ML20006F648

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Forwards Info Requested by Atty General for Antitrust Review of Application for OL
ML20006F648
Person / Time
Site: River Bend  Entergy icon.png
Issue date: 12/28/1973
From: Shapar H
US ATOMIC ENERGY COMMISSION (AEC)
To: Bork R, Saunders J
JUSTICE, DEPT. OF, ATTORNEY GENERAL, OFFICE OF
Shared Package
ML20006F643 List:
References
FOIA-90-71 A, NUDOCS 9002280262
Download: ML20006F648 (52)
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Text

{{#Wiki_filter:*i + e. .2 jr; UNITED STATES - -)4 ATOMIC ENERGY COMMISSION L' . 'i.*. '.. ~ ' WASHINGTON. D C. 20545 o-0EC' 2 s =1973 The Honorable Robert H. Bork Acting Attorney Genera'l Attention: Joseph J. Saunders, Esq. Chief, Public Counsel and Legislative Secticn /f Antitrust Division In the Matter of Gulf States Utilities Company River Bend Station Units 1 and 2 'AEC_ Docket Nos._50-458A and 50-459A

Dear Mr. Bork:

On September 27, 1973, in accordance with Sectfon 105c of the Atomic Energy Act of 1954,' as amended, we transmitted a copy of the information requested by the Attorney General for antitrust review in connection with the above application. At that tim the application had been submitted subject to determination that it met our filing requirements. The application has now formally been accepted. We are' transmitting herewith a copy of the current application and - five _ (5) copies of information requested by the Attorney General. for the antitrust review. The material is being transmitted to afford you an opportunity to render such advice to the Commission as you determine to be appropriate in regard to the finding to be made by the Commission pursuant to Section 105c(5) of the Act. Sincerely,, - l >Hbwa d K. Shapar % si tant General Counsel Licensing and Regulation Enciosure: { p g gf 2 f for Antitrust' Review (5) DEPARTMENT OF JUSTICE 8 AUG 1619M l, t. J R.A.0. Alifl4Rtt37-96 pgg22 egg 2900227 SPECTOR90-71 PDR

LL"-{, ), . c-x- -4 3. ..) ~ t f E-' j y.. /b..} j 'ill vih Y, !f; SD stasn p i -( c':! /h.,$88f h",' .q' LICENSE APPLICATION / q ANTI-TRUST REVIEW. .INFORMATION b [- - APPENDIX L - 10CFR50 j fA. c RIVER BEND STATION UNITS 1 AND 2 l> 4 ,q f A gr o l DOCKET NOS. 5g 4g, GULF STATES UTILITIES COMPANY / e# ~'\\ 71o. 3 I

f, u '? y uff ' 'i ,1.1 i ~ State separately for hydroelectric and thermal generating resources F applicant's most recent peak load and dependable capacity _ for the E same time periodi.. State app.licant's dependable' capacity at time 'of l system peak;for each of the next ten years for which information is available. -Identify each new unit or_ resource. For' hydroe3ectric - generating capacity,- indicate the number of kilowatt hours of use. W" associated with each kilowatt = of espacity during the ' adverse' vater year' upon which dependable capacity is based. Indicate average annual kilovstt hour. loads per kilowatt, assoelated with-each system . peak shovn- (exclusive of interchange. arrangements). t Responset _A. Peak Load i The 1972 summer peak load was 3,602,700-KW. t B. Dependable Capacity at time of most recent peak load. Ovned hydroelectric capacity None Ovned thermal capacity h,0h2,000 KW Purchased hydroelectric capacity v/o Reserves. 98.000 KW ( Purchased thennal capacity. v/o Reserves 106,000 KW ^ Diversity interchange capacity with Reserves 215,000 KW I C. Dependable Capacity at time of system peak for each o the next ten years.' t Dependable Capaelty in Kilowatts Purchased Purchased of Diversity ] Hydro With-CEPCO " With-Interchange Year Owned Thermal out Reserves out Reserves vith Reserves Total 1973. b.56h,000 98,000 70,000 215,000 h.9h7.000 ?' 197h 5,1hb,000 98,000 h5,000 215,000 5,502,000_. 1975 5,086,000 - 98,000 20,000 215,000 5,h19,000 1976 5,617,000 98,000 215,000 5.930,000 1977 6,070,000 98,000 215,000 6,383,000 '1 1978 7,150,000 98,000 .,215,000 7,h63.000 1979 7,690,000 98.000 " 7 I5,000 8,003.000' 1980.8,630,000 98,000 215,000 8,9h3,000 1981 9,560,000 98,000 215,000 9,873,000 -1982 10,500,000 98,000 215,000 10,813,000 t.

  • This is an estimate which may vary due to load growth changes, construction y

completion dates, fuel availability, license and permit contingencies.

    • Tentative purchase from Cajun Electric Power Cooperative.

tn 1: Page 1 of 3

1 - 1.- Continued- + 3 - 4.. r .c 3, D.' -.New Units' Plant Name_and Unit No. Capacity In Service Date Willow Clen No. k 522,000 KW Spring 1973 I Sabine No. b 580,000 KW September 1973 Convert Nelson No. k ' to Oil -0 KW December 197h I y Derate Willow Glen No. 3 -58,000 KW April 1975 1 Willow Clen No. 5 580,000 KW September 1975 Derate Nelson No. 2 -11,000 KW October 1975 Derate Willov Glen No. 2 -22,000 KW March 1976 7 Derate Nelson No. 3 -16,000 KW June.1976 Derate V111ov Glen No. 1 -16,000 KW August 1976 Sabine No. 5 h80,000 KW September 1976 Derate Nelson No. 1- -11,000 KW November 1976 .t Edgerly Unit 1 540,000 KW September 1977 Edgerly Unit 2 540,000 KW April 1978 i Edgerly Unit 3 Sh0,000 KW September 1978' ~! River Bend No. 1 9h0,000 I February 1980 Blue Hills No. 1 930,000 KW September 1980 River Bend No. 2 9h0,000 KW September 1981 \\ Blue Hills' No. 2 930,000 KW September 1982 Unde.termined 1,100,000 KW September 1983 cm 'This is an estimate which may vary due to load growth changes, con-struction completion dates, fuel availability, license and permit. contingencies. E. Hydroelectric Capacity and Energy: Sam Rayburn Dam and Reservoir. (Purchased) Page 2 of 3

