG&E) 10% 100% Commonwealth Edison Company in its environmental report presents six reasons for selecting the Carroll County Site for the proposed two nuclear units. These are: o Environmental suitability and no other site was shown to be more suitable on an overall basis, o The lowest cost alternative at this time. o Provides for geographic dispersion of generating and transmission facilities on the Commonwealth Edison Company system. l o Facilitates implementation of the joint-ownership agreement. o Establishes a large power plant site that may not otherwise remain available for future siting needs. o Provides added flexibility in future system expansion planning. l

p 3 The Argonne analysis of the Commonwealth Edison reasons indicate that the weight given to the last four of these arguments by the NRC staff is crucial to the acceptance or rejection of the Commonwealth Edison Company's power plant site choice. Further, the Argonne report states that the weight given to these arguments will depend upon the findings of the DOE staff review of the transmission and system integration facilities for each alternate site. The Argonne study concludes that all of the currently developed candidate sites: Braidwood, Byron, L a Salle County and Quad Cities were more environmentally preferable to the Carroll County Site, and also that the Carroll County Site was not significantly more environmentally preferable to any of the other identified undeveloped sites. Therefore, the DOE staff using the applicant's proposed Carroll County transmission expansion plan, developed transmission plans for each of the alternate sites. The proposed facilities would fully integrate the 2,200 megawatts of net electric output from each of the projected generating plant sites into the regional power grid. I I I l l I

r 4 ASSESSMENT Particular emphasis was given to the achieving equivalent levels of transmission system adequacy at each of the alternate sites. The planning criteria of the Mid-America Interpool Network and the Commonwealth Edison Company were regarded as the minimum standards applicable at all sites. Detailed transmission criteria, as adopted by the Mid-America Interpool Network is included as Appendix I. In addition, the DOE staff utilized other pertinent documents, maps and diagrams to identify the transmission requirements associated with each site. It is important to note that the major load centers to be served by the Carroll County Station are located in the cities of Rockford and Chicago, Illinois. The transmission system requirements for the Carroll County nuclear power plant site and each alternate site in this investi-gation are significantly affected by the geographical location of generation and load in the Commonwealth Edison Company service area and in the Mid-America Interpool Network region. The transmission facilities developed in this report for the Carroll County Site and for each alternate site are those required to fully integrate that plant's maximum net electrical output of 2,200 MW into the regional power grid after consideration of the Commonwealth Edison Company and the Mid-America Interpool Network planning criteria. Considerations for already developed sites involved the incremental addition of 2,200 megawatts at those sites. It cannot be concluded that the transmission facilites at the alternate sites are the same as might be required to develop the plant with different ownership ratios, or when other 1 regional power plant construction has occurred. This document has not been discussed with or reviewed by the Commonwealth Edison Company or the Mid-America Interpool Network. The actual incremental transmission and substation costs could vary substantially from one candidate site to the next. Such costs are very dependent upon the voltage level used to transmit i the plant's output, the location of the site, and its geological nature, including drainage and/or rock blasting requircaents. Transmission voltage greatly influences the cost of installing transmission facilities. Although a 765-kV circuit regtires larger towers, more conductors per phase (Commonwealth 1:dison Standard) and approximately double the width of the right-of-way of a 345-kV configuration, one 765-kV circuit provides about r six times the power transfer capability of a single 345-kV circuit. l-i l l I

r 5 Transmission voltage selection must take into consideration the immediate and future transmission requirements, the distance to the load centers, and the relative cost. Each of the candidate sites was analyzed in this manner to determine the necessary number and voltage of transmission lines required. Commonwealth Edison Ccmpany has a policy that where practical the first two generatir4g units at a site will be connected to the 345-kV regional grid and any additional units at that site will be connected to the 765-hv regional grid. This concept was employed in this analysis to assure a realistic evaluation. The cost data used in the specific site evaluations were based on estimates that reflect expected typical line and substation costs in the Illinois area utilizing 1991 dollars. The Commonwealth Edison Company supplied much of this data (Appendix II). These typical unit costs are intended to reflect the total construction expenses associated with the installation of the facilities. However, rights-of-way costs were not included since land costs are very dependent on the terrain features and its use. ( I l l I l

6 Transmission System Connections at Each Site An aspect of electric system reliability planning is to disperse generating sites and transmission corridors as widely as possible. If an undue concentration of generating capacity and associated transmission facilities is allowed, then the probability of a common-event multiple outage of generation or transmission is increased. This could, in turn, lead to a cascading outage situation. However, geographic dispersal of generation and transmission facilities does not implicitly indicate " increased system reliability." The DOE staff concurs that, wherever possible, the amount of generation at any one site should reflect a small percentage of the total system capability and EHV transmission lines should not be restricted to a single corridor (right-of-way) nor should an excessive number of circuit crossovers exist. The present ownership and operating agreements with ISP and IIG&E apply to the Carroll County Site only. This is not to imply that the other parties would not be agreeable to sharing generation at a different site. In the following sections, transmission system requirements are discussed for the Carroll County Site, and each of the alternate candidate sites. i l l l I .a

r 7 A. Carroll County Site The undeveloped Carroll County Site is located in northwestern Illinois. The site is 4.5 miles southeast of the City of Savanna, Illinois, and 2.7 miles east of the Mississippi River in Carroll County. It is situated west of the major CECO load centers. All existing CECO bulk power electric transmission facilities are located to the south and east. The proposed transmission system arrangement for the Carroll County Site is shown in Figure 1. Three double-circuit 345-kV transmission lines have been proposed by CECO to transmit the 2,200 megawatts of electric power output from the Carroll County power plant to the existing regional bulk power electric network. The proposed transmission system features three double-circuit 345-kV transmission lines emanating from the Carroll County Station, such that a tower failure could occur causing two circuits to be outaged without limiting the full-load operation of the plant. Additionally, this plan provides for the reinforcement of two remote regional 345-kV lines with the other participating parties (Interstate Power Company and Icwa-Illinois Gas and Electric Company). CECO proposed a double ring bus circuit breaker arrangement at the Carroll County power plant. This arrangement is diagrammed in Figure 2. This substation circuit breaker arrangement provides a very high degree of reliability through the redundancy of the equipment. Since CECO proposed this circuit breaker arrangement for Carroll County, this concept was utilized as the basis for all other sites. Inclusion of the station circuit breaker arrangement in the transmission plans for each alternate site provides an important consideration in the cost comparisons. The specifics of the proposed transmission expansion follow.

a 8 A. Carroll County Site Specific transmission line lengths and '.erminals are as follow: Carroll County - Quad Cities Power Plant 2-345-kV circuits 35 miles Carroll County - Byron Power Plant 2-345-kV circuits 78 miles - Charter Grove Carroll County - Salem and Rock Creek 2-345-kV circuits 79* miles Substations

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) i Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV Carroll County 113 0 1,986 0 1,986

Although the location for the Mississippi River crossing has not been finalized, ISP is holding discussions with the Fish and Wildlife Service, the Iowa and Illinois Departments of Conservation and the U.S. Army Corps of Engineers concerning the selection of the crossing location.