- lb - C5ntin d .( Installed Capacity-52,000 KW s ' Average Annual Energy (6 years) 56,h60,600 KWHR: . Minh An'n'ual Eiiergy 18,900,000 KWHR-g KWHR use/KW Cap = 36h-l Hydroelectric Capacity and Energy: Toledo Bend Dam and Reservoir. - ' (Purchased) Installed Capacity 92,000 KW (Total) ' Installed Capacity - h6,000 KW (OSU Share) cN Average Annual Energy (3 yrs. ) 102,12h,332 KWHR (Total)- 0-Average Annual Energy (3 yrs. )- 51,062,166 KWHR.(OSU Share)- Minimum Annual Energy 65,700,000 KWHR (Total) ' .Hinimum Annual Energy 32,850,000 KWHR (OSU Share) KWHR use/KW Cap = 715' j F. System Peak Loads and Average Annual K116vatt Hour Loads per Kilowatt: t ~ Estimated Estimated. I 1 -Year System Peak Load Average Annual KW KWHR /KW# 1973 3,852,000 0.68 197h h,238,000 0.68 q' 1975 h 661,000 0.68 l1976 5,127,000 0.68 1977 5,6ho,000 0.68 1978' 6,20h,000 0.68 i 1979 6,82h,000. 0.68 1980-7,506,000 0.68~ 1981-8,257,000 0.68-1982-9,083,000 ~0.68 " Calculated as follows: i Estimated Annual KWHR used Total hours in year X Estimated annual peak l-Page 3 of 3 l l l .. m m ~ .z m

g:- a, 0 4-ll 2. State applicant's estimated annual load' growth for each of the next. twenty years : for the t p'eriod ~ applicant utilizes in system planning.

Indicate growth 7oth in ki16Vatt require:nents and. kilowatt hour. re-.-

quirements '. , Response: Year KW Orowth KVHR Growth 1973 '350,000 2,08h 880,000-197h - ~ 385,000 2,293,368,000 1975 h2h,000 2,525,683,200 1976 h66,000 2,783,k73,920-c 1977 512,000 3,0h9.881,600 1978-56h.000 3,359,635.200 ] ~. 1979 620,000 3,693,216,000-1980 682,000 L.073,667,8ho' l 1981 751,000 h,h73,556,800 1982 826,000 h 920,316,800 1983 908,000 5,408,77h h00 i 1984 999,000 5,967,1h6,880 ~ 1985-1,099,000-6,5h6,523,200 ' Difference between estimated peaks of 1972 and'1973 and the KW growth for 1973 is due to CEPCO load. See question No. 8.A.1(d). x 2 I e i

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State estimated annual load ' growth in kilowatts and kilowatt: hours of:

companies. or pools upon which the economic 'justifiestion of the subject ; unit.is based ftfr eacTs of= the next 20 years, or for the' period Applicant. i , utilizes in system planning.- Identify each company or pool member..

Response

. No. pool studies. vere made for economic-justification. Studies ' vere made ' based on Gulf States' load and needs. t 4 l Io i 'I il ~f V:. l i l-l i NM { l g 1 4 _m

M[ ) e, JWF tr 1 y lg k.~ For. the year the subject unit'vould 'first come on line, state estimated annual load ~ growth in kilowatts and kilowatt hours of any coordinating ~ group or pool ot vhich the. Applicant is a member (other than the coordi-nating; group or pool referred to in the Applicant's response to Item 3) which has' generating and/or transmission planning functions..-Identify each company or, pcol member whose loads are indicated in the response _thereto.

Response

A. Southwest Power Pool estimated annual load growth: 4 'l c Year KW Grovth KWHR Grovth s 1980 h,519,000 Not Available 1 1981 h,890,000 Not Available B. Members of Southwest Power Pool: -i Arkansas Electric Cooperative Corp. 8000 Interstate Drive, Little Rock, Arkansas 72209 ' Arkansas-Missouri Power Company h05 West Park Street, Blytheville, Arkansas 72315 Arkansas Power & Light Company l - 9th and Louisiana, Little Rock, Arkansas 72203 Associated Electric Cooperative, Inc. Central Kansas Power Co., Inc. ' 111 East lith, Hays, Kansas 67601 Central Louisiana Electric Company, Inc. h15 Main Street, Fineville, Louisiana 71360 Chanute Municipal Utilities 1 l Chanute, Kansas 66720 E C Coffeyville Municipal Water & Li ht Dept. 6 605 Sante Fe Street, Coffeyville, Kansas 67337 Empire District Electric Company 602 Joplin Street, Joplin, Missouri 6h801 Grand River Dam Authority Vinita, Oklahoma Th301 - Gulf States Utilities Co. P. O. Box 2951, Beaumont. Texas 77704 Page 1 of 3 L 1 '

f

b. - Continuel-l v,

Independence Pc er & Light Dept. 21500 E. Truman Rd., Independence, Missouri 6h056 i; Kansas City Board of Public Utilities i 1211 No. 8th St., Kansas City, Kansas 66101 Kansas City Pwer & Light Company 1330 Baltimore Ave., Kansas City, Missouri 6hlh1 Kansas Gas and Electric Company 201 N. Market Street, Vichita, Kansas 67201 Kansas Pwer & Light Company 818 Kansas Ave., Topeka, Kansas 66601 Louisikna Pwer & Light Ccapany 1h2 Delaronde Street, New Orleans, Louisiana 7011h Mississippi Pwer & Light Company Electric Bldg., Jackson, Mississippi 39205 Missouri Edison Company 202 South 3rd Street, Louisiana, Missouri 63353 Missouri Pwer 6 Light Company 101 Madison St., Jefferson City, Missouri 65101 Missouri Public Service Company 10700 East 50 Highway, Kansas City, Missouri 6h13B Missouri Utilities Company 400 Broadway, Cape Girardeau, Missouri 63701 New Orleans Public Service, Inc. 317 Baronne Street, New Orleans,14. 70160 Oklahoma Cac & Electric Company 321 N. Harvey Ave., Oklahma City, Oklahma 73102 Public Service Co. of Oklahma 600 South Main St., Tulsa, Oklahma Southwestern Electric Pwer Company h28 Travis Street, Shreveport, La. 71102 Southwestern Power Administration P. O. Draver 1619, Tulsa, Oklahma Th101 Page 2 of 3

Lh. - Continued Springfield City Utilities 301 E. Central Street, Springfield, Missouri 65801 St. Joseph Light & Power Company $PO Francis St., St. Joseph, Missouri 6k>02 Vestern Farmers Electric Cooperative Andarko, Oklahcoa 73005 Western Power Division, Central Telephone & Utilities Corp. Broaduny at Morton, Crest Bend, Kansas 67530 Vinfield Municipal Electric Light Dept. P. O. Box 6h6, Vinfield, Kansas 67156 Page 3 of 3 I 9

7 1 e 9 i 5. State applicant's minimum installed reserve criterion (as a percentage ' of load)* for the period when the subject unit vill first come on line. s If the applicant shares reserves with other systems, identify the other systems and provide minimum installed reserve criterion (as a percentage of load)' by contracting parties or pool for the period when the pro-posed unit vill first come on line. ' Indicate whether loads other than peak loads are considered.