The Mississippi River crossing to Iowa is to be done by the partner utilities. The right-of-way and cost data reflect only the CECO portions since the Early Review request was submitted by CECO as the major party. (b) Right-of-way widths assumed to be 250 feet for the 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. f i r )

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r-3 11 A. Carroll County Site

SUMMARY

CF ESTIMATED COSTS FOR CARROLL COUNTY STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) Carroll County 116.8 28.2 0.0 145.0 (2) Transmission Six 345-kV circuits from Carroll County for a total of 113 miles @ 345-kV $116.8* (3) Substation Sixteen 345-kV breakers and ten 345-kV line terminals $28.2 Total $145.0 * (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. Actual projected cost data supplied by CECO. 9 wt y 2 y +

12 B. Biggsville, Gladstone, Rozetta Sites The undeveloped Biggsville, Gladstone and Rozetta Sites are all located in the general vicinity of each other in Henderson County in western Illinois. The Biggsville Site is located 0.5 miles southwest of the town of Biggsville, Illinois. The Gladstone Site is located 2.5 miles northeast of the town of Gladstone, Illinois. The Rozetta Site is located 5.3 miles southwest of the town of Little York, Illinois. All of these proposed candidate sites are situated in southwestern Illinois approximately 175 miles from the major CECO load centers. All existing bulk electric transmission facilities are located to the north and the east. The proposed transmission expansion for these sites feature two 765-kV circuits going to different terminal points utilizing different rights-of-way. The 765-kV voltage was selected due to the distance of these sites from the major load centers on the Commonwealth Edison system. In addition to the two 765-kV circuits, one 345-kV circuit is proposed with each expansion to satisfy the NRC emergency off-site power requirement. The specifics of these proposed transmission expansions follow. l l l t

13 B. Biggsville Site The proposed transmission facilities and breaker arrangements for the Diggsville Site are included as Figures 3 and 4, respectively. The projected costs and right-of-way requirements are also included. The specific transmission line lengths and terminals are as follows: Biggsville - La Salle County Power Plant 1-765-kV circuit 155 miles Biggsville - Plano 1-765-kV circuit 194 miles Biggsville - Louisa 1-345-kV circuit 48 miles

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIFEMENTS (Acres) Transmission New Right of Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV Biggsville 48 349 844 10,576 11,420 (b) Right-of-way widths assumed to be 250 feet for 765-kV line and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. l l 1 l l l

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SUMMARY

OF ESTIMATED COSTS FOR BIGGSVILLE STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) Biggsville 612.6 150.9 49.3 812.8 (2) Transmission Two 765-kV circuits from Biggsville for a total of 349 miles @ 765-kV $560.5 One 345-kV double circuit from Biggsville for a total of 48 miles @ 345-kV 52.1 Total $612.6* (3) Substation Nine 765-kV breakers and four 765-kV line terminals $41.8 l Eight 345-kV breakers and four 345-kV line terminals $14.1 Miscellaneous equipment additions / modifications (4) 595.0 (Two 1500 MVA 765/345-kV transformers Three 1000 MVA 765/345-kV transformers) TOTAL $150.9* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect Costs. (4) Addition of or replacement of transformers, site preparation and/or modification at all affected substations in proposed plan.

Actual projected cost data supplied by CECO.

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17 B. Gladstone Site The proposed transmission facilities and breaker arrangements for the Gladstone Site are shown in Figures 3 and 5, respectively. The estimated costs and right-of-way requirements are also included. The specific transmission line lengths and terminals are as follows: Gladstone - La Salle County Power Plant 1-765-kV circuit 152 miles Gladstone - Plano 1-765-kV circuit 191 miles Gladstone - Louisa 1-345-XV circuit 45 miles

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV Gladstone 45 343 791 10,394 11,185 (b) Right-of-Way widths assumed to be 250 feet for 765-kV lines and i 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. 1 I l l I i l i 1 i I l l l l

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20 B. Gladstone Site

SUMMARY

OF ESTIMATED COSTS FOR GL ADSTONE STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) Gladstone 599.7* 147.4* 48.5* 795.6* (2) Transmission Two 765-kV circuits from Gladstone for a total of 343 miles @ 765-kV $550.8* One 345-kV double circuit from Gladstone for a total of 45 miles @ 345-kV 48.9* Total $599.7* (3) Substation Nine 765-kV breakers and four 765-kV line terminals $41.8* Six 345-kV breakers and four 345-kV line terminals $10.6* Miscellaneous equipment additions / modifications (4) 595.0* (Two 1500 MVA 765/345-kV transformers Three 1000 MVA 765/345-kV transformers) Total $147.4* (1) 1991 Dollars - Includes 7.5% escalation pet year and 25% for indirect costs. 1 (4) Addition of or replacement of transformers, site preparation and/or modification at all affected substations in proposed plan.

Estimated using CECO unit cost data supplied and the Biggsville expansion as a base.

21 B. Rozetta Site The proposed' transmission facilities and breaker arrangements for the Rozetta Site are included as Figures 6 and 7, respectively. The 1 projected costs and right-of-way requirements are also included. The specific transmission line lengths and terminals are as follows: Rozetta - La Salle County Power Plant 1-765-kV circuit 143 miles Rozetta - Plano 1-765-kV circuit 182 miles Rozetta - Louisa 1-345-kV circuit 44 miles

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-KV 765-KV 345-KV 765-KV Rozetta 44 325 773 9,848 10,621 (b) Right-of-way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. J l .-,,~,,,,,,,,,-.-------, -,-

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24 B. Rozetta Site

SUMMARY

OF ESTIMATED COSTS FOR ROZETTA STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) Rozetta 569.7* 147.4* 45.9* 763.0* (2) Transmission Two 765-kV circuits from Rozetta for a total of 325 miles @ 765-kV $521.9* One 345-kV double circuit from Rozetta for a total of 44 miles @ 345-kV 47.8* Total $569.7* (3) Substation Nine 765-kV breakers and four 765-KV line terminals $41.8* Six 345-kV breakers and four 345-kV line terminals $10.6* Miscellaneous equipment additions / modifications (4) $95.0* (Two 1500 MVA 765/345-kV transformers Three 1000 MVA 765/345-kV Transformers) Total S147.4* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. (4) Addition of or replacement of transformers, site preparation and/or modification at all affected substations in proposed plan. Estimated using CECO unit cost data supplied and the Biggsville expansion as a base.

25 <?. g3. ord, Hillview, Milton Sites The undeveloped Concord, Hillview and Milton Sites are all located in the same general area of Illinois. The Concord Site is located in Morgan County about 0.1 mile west of the town of Concord, Illinois. The Hillview Site is located in Greene County approximately 3 miles west of the town of Whitehall, Illinois. The Milton Site is located in Pike County about 1.3 miles southeast of the town of Milton, Illinois. All of these proposed candidate sites are located in the southwestern part of Illinois, some miles from the major CECO load centers. All of the existing bulk power electric transmission facilities are located to the north and east. The proposed transmission expansion for these sites feature two 765-kV circuits going to different terminal goints along different rights-of-way. Additionally, these plans call for a transformation from 765-kV to 345-kV at a future Station M along with two new 345-kV circuits from Station M which will integrate into the existing 345-kV network in the area. This 765-kV expansion was chosen due to the distance of these sites from the major CECO load centers. Also, an additional 345-kV circuit is proposed for each expansion to satisfy the N7C emergency off-site power requirement. The specifics of the proposed transmission expansions follow. y

26 C. Concord Site 4 The proposed transmission facilities and breaker arrangements for the Concord Site are shown as Figures 8 and 9, respectively. The projected costs and right-of-way requirements are also shown. j The specific transmission line lengths and terminals are as follows: Concord - Station M 1-765-kV circuit 30 miles StatiGn 14 - Powerton 1-345-kV circuit 55 miles Str. tion M - Kincaid (initially or,erated at 345-kV) 1-765-kV circuit 58 miles Concord - La Salle County Power Plant 1-765-kV circuit 200 miles Concord - Meredosia (double circuit 138-kV)** 2-138-kV circuits 7 miles

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV (e) Concord 120 230 2,847 6,970 9,817 (b) Right-of-Way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. (e) Area includes 58 miles of 250-foot-wide right-7f-way from Station M to Kincaid. This section of line would be constructed for 765-kV operations, but would ir.itially be operated at 345-kV.

- These circuits are required due to power flows.

i

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- ~**

tb e.aswer Q e.s ru <2 4,n t.) V teass e.) 345 KV LINE-DOUBLE CIRCUlT SINGLE SHATT STRUCTURES KiWCAID 0 CIRCUlT BREAKER ervistem 3 s /ea f M TRANSFORMER ._6. O sEuER4 TOR tiniT j El EoulPWENT ADDITIONS Figure, 9 /WOJ 765KV B 345KV TrmstnissionCo Concord Units 182 (Alternative to Carroll County Units IB 2 )

C. Concord Site

SUMMARY

OF ESTIMATED COSTS FOR CONCORD STATIOil SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Comoensation Total (2) (3) Concord 527.5 168.4 44.0 739.9 J (2) TRANSMISSION Two 765-XV circuits from Concord for a total of 288 miles @ 765-kV S462.5 One 345-kV double circuit from Concord for a total of 55 miles @ 345-kV $59.7 one 138-kV double circuit from Concord for a total of 7 miles @ 138-kV S5.3 Total S527.5 (3) Substation ten 765-kV breakers and four 765-kV line terminals $46.4 Seventeen 345-kV breakers and four 345-kV line terminals $30.0 Miscellaneous equipment additions / modifications (4) $92.0 (Five 1000 MVA 765/345-kV Transformers) Total S168.4* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. (4) Addition of or replacement of transformers, site preparation and/or modification at all affected substations in proposed plan. j

Actual projected cost data supplied by CECO

b 30 C. Hillview Site The proposed transmission facilities and breaker arrangements for the Hillview Site are included as Figures 10 and 11, respectively. The projected costs and right-of-way requirements are also shown. The specific transmission line lengths and terminals are as follows: Hillview - Station M l-765-kV circuit 70 miles Station M - Powerton 1-345-kV circuit 55 miles Station M - Kincaid (initially operated at 345-kV) 1-765-kV circuit 58 miles Hillview - La Salle County Power Plant 1-765-kV circuit 238 miles Hillview - Meredosia (double circuit 2-138-kV circuits 36 miles 138-kV) **

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV (e) Hillview 149 308 3,357 9,333 12,690 (b) Right-of-Way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345 line. (e) Area includes 58 miles of 250-foot-wide right-of-way from Station M to Kincaid. This section of line would be constructed for 765-kV operations, but would initially be operated at 345-kV.

- These circuits are required due to power flows.

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l ~ 238 on.cs 32 p-~~~~~~~~~~~m I H l wa s << yi gg tb l--- tb ,.., ~ es es t l -E E E-U2 8'"" I'la ' -5 5 -- B - I '*""~ k -c o--s a og ,,,,,, t2-c =- -c o-sm ~ swa Q rs.ue vas o.* m l-a-I -m i us., ~E E l LASALLE Gunr4 _ l .o v,se ~ ocpr w~+ r II Il auccees.4[\\3( ~ so. ser ase.s l l (asco) _H,llwee j @wer7DN 3 ,,,,,3 MAkertw & /Wvour esenvuLt Q l U " 5 5 -C O = -j l l sesc< -E O 4A i = ~2 =.

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33 C. Hillview Site

SUMMARY

OF ESTIMATED COSTS FOR HILLVIEW STATION SITES BASED ON TWO 1,100 MW Units (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) Hillview 674.8* 168.4* 58.9* 902.1* (2) Transmission Two 765-kV circuits from Hillview for a total of 366 miles @ 765-kV $550.8* One 345-kV double circui from Hillview for a total of 55 miles @ 345-kV S59.7* One 138-kV double circuit from Hillview for a total.a 36 miles @ 138-kV $27.3* Total $674.8* (3) Substation Ten 765-kV breakers and four 765-kV line terminals $46.4* Seventeen 345-kV breakers and four 345-kV line terminals $30.0* Miscellaneous equipment additions / modifications (4) $92.0* (Five 1000 MVA 765/345-kV Transformers) Total $168.4* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. (4) Addition of or replacement of transformers, site preparation I and/or modification at all affected substations in proposed plan. Estimated using CECO unit cost data supplied and the Concord i expansion as a base. i ( l l l l l l l I

34 C. Milton Site The proposed transmission facilities and breaker arrangements for the Milton Site are shown as Figures 12 and 13. The estimated costs and right-of-way requirements are also included. The specific transmission line lengths and terminals are as follows: Milton - Station M 1-765-kV circuit 62 miles Station M - Powerton 1-345-kV circuit 55 miles Station M - Kincaid (initially operated at 345-kV) 1-765-kV circuit 58 miles Milton - La Salle County Power Plant 1-765-XV circuit 230 miles Milton - Merdosia (double circuit 138-kV) ** 2-138-kV circuits 26 miles

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV (e) Milton 139 292 3,182 8,848 12,030 (b) Right-of-Way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. (e) Area includes 58 miles of 250-foot-wide right-of-way from Station M to Kincaid. This section of line would be constructed for 765-kV operations, but would initially be operated at 345-kV.

- These circuits are required due to power flows.

35 ,,, M '- 2 1 ", - lQ' ~_y}_.H -u-'I -4 , s. y;,* v %. 2 p' W :: '. ).I'.2_: V.@.h-F,h.. %. N . [ s.

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345 KV LINE-DOUBLE CIRCULI l SINGLE SHAFT STRUCTURES A'sWCA,D l O circuli BREAKER REvl510W 3 5/80 M TRANSFORMER O GENERATOR UNIT y EQUIPWENT ADDITIONS Figure! 13 /W9 765KV a 345KVTranstnissionConnection l /d,Han Units 182 (Alternative to Corroll County Units 182 ) g.

37 C. Milton Site

SUMMARY

OF ESTIMATED COSTS FOR MILTON STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) Milton 641.5* 168.4* 55.9* 865.8* (2) Transmission i Two 765-kV circuits from Milton for a total of 350 miles @ 765-kV $562.1* One 345-kV double circuit frem Milton for a total of 55 miles @ 345-kV $59.7* One 138-kV double circuit from Milton for a total of 26 miles @ 138-kV S19.7* Total $641.5* (3) Substation Ten 765-kV breakers and four 765-kV line terminals $46.4* Seventeen 345-kV breakers and four 345-kV line terminals $30.0* Miscellaneous equipment additions / modifications (4) $92.0* (Five 1000 MVA 765/345-kV Transformers) Total $168.4* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. (4) Addition of or replacement of transformers, site preparation and/or modification at all affected substations in proposed plan.

Estimated using CECO unit cost data supplied and the Concord site as a base.