Response

Gulf States Utilities Company subscribes to the following Reserve. Policy which is part of an overall Planning Criteria Policy adopted by the members of the Southwest Power Pool. " Planning of capacity additions must provide that the total generating capacity available to each Group in the Southwest Power Pool system shall be such that the capacity available shall exceed the predicted annual peak load obligation by a margin of 155, or as an alternative, a probability study l made so as to insure that the probability of load exceeding capacity available to such Group shall not be greater than one occurrence in ten years i i provided that in no case shall the reserve be less than 12% of the peak load obligation of the group. t "The method of calculating the probability of load exceeding available capacity shall include considera-tion of uncertainty in prediction of load and shall employ the best available statistical data on genera-l ter forced outage rates. The method vill also con-sider hour-by-hour characteristics of the load, availability of quick-start generation and effects i of interconnections and agreements with neighboring capanies. There shall be no greater dependence upon interconnections with adjacent areas than is agreed to by said areas or is deemed prudent by good engineering judgement. The maximum capability assigned t to any generating unit shall be that which has been .A.4_ demonstrated by actual test under the most adverse conditions that might exist during the loading period being considered". NCYTE: The above statement of Reserve Policy was included in the April 1971 Southvest Pover Pool report of " Reliability and Adequacy of Electric Pover". 1 I. l l

9 e 6. Describe methods used as a basis to establish, or as a guide in estab-lishing the criteria for applicant's and/or applicant's pool's minima j amount of instuited reserves. '[e.g., (a) single largest unit ocyn, (b) probability methods such as loss of load one day in 20 years, loss of capacity once in 5 years, (c) other methods and/or (4) judgement. List contingencies other than risk of forced outage that enter into the dete rmination. )

Response

Mininum installed reserve criteria is based on probability of loss of load of one day in 10 years. In no case vill reserves be less than 12%. 4 O e --- ~ ^ ^

p-7 Indicate whether applicant's system interconnections are credited I explicitly or liqplicitly in establishing applicant's installed reserves.

Response

Gulf States Utilities Company does not consider the capacity of the i interconnections as part of installed reserves. However, the system interconnection capacity does affect installed reserves in the follow-ing manner. The system interconnection espacity is verified by load flow studies. This capacity is used in making loss of load probability studies. The capacity from the interconnections is never greater than that of the excess generating capacity of the adjacent companies. F ( d bS i 4

ITE 8.- - List' rights to receive emergency power and obligations to deliver emergency power, rights or obligations to receive or deliver de-t ficiency power-er unit power,,or other coordinating arrangements, by reference to applicant's Federal Power Commission (FPC) rate schedules (i.e., ABC Power & Light Co., FPC Rate Schedule No.15 including supplement 1-5)**, and also by reference to applicant's state commission filings. Where documents are not on file with the FPC, supply copies, or where not reduced to writing describe krrange-i ments. Identify for each such arrangement the participating parties other than applicant. Provide one line electrical and geographic diagrams of coordinating groups or power pools (with generation or transmission planning functions) of which applicant's generation and i transudssion facilities constitute a part.

    • List separately and identify certificates of concurrence.

Response

s A. Rights to receive emergency power and obligations to deliver emergency power. 1. Agreements: (a.) Central Louisiana Electric Company and Louisiana Power and Light Company, FPC Schedule No. 82 including supplements 1-30. (b. ) Houston Lighting and Power Company, FPC Schedule No. 89 (c.) City of New Roads Louisiana, FPC Schedule No.101. -(d. ) Cajun Electric Power Cooperative, Inc., TPC Schedule No. 10h. 2. Certificates of Concurrence: (a.) Interconnection Agreement among Central Louisiana Electric Company, Culf States Utilities Company, an4A. _uf siana Power and Li ht Company, mg. 6 Document Interconnection Agreement Supplement No. 1 Supplement No.1 to Supplement No.1 Supplement No. 2 to Supplement No. 1 Supplement No. 3 to Supplement No. 1 Page 1 of 3

t. l~

8. - Continued

+. Document Supplement No. 2 Supplement No. I to Supplement No. 2 Supplement No. 2 to Supplement No. 2 Supplement No. 3 Supplement No. b Supplement No. 5 Supplement No. 6 Supplement No. 7 Supplement No. 8 Supplement No. 9 Supplement No.10 i . Supplement No.1 to Supplement No.10 Supplement No. 2 to Supplement No.10 Supplement No. 3 to Supplement No.10 Supplement No. k to Supplement No. 10 Supplement No. 5 to Supplement No.10 Supplement No. 6 to Supplement No. 10 Supplerent No. 11 Supplement No. 12 i Supplement No.1 to Supplement No.12 Supplement No.13 Supplement No. Ik Supplement No. 15 Supplement No. I to Supplement No. 15 Supplement No. 2 to Supplement No. 15 Supplement No. 3 to Supplement No.15 Supplement No, h to Supplement No. 15 Supplement No. 16 i Supplement No. I to Supplement No. 16 Supplement No. 17 Supplement Nc 18 Supplement No.19 Supplement No. 1 to Supplement No. 19 Supplement No.'20 Supplement No. 21 Supplement No. 22 ) t :.: M Supplement No. 23 Supplement No. 2h Supplement No. 25 Supplement No. 26 Supplement No. 27 g. Supplement No. 28 s Supplement No. 29 i Supplement No. 30 B. Rights or obligations to receive or deliver deficiency power or unit power. page 2 of 3 b

g-- - .) . v s i 1. None. Fira power is sold pursuant to various ' filed' schedules. See attachment to answer of question 15. C. Other Coordinating Arrangements 1. None 4 a4e Page 3 of 3 l .. - - -. - - - - - - -. - - - - - - - - - - - - - - - - - - - - - - - ~--- - ~~

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'9. List non-affiliated electric utility systems with peak loads smaller than applicant's which serve either at wholesale or at retail adjacent l to areas served by applicant.. Provide a geographic one line diagram of applicant's generating and transmission facilities (including sub-transmission),-indicating the location of adjacent systems and as to such systems indicate if available their load, their annual load growth. [ their generating capacity, their largest thermal generating unit size, and their minimum reserve criteria. j i Responset i A. Investor-ovned Utilities i 1. Central Louisiana Electric Company, Inc. h15 Main Street, Pineville. Louisiana 71360 F i System Peak Load 518,500 KW Generating Capaelty 565,300 KW Largest Thermal Generator 117,000 KW 2. Kirbyville Light & Power Company 7922 West Glen, Houston, Texas 770k2 System Peak Load 2,30h KW Generatign Capacity 850 KW Largest Thermal Generator h50 KW 3. Louisiana Power & Light Company 1h2 Delaronde Street, New Orleans, Louisiana 7011b System Peak Load Not Available Generating Capacity 1,892.000 KW Largest Thermal Generator Sh9,000 KW h. Mississippi Power & Light Company l Electric Bldg., Jackson, Mississippi 39205 System Peak Load 1,3h3,000 KW Generating Capacity 2,007,300 KW Largest Thernal Generator 783,000 KW 5 Texas Power & Light Company 1511 Bryan, Dallas, Texas 75201 System Peak Load 2,956,000 KW Generating Capacity 3,016,800 KW Largest Therraal Generator 565,000 KW B. Municipalities: Page 1 of 7 I