1

38 D. Granville South Site The undeveloped Granville South Site is situated in the central area of Illinois. This site is located in Putnam County, approximately 1.6 miles south of the town of Standard, Illinois. This proposed candidate site is located southwest of the major CECO load centers. All existing bulk power electric transmission facilities are located to the north and east. The proposed transmission expansion for this site features two 765-kV circuits going to different terminal points along two different rights-of-way. The 765-kV expansion was chosen because of the distance from the load centers, the absence of any future development or 345-kV facilities in this area by CECO and also because of the planned construction of 765-kV facilities at the Plano substation. An additional 345-kV circuit is proposed to satisfy the NRC emergency off-site power requirement. The specifics of the proposed transmission expansion follow. il

39 D. Granville South Site The proposed transmission facilities and breaker arrangements for the Granville South Site are included as Figures 14 and 15, respectively. The estimated costs and right-of-way requirements are also included. The specific transmission line lengths and terminals are as follows: Granville South - La Salle County Power Plant 1-765-kV circuit 30 miles Granville South - Plano 1-765-kV circuit 70 miles Granville South - La Salle County 1-345-kV circuit 30 miles Power Plant

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV (c) Granville South 30 100 236 3,030 3,266 (b) Right-of-Way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. (c) Area based on 65 feet of additional right-of-way width. l l l

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=-_ m \\. --y .;- t 1..... g. r;-. - w - 901510h 3 $/80 _ SCALE eSo o to Souw1 1 l WW Figure 14 @ DEVELOPED SITES Tentative Transmission Corridors For Grc.Wille South Site f UNDEVELOPED SITES

41 9e war s / ~~l ~ ur re c.. < -C f -c l rw. o- / ^" "VlLLT ",s - h h ( wo zaa rra.7 sm ra.: a r 0 e -c l o a l a-l no-a a ..s~ -W M m- -C D- -C o-yas er a, a y( -m 4 u_ c... s g

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o---a - -C u--c ak C D- -O O-m- 0 v.s e ruwe U SA u e fouarv __ __ 76S KV LINE $1NGLE CIRCUlT STEEL TOWERS 345 KV LINE-DOUBLE CIRCUlT SINGLE SHAFT STRUCTURES circuli BRE AXER /\\/\\ TRANSFORMER 'f 5 '0

3 Sh O

GENERATOR UNIT R EQUIPMENT ADDITIONS MS Figure.15 765 KV Transmission Connections Gre,.<l//c Souff Unifs I 6 2 ( Allernative to Corroll County Units 182)

42 D. Granville South Site

SUMMARY

OF ESTIMATED COSTS FOR GRANVILLE SOUTH STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation -Total (2) (3) Granville South 193.2* 154.4* 2.8* 350.4* (2) TRANSMISSION Two 765-XV circuits from Granville South for a total of 100 miles @ 765-kV $160.6* One 345-kV double circuit from Granville South for a total of 30 miles @ 345-kV $ 32.6* Total $193.2* (3) Substation Nine 765-kV breakers and four 765-kV line terminals $41.8* Ten 345-kV breakers and four 345-kV .ne terminals $71.6* Miscellaneous equipment additional / modifications (4) $95.0* (Two 1500 MVA 765/345-kV Transformers Three 1000 MVA 765-345-kV Transformers) Total $154.4* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. (4) Addition of or replacement of transformers, site preparation and/or modification at all affected substations in proposed plan.

Estimated using CECO unit cost data supplied and the Biggsville Site as a base.

43 E. Erie South Site The undeveloped Erie South Site is located in northwestern Illinois. This site is in Whiteside County, approximately 3.5 miles south of the town of Erie, Illinois. This proposed candidate site is situated west of the major CECO load centers. All existing bulk electric power transmission facilities are located to the east. The proposed transmission expansion for this site features two 765-kV circuits going to different terminal points along two different rights-of-way. The 765-kV expansion was chosen because of the d stance to the load centers, the lack of future 345-kV develop-ment in this area by CECO and the concentration of existing 345-kV facilities around the Quad Cities Station. Right-of-Way acquisition could present a problem and if acquired might be better utilized at the 765-kV level. Additionally, a 345-kV circuit is included in the expansion to satisfy the NRC emergency off-site power requirement. The specifics of the proposed transmission expansion follow. 1 L l l l l l l l l

44 E. Erie South Site The proposed transmission facilities and breaker arrangements are shown as Figures 16 and 17, respectively. The projected costs and right-of-way requirements are also shown. The specific transmission line lengths and terminals are as follows: Erie South - Plano 1-765-kV circuit 103 miles Erie South - Charter Grove 1-765-kV circuit 132 miles Erie South - Erie North 2-345-kV circuits 2 miles

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV' 345-kV 765-kV (d) Erie South 2 235 35 6,025 6,060 (b) Right-of-Way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. (d) An incremental right-of-way width of 170 feet for 113 miles was used. i l I l

45 h' q ^ - j ;-y. 1 v-s__..N,s )'f., T"y'.Q.:% s. _ 4 r J J em._I1; g5. 1-i. _. s 3.- -r I r-4 I, af ..,, <e N. e

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i. y...,., ^. -

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s 46 132 *er ~. / -m ---a 7&sst N b [ '30**** y y l An*O w,M 4 0-bass () --C l O- ~*~' (p _, _L, W, _ I 74ssv -E E,-n-C waerue 61ove h L. - s m ~a -. ~. s -E E-4 fog f 34sev -= --E p - N ( \\ ERnr {o ?'l0 W ) KRIE scu.TH & ears 64.,4 {-C l C it.s n o-km 2-'"og-!g;g - M y twsaza rame.Kr. y,, e 3 r., C C C } .s.s yv l -C S -C D-NGL CIRCulT STEEL Towl diT LT 4"S** ~~ l 345 KV LINE-DOUBLE CIRCU

4d "O SINGLE SHAFT STRUCTURES CIRCulT BREAKER

/\\/\\ TRANSFORMER O stNtRAToR uni 1 EQUlPWENT ADDITIONS t A/\\ e Figure 17 765 KV Transmission Connections Ec,e South Units i B 2 _[ Alternative _lo_Cowell Ceunty Un ts 162) i

f 47 E. Erie South Site

SUMMARY

OF ESTIMATED COSTS FOR ERIE SOUTH STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) Erie South 379.6* 153.7* 44.0* 577.3* (2) TRANSMISSION Two 765-kV circuits from Erie South for a total of 235 miles @ 765-kV $377.4* One 345-kV double circuit from Erie South for a total of 2 miles @ 345-kV 2.2* Total $379.6* (3) Substation Ten 765-kV breakers and four 765-kV line terminals $46.4* Seven 345-kV breakers and forr 345-kV line terminals S12.3* Miscellaneous equipment additions / modifications (4) $95.0* (Three 1500 MVA 765/345-kV Transformers Two 1000 MVA 765/345-XV Transformers) Total $153.7* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. (4) Addition of or replacement of transformers, site preparation and/or modification at all affected substations in proposed plan.

Estimated using CECO unit cost data supplied and the Biggsville site as a base.

4 48 F. Braidwood Site The developed Braidwood Site is situated in the north-central region of Illinois. This site is located in Will County near the town of Braidwood, Illinois. This candidate site is south of the major CECO load centers. Presently this site is being developed for two nuclear, pressurized-water reactor units of 1,120 MW each. All existing bulk electric power transmission facilities are located to the north and the east. The proposed transmission expansion for this site features two 765-kV circuits going to two different terminal points along different rights-of-way. Because of the existing 345-kV facilities and the future extensive development by CECO of 345-kV facilities in this area, right-of-way acquisition could present a significant problem, and if obtained might be better utilized at the 765-kV level. Based on these considerations and the planned expansion of 765-kV facilities at Plano and Wilton Center, the DOE staff does not view transmission expansion at 345-kV as a viable alternative. Also, it is CECO policy when expanding an existing 345-kV generating station by the addition of two new units that the new units be placed on the 765-kV network. Additionally, the NRC off-site power requirement will be satisfied using the existing 345-kV facilities. The specifics of the proposed transmission expansion follow. i i f i l l l

49 F. Braidwood Site The proposed transmission facilities and breaker arrangements are included as Figures 18 and 19, respectively. The projected costs and right-of-way requirements are also shown. The specific transmission line lengths and terminals are as follows: Braidwood Power Plant - Wilton Center 1-765-kV circuit 38 miles Braidwood Power Plant - Plano 1-765-kV circuit 72 miles

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV Braidwood 0 110 0 3,333 3,333 (b) Right-of-Way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. l l - ~

50 ' ~7 = p= f. - '~~f f. 4. - ' Q u~~= ~ ~_s i ..mc. _ %_.. %.. ('-: ~a _..L lg },..,..,

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51 g _C'_ __ __ __ __ __ q cauws l l + -c = i t rz m es y ***" '~'M% l _g ar u I l i ~ Lumw nu==:.n.r -o La I 1 o c tv-I d -c o- -c a-I u.a.., tw-rv ca-~re 4 _j usu PL wo -.q --g sse m M M ~ ~ ~ ~ ~ ~~'~ menscwooc Aur % I

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&nemrf Caaatri L raamtrett I o c c o o o-ll c D--4~3 us=r -C C l D-l A 's., ' ** ' 0, $a"a. Y,lc.s l rte.1 g i s_o. -_1 a.as cou >~ s l -c = D-nmus zwwgog;a,, v ^ IcrD M cm.e.s et - ha d' ' __ __ 765 KV LINE SINGLE CIRCUIT STEEL TOWERS -C O-C 345 KV LINE-DOUBLE CIRCulT -c D-SINGLE SHAFT STRUCTURES CIRCUlT BREAKER u do" ~ W, tron / [rvrtc /\\/\\ TRANSFORMER 'f W 5'0" I 5 /i O GENERATOR UNIT E EQUIPWE hT, ADDITIONS W\\9 C Figure 19 l 765 KV Transmission Connections Braidwood Units 38 4 iaei i a e ti F .A ffaiit l$7I

52 F. Braidwood Site

SUMMARY

OF ESTIMATED COSTS FOR BRAIDWOOD STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) Braidwood 176.7 146.0 6.1 328.8 (2) Transrlssion Two 7c5-kV circuits from Braidwood for a total of 110 miles @ 765-kV S176.7* Total $176.7* (3) Substation Eight 765-kV breaker and four 765-kV line terminals S 37.1 Four 345-kV breakers and two 345-kV line terminals S 7.1 Miscellaneous equipment additions / modifications (4) $101.8 (Six 1500 MVA 765/345-kV Transformers) Total $146.O* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. (4) Addition of or replacement of transformers, site preparation and/or modification at all affected substations in proposed plan.

Actual projected cost data supplied by CECO.

53 G. Byron Site The developed Byron Site is situated in north-central Illinois. This proposed site is located in Ogle County approximately 3 miles south-southwest of the town of Byron, Illinois. This candidate site is northwest of the major CECO load centers. Presently, these are under construction at this site, two nuclear, pressurized-water reactor units of 1,120 MW each. All existing bulk power electric transmission facilities are located to the south and the east. The proposed transmission expansion for this site features two 765-kV circuits going to two dif ferent terminals along two different rights-of-way. Because of the existing and planned expansion of 345-kV facilities in this area by CECO, right-of-way acquisition might prove difficult and if obtain might be better utilized at the 765-kV level. In light of these considerations, and the planned expansion at Plano of 765-kV facilities, the DOE staff does not view 345-kV transmission expansion as practical. Also, it is CECO policy to place the two new units on the 765-kV network. The NRC off-site power requirement will be met utilizing the existing 345-kV facilities. The specifics of the proposed transmission expansion follow. i Y

54 G. Byron Site The proposed transmission facilities and breaker arrangements for the Byron Site are included as Figures 20 and 21, respectively. The projected costs and right-of-way requirements are also shown. The specific transmission line lengths and terminals are as follows: Byron Power Plant - Charter Grove 1-765-kV circuit 34 miles Byron Power Plant - Plano 1-765-kV circuit 103 miles

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENT (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV i Byron 0 137 0 4,152 4,152 (b) Right-of-Way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. l l l I i l i

55 Q $,,Q 7", ~ ' K ~ 7, 7 - ; '. - s T V 2. 3 w +.. .I ...s ..e..1,,..p w i e~,y v In e. t l-; N,, - .,j .- q:..~ o -w .I s i -l- =.- I y-Q W.-__. c,,,x, 3 ' 8 t.C - 4, y - + _.,. s._. --r c_. 1 ca p,s m e 7., l .u. . <...j. ..-:.-c -J -. y. . y ,s. -A.

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s 56 .54a. sics _ - -q / ~ * ' E - / -a o- ,u ~ +r ,~ ( (*d t ~/f i ,,f G,evt l.5= ~ -a l -a I ab0 e - o- -c -

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( 57 G. Byron Site

SUMMARY

OF ESTIMATED COSTS FOR BYRON STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) Byron 220.0 141.9 7.5 369.4 (2) Transmission Two 765-kV circ lits f rom Byron for a total of 137 miles @ 765-kV $220.0 'f otal $220.0* (3) Substation Ten 765-kV breakers and four 765-kV line terminals $46.4 Six 345-kV breakers and two 345-kV line terminals $10.6 Miscellaneous equipment additions / modifications (4) S84.9 (Five 1500 MVA 765/345-kV Transformers) Total $141.9* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. (4) Addition of or replacement of transformers, site preparation and/or modification at all affected substations in proposed plan.

Actual projected cost data supplied by CECO

58 H. La Salle County Site The developed La Salle County Site is located in north-central Illinois. This proposed site is situated in La Salle County approximately 5 miles south-southwest of the town of Seneca, Illinois. This candidate site is located south and west of the major CECO load centers. The site is presently developed with two nuclear, boiling-water reactor units of 1,078 MW each. All existing bulk power electric transmission facilities are located to the north and east. Because of the existing facilities, and the planned expansions by CECO in this area, acquisition of necessary right-of-way could be difficult. If right-of-way could be obtained, its use at 765-kV might be more attractive than utilization at 345-kV. In light of these considerations, and the planned expansion at Plano Station for 765-kV facilities, the DOE staff does not view 345-kV transmission expansion as practical. Also, it is CECO policy to place these two new units on the 765-kV network. The NRC off-site power requirement will be met by utilizing the existing 345-kV facilities. The specifics of the proposed transmission expansion follow.

59 H. La Salle County Site The proposed transmission facilities and breaker arrangements are included as Figures 22 and 23, respectively. The estimated costs and right-of-way requirements are also shown. The specific transmission line lengths and terminals are as follows: La Salle County Power Plant - Plano 1-765-kV circuit 45 miles

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV La Salle County 0 45 0 1,364 1,364 (b) Right-of-Way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. l l

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62 H. La Salle County Site

SUMMARY

OF ESTIMATED COSTS FOR L A SALLE COUNTY STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) La Salle County 72.3 102.8 2.8 177.9 (2) Transmission one 765-kV circuit from La Salle County for a total of 45 miles @ 765-kV $72.3 Total $72.3* - (3) Substation Six 765-kV breakers and two 765-kV line terminals $27.8 Four 345-kV breakers and four 345-kV line terminals S 7.1 Miscellaneous equipment additions / modifications (4) $67.9 (Four 1500 MVA 765/345-kV Transformers) Total $102.8* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. (4) Addition of or replacement of transformers, site preparation and/or modification at all affected substations in proposed plan.

Actual projected cost data supplied by CECO.