f

9. - Continued _

b t i. 1. Bryan Municipal Electric System P. O. Box 1000, Bryan, Texas 77801 System Peak Load 81,500 KW Oenerating Capacity 120,000 KW Largest Thennal Generator 50,000 KW 2. Caldwell Municipal Light Dept. Elk W. Buck,~ Caldwell, Texas 77836 System Peak Load 2,558 KW Generating Capacity None Largest Thermal Generator None 3. College Station Electric Dept. P. O. Box 9960 College Station, Texas 778h0 System Peak Load 15,5hh KW Generating Capacity None Largest Thermal Generator None h. Hearne Muntelpal Light Dept. 200-20 Ccdar Street, Hearne, Texas 77859 System Peak Load 6,700 KW Generating Capacity 7,775 KW Largest Thermal Generator 2,500 KW 5. Jasper Electric System 272 E. Lamar, Jasper, Texas 75951 System Peak Load 10,800 KW Generating Capacity 7,360 KW Largest Thermal Generator 1,360 KW 6. Liberty Light & Power Dept. 1829 Sam Houston Ave., Liberty, Texas 77575 System Peak Load 10,530 KW Generating Capacity h,h90 KW Largest Thermal Generator Not Available 7 Livingston Municipal Light Dept. P. O. Box 867, Livingston, Texas 77351 System Peak Load 6,150 KW Generating Capacity None Largest Thermal Generator None Page 2 of 7

9. - Continued I

8. Newton Manicipal Utilities i I. P. O. Box 86, Newton, Texas 75966 b '~ System Peak Load 3,192 KW Generating Capacity None Largest Thermal Generator None 9. Abbeville Municipal Water & Light Plant Box Tho, Abbeville, Louisiana 71510 i System Peak Load 12,228 KW Generating Capacity None i Largest 'Ihermal Generator None L 10. Erath Electric Dept. [ Erath, Louisiana 70533 System Peak Load 3,176 KW Generating Ct.pacity None Largest Themal Generator None 11. Gueydan Municipal Light & Vater Dept. Gueydan, Louisiana 705h2 System Peak Load 2,976 KW Generating Capacity None Largest Themal Generator None 12. Kaplan Municipal Water & Light Plant Kaplan, Louisiana 705h8 System Peak Load 7,632 KW Generating Capacity None Largest Thermal Generator None 13 Lafayette Utilities System 733 Jefferson St., Lafayette, La. 70501 L System Peak Load 10h,500 N I-Generating Capacit.y 189,950 KW Largest Themal Generator 90,000 KW Ib. New Roads Municipal Water & Light Plant New Roads, La. 70760 l System Peak Load Not Available Generating Capacity Not Available Largest Themal Generator Not Available Page 3 of 7 f

i[

9. - Continued L

[ K 15 Opelousas Manicipal Electric Dept. Opelousas, Louisiana 70570 System Peak load 2h,500 W Generating Capacity 50,690 W j Largest Therm 1 Generator 26,000 W

16. Plaquemine Light Dept.

209 Main, Plaquemine, La. 7076b [ System Peak Load Not Available Generating Capacity 8,800 W Largest Thermal Generator Rot Available i

17. Rayne Municipal Utilities Rayne, Louisiana 70578 System Peak Load

-3,918 W Generating Capacity 7,020 W Largest Themal Generator 1,750 W 18. St. Martinville Municipal Light Dept. St. Martinville, La. 70582 System Peak Load 5,799 W Generating Capacity Not Available Largest Thermal Generator Not Available 19 Vinton Electric Light Dept. 1200 Horridge St., Vinton, La. 70668 System Peak Load 3,b56 W Generating Capacity None Largest Thermal Generator None 20. Welsh Municipal Light Dept. lielsh, Louisiana 70591 System:PEnirLoad h,032 W Generating Capacity None Largest Thermal Generator None C. Rural Electric Cooperative Systems b Page h of T e e

a j'

9. - Continued 3

1. Brasos Electric Power Cooperative, Inc. P. O. Box 6296, Waco, Texas 76706 System Peak Load 183.h00 KW Generating Capacity 155,000 KW Largest h ermal Generator 66,000 KW 2. Deep East Texas Electric Cooperative. Inc. San Augustine, Texas 75972 System Peak Load h3.5k6 KW Generating Capacity None Largest Thermal Generator None 3. Jasper-Newton Electric Cooperative, Inc. 812 S. Margaret Kirbyv111e, Texas 75956 System Peak Load 22.h73 KW ~ Generating Capacity None Largest Themal Generator None b. Mid-South Electric Cooperative Association Highway 6 & Stoneham, Navasota, Texas 77868 System Peak Load Not Available Generating Capacity None Largest h ermal Generator None 5 Robertson Electric Cooperative, Inc. P. O. Box E, Franklin, Texas 77856 System Peak Load 5,1h1 KW Generating Capacity None Largest Thermal Generator-None 6. Sam 11ouston Electric Cooperative, Inc. P. O. Box 1121, Livingston, Texas 77351 a' A r is System Peak Load 35,69h KW Generating Capacity None Largest Thermal Generator None 7. Sam Rayburn Dam Electric Cooperative. Inc. ) P. O. Box h30, Kirbyville Texas System Peak Load Not Available Generating Capacity None Largest Thermal Generator None Page 5 of 7 4

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9. - Continu,4-l
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8. Houstbh' County Electric Cooperative Association Crockett, Texas 75835 System Peak Load Not Available Generating Capacity None Largest Thermal Generator None 9. Dixie Electric Membership Corp. P. O. Box 15659, Baton Rouge, Louisiana 70815 System Peak Load 55,5h8 W Generating Capacity None Largest Thermal Generator None 10. Jefferson Davis Electric Cooperative, Inc. P. O. Box 1229, Jennings, Louisiana 705h6 System Penh Load 18,581 W Generatius Capacity None Largest Thermal Generator None 11. Beauregard Electric Cooperative, Inc. Lake Charles Highway, Deridder, Louisiana 7063h System Peak Load 23,367 W Generr* ting Capacity None Largest Thermal Generator None 12. Pointe Coupee Electric Membership Corp. New Roads, Louisiana 70760 System Peak Load h,800 W Generating Capacity None Largest Thermal Generator None 13 Southveat Louisiana Electric Membership Corp. 271 N. University Ave., Lafayette, Louisiana 70501 System Peak Load 115,17h W Generating Capacity None .d:-M Largest Thermal Generator None Ib. Cajun E3ee Power Cooperative, Inc., as power supply agent for cooperatives listed above as nos. 9-12. System Peak Load Not Available Generating Capacity 220,000 W Largest Themal Generator 110,000 W Page 6 of 7

l '9. - Continued i e k I j l I NOTES: (1) System peak loads, generating capacities, and lar6est themal generator sites shcvn above are tabulated as of January 1,1971, from Electrice.1 World Directory of l Electrie Utilities, McGraw-Hill, Inc., New York, N. Y., l-80th Edition,1971. (2) Annual load growth and minimum reserve criteria for systems listed above are not available from records of applicant. 1 it-j h-J F 5 l l d-h 1 o Page 7 of 7

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10. List ~ separately those systems in Item 9 vhich purchase from Applicant (a) all bulk power supply and (b) systems which purchase partial bulk power supply TequirFments? Where information is available to Appli-l cant, identify those Item 9 systems purchasing part or all of their f

bulk power supply requirements from suppliers other than Applicant.