63 I. Quad cities Site The developed Quad Cities Site is located in northwestern Illinois. This proposed site is situated in Rock Island County approximately 3 miles north of the town of Cordova, Illinois. This candidate site is located west of the major CECO load centers. Presently, this site has two nuclear, boiling-water reactor units of 1,050 MW each. All existing bulk electric power transmission facilities are located east of the site. The proposed transmission expansiun at this site features two 765-kV circuits going to two different terminal points along two different rights-of-way. The lack of future development by CECO in this area at 345-kV, coupled with the concentration of existing facilities around Quad Cities Station, might make right-of-way acquisition difficult and if obtained this right-of-way might be better utilized at 765-kV. Additionally, due to the distance to the load centers, and the planned construction of the Plano Station at 765-kV, the proposed 765-kV system expansion at Quad Cities Station might appear more attractive. Also, it is CECO policy to place the two new units on the 765-kV network. The NRC off-site power requirement will be met by.the existing 345-kV facilities. The specifics of the proposed transmission expansion follow. ) i l

64 I. Quad Cities Site The proposed transmission facilities and breaker arrangements are shown as Figures 16 and 24, respectively. The projected costs and right-of-way requirements are also shown. The specific transmission line lengths and terminals are as follows: Quad Cities Power Plant - Charter Grove 1-765-kV circuit 113 miles Quad Cities Power Plant - Plano 1-765-kV circuit 122 miles

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS (Acres) Transmission New Right-of-Way (b) Station Mileage Requirements (Acres) Total 345-kV 765-kV 345-kV 765-kV Quad Cities 0 235 0 7,121 7,121 (b) Right-of-Way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line.

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1 66 i l //) *** l: r------- -8 T& $ H I o e 'e- - vs I m N GO d E we vawti 74 sr/ j m m i /soo m 4 AA AA ' " " -C O- \\ l n n \\ mes n W l _ DAR TER & v6 he t Dif< Asop 91 (f $ # (a) Awa(W @480) / 2 2 MI -c c c a o =s .,,, ~ b E g @cdATih C'e-: Al.1 BL G \\ OUAD [r?"of 5 ya t'st &s ous G e o vL C n-76S ei -C y h prm s-mof,L-ig;s zeus.s we.tr naa ra e x,. -C C D C D-- -C D- -C D-us wiwe .srutat CietusT srest 'rowfC$ b?uY, $uY .3As W LtdC - UUP.LE tote sto f .$IWGL L 3HMI'.S Yt s/CTuCC S PLAuo O ci.: cuo r er ra u cit m ru ~s e;curc O s ""r= c '~' ' Sr vi$tch 3 e\\ eau,oas.a a=o.rooc E ~ M Figure 24 765 KV Transtnission Connections Quad Cities Units 3 8 4 ( Alternative to Carroil County Units I82)

67 I. Quad Cities Site

SUMMARY

OF ESTIMATED COSTS FOR QUAD CITIES STATION SITES BASED ON TWO 1,100 MW UNITS (1) (Dollars in Millions) Station Transmission Substation Compensation Total (2) (3) Quad Cities 377.4 145.4 8.0 530.8 (2) Transmission Two 765-kV circuits from Quad Cities for a total of 235 miles @ 765-kV S377.4 Total S377.4* (3) Substation Ten 765-kV breakers and four 765-kV line terminals $46.4 Eight 345-kV breakers and four 345-kV line terminals $14.1 Miscellaneous equipment additions / modifications (4) $84.9 (Five 1500 MVA 765/345-XV Transformers) Total $145.4* (1) 1991 Dollars - Includes 7.5% escalation per year and 25% for indirect costs. (4) Addition of or replacement of transformers, site preparation and/or raodification at all affected substations in proposed plan.

Actual projected cost data supplied by CECO.

68 CONCLUSIONS This DOE staff analysis indicat'* that the proposed Carroll County site is cost advantageous with respect to transmission and casociated substation facilities. The proposed Carroll County transmission arrangement will provide cdditional interconnections betwean the Commonwealth Edison CompaIny and the Iowa Interstate Pover Company and the Iowa-Illinois ^ Gas and Electric Company. These interconnections and the physical location of the power plant near the Iowa-Illinois boundary should cnha- 'a overall system reliability. A location other than Carroll County could pose a reliability problem for the Iowa-Illinois Gas and Electric Company (IIG&E). Presently, IIG&E owns 25 percent of the output of the Quad Cities nuclear units which are located in the proximity of the Carroll County site. If the new units with the same ownership ratios were placed at one of the other sites than Carroll County, in actuality the combined electric power commitment to I1G&E from Quad Cities and the new units would be supplied solely by Quad Cities; the system power flow impacts would be nearly the same as if the IIG&E percentage of ownership in the Quad Cities units was increased. The power for IIG&E would have to be supplied through the Quad Cities transmission interties unless new transmission lines are added between the Commonwealth Edison Company and IIG&E. There vould be more dependence on existing facilities and a single contingency or outage could have more serious consequence. All the alternate sites were evaluated, t3 the maximum extent possible, on the basis of facilities needed to provide equivalent system reliability. Thus, the estimated lower costs for the Catcoll County transmission and substation facilities represent relative value of expected savings over other locations. Tablos I and II summarize the DOE staff computed circuit miles of transmission lines required and the estimated costs of associated transmission and substation facilities for a Carroll County site and for each of the alternate sites selected by NRC for analysis. Costs do not include acquisition of transmission line rights-of-way and substation sites. Sites that are more remote from the Commonwealth Edison Company load centers require higher voltage transmission linec and/or more miles of transmission.

69 Table I

SUMMARY

OF ESTIMATED COSTS FOR VARIOUS STATION SITES BASED ON TWO 1,100 MW Units (1) (Dollars in Millions) Station Transmission Substation Compensation Total Carroll County 116.8 28.2 0.0 145.0 Biggsville 612.6 150.9 49.3 812.8 Gladstone 599.7* 147.4* 48.5* 795.6* Rozotta 569.7* 147.4* 45.9* 763.0* Concord 527.5 168.4 44.0 739.9 Hillview 674.8* 168.4* 58.9* 902.1* Milton 641.5* 168.4* 55.9* 875.8* Granville South 193.2* 154.4* 2.8* 350.4* Erie South 379.6* 153.7* 44.0* 577.3* Braidwood 176.7 146.0 6.1 328.8 Byron 220.0 141.9 7.5 369.4 LaSalle County 72.3 102.8 2.8 177.9 Quad Cities 377.4 145.4 8.0 530.8 (1) 1991 Dollars - Includes 7.5% escalation per year and 25i for indirect costs. Estimated using CECO unit cost data supplied f i i

=- __ 70 Table II

SUMMARY

OF ESTIMATED NEW RIGHT-OF-WAY REQUIREMENTS ( J.cre s ) Transmission New Right-of-Way Station Mileage (a) Requirements ( P.cre s ) ( b ) Total 345-kV 765-kV 345-kV 765-kV i i Carroll Cour.ty 113 0 1,986 0 1,986 Biggsville 48 349 844 10,576 11,420 Gladstone 45 343 791 10,394 11,185 Rozetta 44 325 773 9,848 10,621 e concord 120 230 2,847 6,970 9,817 e Hillview 149 308 3,357 9,333 12,690 e Milton 139 292 3,182 8,848 12,030 c Granville South 30 100 236 3,030 3,266 d Eric South 2 235 35 6,025 6,060 Braidwood 0 110 0 3,333 3,333 Byron 0 137 0 4,152 4,152 LaSalle County 0 45 0 1,364 1,364 Quad Cities 0 235 0 7,121 7,121 i n. Details of transmission line length and destination are shown in report. b. Right-of-Way widths assumed to be 250 feet for 765-kV lines and 145 feet for double circuit 345-kV lines and 110 feet for single circuit 345-kV line. c. Area based on 65 feet of additional right-of-way width. d. An incremental right-of-way width of 170 feet for 113 miles + was used. c. Area includes 58 miles of 250-foot-wide right-of-way from Station M to Kincaid. This section of line would be constructed for 765-kV operations, but would initially be operated at 345-kV.

4 Aomndix I l i i I i ) I i 1 1

MAIN GUIDE NO. 2 SIMULATION TESTING OF THE MAIN BULK POWER TRANSMISSION SYSTEM The primary purpose of MAIN is to promote maximum coordination of planning, construction and utilization of generation and transmission facilities on a regional basis to provide a reliable and adequate electric bulk power supply in the MAIN area. Recognizing that the simulated testing of existing and planned bulk power systems is essential to measure reliability and adequacy, the definitions, tests and procedures given in this Guide have been adopted by MAIN. This Guide presents the characteristics of a well planned bulk power transmission system, and describes Transfer Capability and Extreme Disturbance testing, which will be used to evaluate the { reliability and adequacy of the MAIN bulk power regional transmission I system. f r L The section of this guide pertaining to Transfer Capability Testing is in accord with the guidelines in the NERC reference ~ document, " Transfer Capability", dated October, 1980. (Refer to 7 Appendix II for NERC Transfer Capability Definitions) L F L Characteristics of a Well Planned System H l The following basic characteristics are considered essential to a well planned system and would be expected to provide an effective safeguard against the occurrence of an uncontrolled area- [{ wide power interruption and to provide adequate transfer capabilities. F I . M02-1.

A. A balanced relationship should be maintained among power system elements, in terms of size of load, size of generating units and plants, strength of interconnections, and the concentration of power at any point on the transmission system. Adherence to this principle implies: i 1. Avoiding excessive concentration of generating capacity in one unit, at one location, or in one area. 2. Avoiding excessive concentration of power being carried on any single transmission circuit, tower line, or right-of-way, as well as through any one transmission station. I B. Transmission and interconnection capability should be adequate to provide for intraregional, interregional, and transregional power flows under normal conditions, and to meet a wide range of contingencies. C. Suitable switching arrangements should be provided that would permit effective maintenance of equipment withest excessive risk to the system. c D. Adequate switching arrangements and associated relay schemes should be provided that do not limit the capability of a transmission element to the extent of MG2-2

causing excessive risk to the system. E. The interconnected system of MAIN members should be capable of operation such that adequate power interchanges within MAIN and with systems outside MAIN remain within design capabilities of the interconnected network. Transfer Capability Testing The adequacy of the MAIN interconnected system shall be tested by measuring its transfer capability under normal and contingency conditions. It should be noted that the values so obtained are in addition to the existing or projected interchange schedules. Therefore, the word, " incremental" is included in each of the definitions. Three measures of transfer capability are defined below. Transfer capability is more an indication of system strength (or weakness) than an absolute value to which a transfer must be limited, as actual transfer capability is a function of the specific system conditions existing at the time. Since all companies plan at i least on a worst single contingency basis, a first contingency incremental transfer capability which is based on this criterion is both appropriate and important in MAIN study work. l l First Contingency Incremental Transfer Capability (FCITC) The FCITC is defined as the maximum amount of power above existing or projected schedules that can be safely transferred in a MG2-3

specific direction under peak load conditions without any facility becoming loaded above emergency rating following the outage of the most critical transmission element. The FCITC is the value used for reporting all interregional transfers, and will be used to determine the safe operating levels for intraregional, interregional, and transregional power flows, and for MAIN reporting purposes. In studies of future systems, it may be desirable to evaluate the FCITC assuming the installation of proposed facilities in the later years is postponed or delayed. The FCITC of the transmission network into MAIN and also into each of the MAIN sub-regions should be at least equal to the emergency assistance level required to maintain a reasonable generation reserve margin. Studies of reserve requirements based on MAIN Guide No. 6 are used in determining the required emergency assistance. l Second Contingency Incremental Transfer Capability (SCITC) The SCITC is defined as the maximum amount of power above existing or projected schedules that can be safely transferred in a l specific direction under peak load conditions without any facility being loaded above emergency rating during the outage of the two most ~ critical transmission elements. The SCITC of the transmission network into each of the MAIN sub-regions should be at least sufficient to provide for all planned firm and diversity scheduled interchanges. MG2-4

It should be noted that the SCITC considers the simultaneous outage of two facilities without intervening time for operator-directed system adjustment. It is recognized that the probability of double contingencies at times of heavy system lead and reduced system generation reserve is relatively low; however, this test is useful for disclosing possible weaknesses in the design of the transmission system and therefore may be considered in planning and operating the system. MAIN companies also study multiple contingency outages at FCITC transfer levels in the Extreme Disturbance Tests to assess system strength and ability to avoid widespread cascading outages. However, significant system reinforcement to protect against double contingencies would generally be justified only to prevent a cascading outage, or complete outasa to a major load area, and not to provide increased transfer capability for double contingencies or for extended periods of time. j i It is also recognized that the large variation in system loadings and the many combinations of double outages make it ,g impossible, in a generalized study, to examine all the conditions i that could be encountered in determining the SCITC. However, if an I extended power transfer or a prolonged facility outage were to occur unexpectedly, the SCITC would be a usefal guideline until such time specific studies could be made using the prevailing schedules with as I the appropriate outages. I I MG2-5

Installed Incremental Transfer capability (IITC) The IITC is defined as the total amount of power above existing or projected schedules that can be transferred in a specific direction under peak load conditions with all facilities in service L and no facility loaded above normal rating, no consideration being given to possible contingency loadings. System operation is normally approached from the standpoint of anticipating a future jeopardizing event. For this reason, IITC is not routinely used in system operation. Therefore, report commentaries and appraisals do not usually discuss or attribute significant importance to IITC. It should be noted that during extreme conditions some companies mignt schedule emergency transfers approaching the IITC limit, if the alternative is dropping of firm load. Specific studies should then be made to insure that the interconnected system will not be subject to instability or widespread cascading for the most probable outage of one or more key facilities. f Procedures for Determining Transfer Capabilities l Procedures for testing to determine transfer capabilities j' l are given in Appendix I. The three measures of transfer capability can be summarized as follows: I MG2-6

Thermal Rating

Key Facilities of Limiting Capability Being Determined Out of Service Facility First Contingency Incremental Transfer Capability.

.(FCITC) One Emergency (But not greater than IITC) Second Contingency Incremental Transfer Capability. .(SCITC) Two Emergency (But not greater than FCITC) g Installed Incremental Transfer Capability. .(IITC) None Normal

Anticipated during transfers Extreme Disturbance Testing The reliability and strength of the MAIN interconnected system shall be tested by subjecting the system to simulated extreme disturbances.

It should be able to withstand severe' outages without resulting in an uncontrolled widespread tripping of lines and/or generators with resulting loss of load over a large area. In planning and operating a bulk power transmission system to have a high degree of reliability, conditions should be avoided which could cause an uncontrolled break-up or collapse of the interconnected system even for extremely improbable but credible contingencies. Providing 100% reliability is, of course, impossible, but it is possible to build an interconnected bulk power system in which uncontrolled widespread interruptions would be very unlikely even during improbable disturbances. Also, it is bnpossible to anticipate and test for all combinati ms of contingencies that could occur on an interconnected MG2-7 1

network. Therefore, reliability testing should be such as to thoroughly search ont the maximum credible contingencies for examination with good assurance that the many possible contingencies not studied are less severe. i s. Due to the individual characteristics of the various systems in the interconnected network, each system should be tested for the most severe of the following contingencies: A. At peak load, with reasonable incremental interchange above projected base case schedules between the two systems most affected by the disturbance: 1. Sudden outage of all generating capacity at any plcnt. 2. Sudden outage of any transmission station, including all generating capacity associated with such a station. l i I 3. Sudden dropping of a large load or a major load center. l l 4. Any other credible contingency of the same degree. i l l i B. At peak load, with interchange equal to *First Contingency Incremental Transfers Capability (FCITC) between the two systems most affected by the l l MG2-8

l disturbance: 1. Sudden outage of any transmission tower line at a time when any other circuit is out of service. 2. Sudden outage of all transmission circuits on the same right-of-way. 3. Sudden outage of any single or double circuit transmission tower line associated with a station which has two generating units already cut of service.