Response

A. Systems which purchase all bulk power supply from Applicant: (1) Investor Ovned Utilities: i Kirbyville Light & Power Company ) (2) Municipalities: i r Calavell Municipal Light Dept. Newton Municipal Utilities Gueydan Municipal Light & Water Dept. 1 Kaplan Municipal Water & Light Plant Abbeville Municipal Water & Light Plant Erath Electric Dept. St. Martinville Municipal Light Dept. Welsh Municipal Light Dept. " Liberty Light and Power Dept.

    • Vinton Electric Light Dept.
    • Livingston Municipal Light Dept.

(3) Rural Electric Cooperatives Sy stems: ' Jefferson Davis Electric Cooperative Inc. B. Systems which purchase partial bulk power supply from Applicant: i (1) Investor Ovned Utilities: i ' None SWNn (2) - Municipalities: Rayne Municipal Utilities Jasper Electric System ' Jefferson Davis Electric Cooperative, Inc. is a member of Cajun Elee. Power Cooperative, Inc. All purchases by these Coop. 's are made by and through Cajun Electric Power Cooperative, Inc. Memberr of Sam Rayburn Dam Electric Cooperative. Inc. Page 1 of 2

100 - Continued-Q I (3) RuraT'ElectYic Cooperative Systems: Deep East Texas Electric Cooperative Inc. eseRobertson Electric Cooperative, Inc. . Houston County Electric Cooperative Association "'Mid-South Electric Cooperative Association

    • Sam Houston Electric Cooperative, Inc.

" Jasper Newton Electric Cooperative Inc. ' 8 Dixie Electric Membership Corp. Southwest Louisiana Electric Mesbership Corp. ePointe Coupee Electric Membership Corp. 'Beauregard Electric Cooperative, Inc. C. Systems which purchase all or part of their bull power supply from suppliers other than Applicant (1) Investor Ovned Utilities: None (2) Municipalities: Bryan Municipal Electric System College Station Electric Dept. Hearne Municipal Light Dept. Opelousas Municipal Electric Dept. Plaquemine Light Dept. (3) Rural Electric Cooperative Systems: Deep East Texas Electric Cooperative. Inc.

      • Robertson Electric Cooperative Inc.

Houston County Electric Cooperative Association "'Mid-South Electric Cooperative Association Sam Houston Electric Cooperative, Inc. Jasper Newton Electric Cooperative, Inc. scr- ~ Southwest Louisiana Electric Mesbership Corp. ' Dixie Electric Mesbership Corp. ' Pointe Coupee Electric Mesbership Corp.,

  • Beauregard Electric Cooperative, Inc.

'These are members of Cajun Elec. Power Cooperative, Inc. All purchases by these Coop. 's are made by and through Cajun Elec. Power Cooperative, Inc. "Mesbers of Sam Rayburn Dam Electric Cooperative, Inc. ma9(embers of Brazos Electric Power Cooperative. Inc. Page 2 of 2 4

e f 4 g

11. State as to all power generated and sold by applicant the most recent average cost of bulk power sup of generating-facilities,--(b) ply experienced by applicant (a) at site at the delivery points from the primary transmission (backbone) system. (c) at delivery points from the secon-L dary transmission system, and (d) at delivery points from the dis-tribution system, in terms of dollars per kilowatt per year, in mills per kilowatt-hour, and in both the kilowatt costs and kilowatt hour costs divided by the kilowatt hours. If wholesale sales are made at e

varying voltages, indicate average cost at each voltage.

Response

The following information is furnished in response to question no.11 from cost of service data prepared in conjunction with a current filing before the FPC covering sales by Gulf States Utilities Company at whole-s ale. The hi6 hest volta 6e listed is 138 KV which is presently a part of the primary transmission (backbone) system. We vould ecnbine parts (a) and (b) in this question and offer the 138 KV voltage level figures in response. This seems practical since sales "(a) at site of genera-tine facilities" would have to consider the costs of the primary trans- [ mission (backbone) system. It goes without saying that the primary transmission system is necessary for any sales, even at the site of the Eenerating facilities. The 69 KV volta 6e level figures vould answer (c) above and 13 8 KV voltage level vould answer (d) above. ESTIMATED COST OF BULK POWER - YEAR ENDING MAY 31. 1972 Total Cost Cost in Mills per Kvbr q $/KV year Total Demand - Energy 1 1. at 138 KV 36.02 8.9h 6.70 2.2h 2. ~at 69 Ky bl.83 10.38 8.11 2.27 i 3 at 13.8 Kv LS.h5 11.28 8.90 2.38 Note: Sales are at h6% load factor based on non-coincident peak loads. ~2= h= f-. i L M.'

a ,l j

12. State (a) for generating facilities and (b) for transmission sub-divided by voltage classes, the most recent estimated cost of j

applicant's buh power supply expansion program of which the sub-jeet unit is a part, in terms of dollars per kilowatt per year, in mills per kilowatt hour, and in both the kilowatt costs and kilowatt hour costs divided by the kilowatt hours. Also, state separately J the most recently estimated cost of the subject units. i kaponset j j Gulf States Utilities Company's " bulk power supply expe.nsion program of which the subject units are a part" is cornplete in a planning sense only to the extent relating to generating units. The estimated in service date of the subject units are 1980 and 1981. Tentative j in service dates of fossil fired generating units between 1973 and 1981 are subject to change based upon later studies as to the capacity required. The whole spectrum of in service dates may change depending on whether load growth meets, exceeds, or falls short of present estimates. We have not made detailed cost estimates relative to our l transmission system for the time span here under consideration. Any i sale of bulk power would include transmission. costs since both types of facilities are required to supply any bulk power. The following tentative cost data is cceputed on the basis of a 60% I capacity factor. The cost data is based upon only gas and oil-fired units being installed before the nuclear units; however, some oil-fired units may be replaced with coal-fired units, as fuel availability and other conditions may require. This may cause a change in these cost data. Table for Question 12 Estimated Total Cost 1973-1981 Denand costs Energy Costs $/Kv/ Year $ 1s/Kvbr Mills /Kvbr Mills /Kvbr__ (a) Generation 75.67 lb.h0 10.75 3.65 (b) Transmission (See above discussion) Estimated Installed Costs Unit g Cost

  • Expected Rating Cost per KV River Bend unit #1

$379,927,000 ,9h0,000 Kv $h0h River Bend unit #2 $3h7,h17,000 9ho,000 Kv $370_ ' Includes transformers, but excludes switchyard, transmission lines and fuel. t 2

M. s 13. List and describe all requests for, or indications of interest in, interconnection and/or coordination and purchases or sales of co-e ordinating powTt mad" energy' from adjacent utilities listed in Item 9 since 1960 and state applicant's response thereto. List and describe all requests for, or indications of interest in, supply of full or partial requirements of bulk power for the same period and state applicant's response thereto.

Response

( b .A. Inquiries for interconnections' to accommodate the sale of coordinating power or for full or partial requirements of bulk power have resulted in neEotiations and signed contracts which are now in force with all of the adjacent lL utilities listed in Item 10.A and B. ( B. Inquiries which have not resulted in signed agreements and the applicant's responses thereto are as - follovs' 1. City of Hearne. Texas. Hearne was experiencing difficulties with their electrical plant in 196k and made an inquiry to the applicant. Applictnt made a proposal to serve Hearne with bulk power under the provision of Rate Schedules b23 and h23A. Hearne elected not to buy the power. 2. City of Lafayette. Louisiana. A verbal request for 200 MW of interconnectin6 power was made by the city of Lafayette on August 2,1972. Negotiations are still underway. 3. City of Plaouemine. Louisiana. A verbal request was made on August 2,'1972 for applicant to supply 20 MW of interconnectin6 power to Plaquetine. Negotiations are in abeyance pending completion of negotiations with city of Lafgyette.

7 4 ik. List (a) agreements to which applicant is a party (reproducing relevant i paragraphs) and (b) state laws (supply citations only), which restrict or preclude coor81natibn byi vith, between, or among any electric utilities or systems identified in applicant's response to Items 8 and 9 List (a) agreements to which the applicant is a party (reproducing relevant paragraphs) and (b) state laws (supply citations only) which restrict or preclude substitution of service or establishment of service of full or partial bulk power supply requirements by an electric utility other than applicant to systems identified in Items 8 and 9 Where the contract provision appears in contracts or rate schedules on file with a federal agency, identify each in the same form as in previous responses. Where the contract has not been filed with a federal agency, a copy. should be supplied unless it has been supplied pursuant to another item hereto. Where it is not in writing, it should be described. Responset With the possible exception noted belov, applicant does not believe that any agreements to which it is a party restrict or preclude (1) coordination (as defined in the questionnaire) by, with, between, or among the utilities identified in response to items 8 and 9 or (ii) sub-stitution of service or establishment of service of full or partial bulk power supply requirements by a utility other than applicant to a utility identified in response to Items 8 and 9 Applicant is a party to a Contract with Sam Rayburn Dam Electric Co-operative, Inc. (Sam Dam) dated February 13,196h, filed as FPC Schedule No. 98. Sam Dam contracted with four member municipalities and two member cooperatives for the sale by Sam Dam and the purchase by the members of the. total electric service requirements of the members. Applicant agreed in its Contract to sell to Sam Dam and Sam Dam agreed to purchase the power and energy necessary to fulfill these requirements of Sam Dam's members. These members may terminate their contracts upon 36 months' advance notice; so any effect vould be temporary and at the vill of the members. (excerpts attached) Statutes which may affect substitution of service are LR3 b5:123; Tex. Rev. Civ. Stat. Articles lh36a and 1175(12). G=- % ~

1k. - Attachment' } i. [ I ARTICLE III SALE OF POWER AMD ENERGY BY.THE COMPANY TO SAM DAM CO-OP FOR DELIVERY TO CERTAIN SPECIFIED MEMBER MUNICIPAIS i. Section 1. Electric Service by the Company. Gulf States shall sell to the Sam Dam Co-op, and deliver for the secount of Sam Dam Co-op, and the Sam Dam Co-op shall purchase and cause to be received, the amounts of electric pwer capacity and the acecepanying energy necessary to fulfill L the electric service requirements of the Member Municipals listed belw in i. the areas within their respective city limits as constituted and established from time to time, and within such areas outside such city limits as are normally and/or historically served by such Member Municipals t (1) City of Jasper, Texas (ii) City of Liberty Texas s (iii) City of Livingston, Texts j (iv) Tovn of Vinton, louisiana ARTICLE IV SALE OF POWER AND ENERGY BY GULF STATES TO THE SAM DAM CO-OP FOR DELIVERY 'IO CERTAIN SPECIFIED RURAL ELECTRIC DISTRIBUTION COOPERATIVES Section 1. Electric Service by Gulf States. (a) Gulf States shall sell to the Sam Dam Co-op, and deliver for the account of the Sam Dam Co-op, and the Sam Dam Co-op shall purchase and cause to be received, the amounts - b.5..N of electric pwer capacity and the accompanying energy necessary to fulfill the electric service requirements of the Member Cooperatives listed belw j-which desire to purchase such service, at the points of delivery detailed on Exhibit "4", a copy of which is attached hereto and by this reference made a part hereof. 4

I 9 1: ~ d l 15. State, at point of delivery, average future cost of power purchased i from applicant to adjacent systems identified in applicant's response 'to Item 9 in te?ns of'dollax's/ month /kv for capmeity, sill / kwhr for energy and mills /kvbr for both power and energy at purchaser's present e lomo factor (a) at present load, (b) at 50% increase over present F load. (c) at 100% increase over present load, and (d) at 200% increase over present load. (All costs should be determined under present rate i schedules. ) Where sales are made under contract or rate schedules on file with a federal agency and not included in the response to Item 9, identify each in the same form as in previous responses. Where the contract has not been filed with a federal aEency, a copy should be c supplied. t-

Response

l Gulf States Utilities Company's sales of electric energy to systems identified in applicant's reaponse to Item 9 are reported to the Federal i Power Commission annually in Form No. 1. Such reporting details by points of delivery, the delivered voltage, Kw demand,' Kvbr sales, revenue s from demand, energy and other charges, and the unit rate. A copy of the applicable data for the year 1972 is attached,- If additional power is furnished under present rate schedules and assuming the customer's load factor is constant, the unit rate for energy in mills / kwhr vould be constant.- The dollar / month /Kw would also remain constant. Only the total bill vould increase in proportion to the increased requirements. } Puture costs vill be determined by such rate schedules as changed from time to time under applicable regulatory procedures. b w

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3 er me se me se es i es hs m a. ,e s e s s es. 13,200 11,918.hoo b5,11b 28.her 73,6C ,W 13,200 4,756,600 16,782 12,318 29,100..e Mio.SouthElec. Coop. 76 Conroe,7 emes RS (3) 2,k26 3.ho2 13,200 5,516,000 23,958 '11,517 35,%75 8 Dobbin, femme as (3 902 1,218 13,200 5,908,500 22,u8 14,509 36.627 Huntsvine #1, Ms. ps f 1,262 1,869 2 13,200 b,9 6,150 16,99e n,%5 26,43r '.42 nuntsvine #2, ten. I 1,189 1,596 e 8 movesota, Temas as i 916 1,197 Mid==y, Terme