Notes:

If the results of Extreme Disturbance Testing show i. severe problems which might jeopardize the system, this should be noted and the tests repeated to determine an acceptable lower level of transfer. 11. A further analysis should be made to ensure that, as a l result of the disturbance, the outage of any facility i due to overloading will not cause instability or I cascading. The studies conducted to test the effect of the above contingencies should give due consideration to the follos.ing: i t A. Steady-state, transient and dynamic stability i

consideration, including three-phase faults at the most critical locations. B. The effect of slow clearing as a consequence of improper relay operation or failure of a circuit breaker to open. C. Possible occurrence of the above contingencies not only on the interconnected MAIN network, but also on the network of adjacent power systems, where a major contingency might involve MAIN or portions thereof in a cascading incident. e l' l l I I MG2-10

1 Procedures for Testing Interchange Capability The following material is included as a guide to those directly involved in interchange capability testing for MAIN. It describes the successive steps taken to determine the three types of transfer capability - IITC, FCITC, and SCITC. A. Normal Conditions With anticipated peak loads and expected generation dispatch and all existing or projected transfer schedules in effecc, all transmission loadings initially should be within normal ratings and all voltages initially enou.id be within acceptable limits. (Base Case) B. Installed Incremental Transfer Capability (IITC) The IITC is the transfer level determined with all transmission facilities in service, all facilities loaded within normal ratings, and all voltages within acceptable limits. M32 11

i C. First Contingency Incremental Transfer Capability (FCITC) The FCITC is determined by the most limiting of the following tests: 1. With the FCITC transfer, all transmission facilities should be loaded to within emergency ratings and all voltages should be within emergency limits after the initial power swings following the outage of any single transmission facility or generating unit, but before operator-direc?ed system adjustments are made. (In the event of a permanent outage of a facility, transfer schedules may need to be revised.) 2. If the FCITC as determined above exceeds the IITC, the IITC value should be used,as the FCITC. (It is possible that the FCITC so determined included the outage of the most limiting element of the IITC test, thereby resulting in an FCITC value higher than the IITC value.) To permit thorough coverage of the possible facility outages that may prove to be critical, System Linear Analysis Techniques (SLANT) program is used with verification by load flow as neeued. FCITC is the amount of power (above existing or projected MG2-12

schedules) that can be safely transferred with all facilities in service, and yet withstand the outage of the most critical facility. Although tests to determine FCITC are made assuming a critical facility is out of service, it must be remembered that FCITC is defined and should be treated in reports as the transfer level which applies when facilities are in service and the system is prepared to all experience the loss of the mort critical facility. Generally extreme disturbance testing, which checks system stability, considers the appropriate trans fer level and more severe contingencies than are used in FCITC determinations; therefore, it is assumed that the system would be stable with the outages used in FCITC testing. ( Second Contingency Incremental Transfer Capability D. (SCTTC) i The SCITC is determined by the most limiting of the following tests: 1 With the SCITC transfer, all transmission facilities i l' l. I should be loaded to within emergency ratings and voltages should be within emergency limits after the initial power swings following the outage of any two system transmission facilities but before operator-directed system adjustments are made. l i I MG2.

F 2. If the SCITC as determined above exceeds the FCITC, the FCITC value should be used. (It is possible that the SCITC so determined included the outage of the most { limiting element of the FCITC test, thereby resulting in an SCITC value higher than the FCITC value.) .b To permit thorough coverage of the possible facility outages that may prove to be critical, System Linear Analysis Techniques (SLANT) program is used with verification by load flow as needed. The SCITC is the amount of power (above existing or projected schedules) that can be safely transferred with all facilities in service, and yet withstand the simultaneous outage of the two most critical facilities. Although tests to determine SCITC are made assuming two critical facilities are out of service, it must be remembered that SCITC is i defined and should be treated in reports as the transfer level which applies when all facilities arc in service and the system is prepared to experience the loss of two ,i critical facilities. l' Generally extreme disturbance testing, which checks stability, considers the appropriate transfer level and more J severe contingencies than are used in SCITC determinations; therefore, it is assumed that the syst'em would be stable with the outages used in SCITC testing. I MG2-14

I ~ l l The SCITC test made by MAIN for many years does not initially consider operator-directed system adjustments as permitted in the Second Contingency Incremental Transfer Capability (SCITC) determination described in the NERC document " Transfer Capability", dated October, 1980. Efficient use of the SLANT program precludes system adjustments after the first and before the second outage. Therefore, multiple outages always have been considered to be simultaneous, and MAIN studies and reports are made on this basis. However, when such adjustments can effectively increase the SCITC they are specifically noted. I f i l l MG2-15

NERC Transfer Capability Definitions I The section of MAIN Guide #2 pertaining to Transfer Capability Testing is based on the NERC reference document, " Transfer Capability", dated October, 1980. For reference, NERC definitions of First Contingency Incremental Transfer Capability (FCITC), Second Contingency Incremental Transfer Capability (SCITC), and Installed Incremental Transfer Capability (IITC) are included below. A. First Contingency Incremental Transfer Capability The amount of power, incremental above normal base power transfers, that can be transferred over the transmission network in a reliable manner, based on the following conditions: i 1. With all transmission facilities in service, all facility loadings are within normal ratings and all voltages are within normal limits. 2. The bulk power system is capable of absorbing the dynamic power swings and remaining stable following a disturbance resulting in the loss of any single generating unit, transmission circuit or transformer. 1 ( l l 3. After the dynamic power swings following a disturbance MG2-16 e

resulting in the loss of any single generating unit, transmission circuit or transformer, but before operator-directed system adjustments are made, all transmission facility loadings are within emergency ratings and all voltages are within emergency limits. Although transfer capabilities based on the first contingency are generally used for reporting purposes, other contingency considerations are also used in defining transfer capability. Two such definitions follow. I B. Second Contingency Incremental Transfer Capability l t The amount of power, incremental above normal base power transfers, that can be transferred over the transmission network in a reliable manner, based on the following conditions: I 1. With all transmission facilities in service, all 1 facility loadings are within normal ratings and all l voltages are within normal limits. 1 2. The bulk power system is capable of absorbing the dynamic power swings and remaining stable following a disturbance resulting in the sequential and overlapping outage of two facilities - either being a generating unit, transmission circuit or transformer - with system i MG2-17 --r -- -- w -w m -v-,

y----

--e ,,a- - g

adjustments made between the two outages as required. 3. After the dynamic power swings following a disturbance resulting in the loss of the second facility - either a generating unit, transmission circuit or transformer - but before further operator-directed system adjustments are made, all transmission facility loadings are within emergency ratings and all voltages are within emergency limits. NOTE: The term "second contingency" is used to specifically exclude simultaneous outages. Use of the term " double contingency" has been avoided, since it is often used to include both simultaneous and sequential outages. ( C. Installed Incremental Transfer Capability The amount of power, incremental above normal base power transfers, that can be transferred over the transmission network without giving consideration to the effect of transmission facility outages. All facility loadings are = within normal ratings and all voltages are within normal limits. C { MG2-18

A;nxmdix II

v t 20 Typical Transmission Line and Substation Cost Transmission Normal Cost kV Structure Type Conductors Rating MVA Per Mile 345 Double Circuit

1-2156 1,360

$1,086,000 MCM ACSR 765 Single Circuit 4-1585 7,950 $1,606,000 Steel Tower MCM ACSR

Single shaft tangent structures with conventional lattice corner towers.

Substation i Breaker Size kV (Amps) Cost l 345 2,000 $1,764,000 765 3,000 S4,639,000 These costs are based on CECO standard ring bus design. i}}

ML20032C757

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