(3) 94 126 7,620 62,000 1,769 1,o56 2,805 43 e

e North zuleh, Texas Rs (3) b51 630 13,200 2 h21,300 - 8,387 6,361 14,7h8 ..e ~ 13,200 1 A15.600 84 2 (1 1o.837 6 23L.5D Huntsville #3, Tex. 876 903 _37,130.556 Subtotal '8 Jeff-Davis Elec.Cbegk To Neekberry,Imatetene Cs 2,MA 3,960 69,000 16,bS1,16b 48,374 W,637 (1,b79) ,5N wins sut. 1,236 1,%& 13,200 6,722,100 24,u2 17,151 1 3h9 ,e2 A) Compton sub. Cs 1,2(o 1,800 3b,$oo 6,05k,000 24,086 13,99% 776 37,306 AF take Arthur,14 Cs grT5 1,hbo 69,e 5,166,000 18,723 13,063 , 581 31,205. Jo 33 12,814 A3 8 2,031,330 7,197 5,244 titon, tout,et.ene ,,,37,o 13,,200 63.2, - m,e 5 183.2, (7. - .*6.-- es 7 694 Cu oe, m. .n. u,Seo 16 [,' Iowa,Imuisiema 607 8h0 13,200 452 Dixie E3se, tem.b. Coop. Th Neemmed, Louisiana Cs 39,920 54,72o 69,000 tfo6/ M,ooo Tb2,512 326A80 (23,891) 1 M,3D1 m E2m Ftrk, Leutetens 2,493 3,480 34,500 12,810,000 b7,80e 31,55o 2.674 8.F. M 4.oT6 41 Clinton, Imutetena Cs 1.310 1,680 34,500 6.618,000 24,366 16,50E (7pf gg g g 1;;g g zeeh.,7, i.i a 3,750 e.o2 69.- semenest Im. EL. perab< Corp. 72 Evenyaline,I,a. 6bk 840 13,200 2,997,750 U, 6,896 ' 10,677 43 ", = asen,Imuseissa as 7a 1,050 13,200 3,733.800 13, 9**95 '#*8"' ."57 seersentes, touteteam 469 696 13.200 3.6h0,850 8,359 n,221 19,580 ~ Iota, Imaisiema 1,03b 1 bb9 13,2o0 5,269,600 19,223 13,269 3r,672 .e ~ ~ " " omeyees,Imutsieme 1,53o 2,184 13,200 7,590,800 28,514 18.580 47,09b .R noree,1eutetena 8ho 1,050 13,200 h,2er.150 15,6et 10.ho8 26,ose .6e seemax, Lostetena Cs Sh6 683 13,200 2.547,300 10,159 S,e73 16,ey .63,, 10,% 8,600 61,16o 26.3cb 87,48b

w. Ateevine, La.

cs 2,213 3,087 13,200 9,25o.50o 35 la 22 =16 57,535 13,20 5.r.i u a.e.iue,14. 1,888 2,52o seplan,Imeistema 2,056 2,h26 13,2co 9,525.600 38,73h 21,813 do,ob7 . 63,", Duhon S*,napina, La 7,16o 9,18o 69,000 39,672,000 13e,804 107,0h6 (11, 227,857 .57 " ~ ~ ~ 1491 enc h, Ereth, La k,190 5, oho 69,000 20,292,000 TT,93b h8,6E1 (6 120,227 .9F,,, ,e

  • * ~

Imenvine, touteteam Cs 835 1,oSo 13,2o0 3.690.750 13.533 8, cal (3t6 23,2s8 .63 .o e. a3 WBF F-81 e g.O 486, 3,,g .s-+ - f.

V .. I. g:f . ~.... 15 ATTAC9 srr _,. 72 93t7 STA?ts UTILITIES coleampY w se *7 outr s7Ates trrxLI7 ras Coensrr Sass 59 88E544st h esq s5 -a can ~ n.. - ~ ~. - . a. -

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s. ~ 3~,u" s. -a.. a -~ ... s e .I !J.j{ I a.- - e-- 4 l e---. m 4J J = = =- = = a =, m u m .e 13,, 1o,752,jo 3ep ' 'r7,253 km e9

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.Y 2,996 2,E 1,26o 13,00 6,236,75o 13,726 lo,=e7 b=1 25m 61 . ana.ese ra. m. nom. car >. trots sprinse,1.. o,el-e, a-s, t.. 3 o emo,rouletene b,685 5,700 69,00o 2e,622,000 87,161 en,596 (8,tn leeM .56 st. seertiev111., La. as 738 908 13,2co 3,56k,225 th,o95 e,291 22,396 63 s suleemd,Lemielema as 1.hos 1,795 13,200 6.696,9 m 26,138 15p Tes bl.we 63 n1 63 153Q Laterette,Ia.Sesm et.) as 7,196 9,406 13,200 33,689,8W 133,8 4 77,99e F 1 avert-st. John,14. %,715

  • 000 13,200 26,91o M 87,699 76,M2 M,

e Arnemoville, Im. 1,81b 2,2o5 13,200 8,n5,9% 33,m 21,wh M.M 8 cecelia, Iceleiena 1 b.13b b,91h 13,200 19,M4,000 76,983 4,065 122,9s6 .63 77,o35.O sidae pond,La.W' 2.576 3.2b5 13,200 12,310,200 67,951 27.096 . W,299 .99 pidge good,14. 13,114 18,000 69,000 6k,82b. coo 2bb,032 156,3h6 (20,119)- .e Landry Bond,14.

  • 610 2,352 13,200 7,501,200 30,076 17,197 47,273

.63 se o Airport Lasistena "5,621 7,392 13,200 26,016,760 lob,551 59.500 16h,o51 63 u .i 1sorth Caremero,14. 1,577 1,990 13,200 7,515,900 29,327 17,726 - 47,oS3 63 m u Cerenero, Louisimma 5,o98 6.3% 13,200 25.024.3m 96,818 60,751 155,569 62 e. Dae, Lasielena 2,819 3,465 13,200 13,932,450 52,441 Aq 86.h?? Branch, Louteiana ns. 1,754 2,310 13,200 10,159,800 32,615 26,269

  1. ,8 oeuren point 14.

as 2,k29 2.896 13,200 12.361.w6 6 181 ' 31.035 Mon 6 a us.376.eu 1 1.1M.u9 UGI) 2.** W se.,s t.t reinte Causee n. samme. ory. 75 sesrsensa,Louielems as 2p b,2m 13,200 lb.126,e m 52,696 3h,813 2,774 ~I ^1[*,ee .3 ,S,g 1.1,mia. Louisi-a 2,o30 2,9ho 13,200 20,676,900 37,953 26,5cb 2,051 n cresee twte,14. k25 588 13,200 2,o'77.9m 7.899 5.12"

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154 231 13,200 639,b50 3,oe9 1,224 1 31 ,gg g g2,dB 25 ::: i Dayan Flet=amina, La. 9=

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  • u,2=

s. .re m.. La. seenregart Elee. Coep. 73iRinder,Lantaiens as 1,7h3 2,80b 13,200 9.3h9,200 5.,514 23,255 1,83o MM 2P .O a =we sinfr. Ia. 2.867 4,158 23,200 lb,738,0N 56,719 36,an 2,865 g,677 .2s8 E a isee ian,Immisiana 2,660 3.h66 13,200 12.650.4m 29.M7 2.552 35.237.600 Ub.42b 7.247 NM Ah r e M 8' Subtetal M n (1) Infbruation not ownLlahLe. see previous -.,. - . wita the 8' Cammission la regartt rey srtieg data for F.F.$ Flurin 17-1l. M tesista, fuel clamme ad,tiertedsats endl (2) Depresents voltauge zo contreet demuid speca[matistata=d try customer 1br lptandby M. d [ allomuuteos fer empeEity riesforindividualpoishabfcorseebut (3) contreet with e6en :ooperata,e e,seifice liest is, seemet te cessenr whieb cm y e 13 reguirud te fhrnista. .2 "'Y ' *n C

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p.,- % N e 4, I

t;m m . ii !I -) a 16; g' State whether applicant has prepared, caused to be prepared, or received engineering, studies f,or generation and transmission expan-sion programs v6f ch includi' loads of each system in Item 9.-

Response

Studies are run-representing the system loads of those systems with -which we have interconnections. We have run joint studies with or we have received studies.from the .I following: A. Central Louisiana Electric Company,-Inc. i B. Louisiana Power and Light Company t C. - Dixie Electric Membership Corporation D. Jefferson Davis Electric Cooperative, Inc. E. Beauregard Electric Cooperative, Inc. F. Southwest Louisiana Electric Membership Corporation G. Cajun Electric Power Cooperative. -Inc. H. Lafayette Utilities System i f i db l

M p

17. List adjacent systems to which applicant has offered to sponsor or; to conduct system surveys in contemplation of an offer by applicant to purchase EeYge 6f consolidate with said adjacent system, subse-quent to January 1,1960.

l Besponse: 1960-1962 . Liberty, Texas - Studies made on Liberty Electric System . in contemplation of offers. 1965 Erath, Louisiana - Study made by GSU on the electric system owned by the city. 1965 Hee.rne,-Texas - GSU made study of the electric system of 5 the city.. 1965-1968 SLEMCO - various studies conducted by Company on-joint operations ~ and/or acquisition. 1968 Dow Chemical Co., Plaquemine, Louisiana - GSU offered to make study to purchase company's generating facilities. 1968 Central Louisiana Electric.Co., Inc. - GSU made preliminary studies on feasibility. of joint operation and/or acquisition. 1968' .New Iberia Naval Auxiliary Air Station - Study prepared with intent'of bidding on system. 1969 Plaquemine, Louisiana - GSU and city agreed on a study of-the city's electric system. i 1972 Opelousas, Louisiana - Study of city's facilities made.with. l . respect to GSU's making a bid' as requested by the city, a i L l l r l i 'f. t

s ~18. List applicant's offers. or proposals to purchase,- merge or consolidate with electric atilities, subsequent to January 1,1960.

Response

i 1960-1962 ' Liberty Texas - Offer made by GSU to purchase the electric system of the City.of Liberty. Offer rejected.

Instead, city bought GSU facilities.

c 1965-Hearne, Texas - GSU made offer to the city for the purchase' .of its electric system. Negative = vote 2/5/67 by citizens. l 1972 Opelousas, Louisiana - GSU made a bid, as requested by the city to purchase electric system belonging to the city. b o (I '

r \\ '-' ' h3 a.. e - 19 List all acquisitions 'of or mergers or consolidations with electric-utilities by' applicant, subsequent to January 1,1960, including: (a) - The name and' principal place of business of the system prior . to the acquisition, merger or consolidation; ] (b) The date the acquisition, merger or consolidation was consummated; (c) Gross annual revenue and most' recent peak load, dependable capacity-and the-largest thermal' generating unit of the. system, prior to the dates of consummation. Responses-There have -been none. f 1-i .k 4 e g

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. g.. - 2 e. 20. St' ate' applicant's six (or fever if there are not six) lowest-industrial or-large connercial rates' for finn electric power supply in terus of.= cost for power"~hd energy ih mills per kilowatt hour (and separately, the damand and energy' components) and' indicate the portion of the charge attributed to bulk power supply. State the rates or rate . blocks.' applicant utilizes for its six (or fever if there-are not six) ~c promotional services such as electric space heating, electric hot water heating, and the like, in tenns of mills per kilowatt hour for power and energy and indicate the portion of the rate of rate blocks attributed to bulk power supply, f

Response

Gulf States Utilities Company supplies power to large commercial and industrial customers under schedules LGS, LPS and LIS. Applicant's-sales under each of these schedules for the year 1972 is detailed on i the attached sheets which are excerpts from applicant's FPC. Form No; 1. Power for water heating is supplied under rate. schedule WHS and power for space conditioning service is supplied under schedule SCS. Both of these schedu3es are rider schedules to be used in conjunction with schedules for General Service and Large General Service. A copy of the schedules for water heating and space conditioning service are attached. Rates are not apportioned to bulk supply charges, etc. & t'-L

e~ l s.

20. Attachment-Excerpts gom pages 41hc and h1hD of FPC Form No.1 - Annual Report -of Gulf States Utilities Company to the Federal; Power Comission for the year ending December.

~ 31, 1972 k Average Kvh of Revenue Ntunber and Title of Rate Number of Sales per pyr Schedule Kwh Sold Revenue Customers Customer Kvh, Sold Louisiana hh2 Camercial Sales LPS Large Power Ser. 122,51h,000 83h,397 98 1,' 122,51h,000 .68 DDL Dusk to Dawn Lighting Serv. h,689,322 221,hh5 02 26h(e) k.T2 FC Facilities. Charge 163,031 96 FIS Flood Lighting 11,h21.h7 1 3 97 Service' 287,9 h6 SHL Street & Highway Lighting Ser. 1,608,053 56,851 97 120(e) 3 54 GS General Service (and riders). 562,616,317 1h,976,2h7.bh 19,823 28,382 2.66 IES Large General Serv. (and 9,hhh,5h6.77 623 1.125.915 M riders) 701.hhh,921 Total commercial 1,393,160,559 25,707,9h2.61 20,832 66,876-1.85 hh2 Industrial Sales hoh-L Oil Field & Oil Pipe Line Service 6,h29,277 1hh,649.82 146 hh,036 2.25 h05-L Large Oil Field & ~1 1,156,800 1.80 Pipe Line Serv. 1,156,800 .20,796.82 LPS Large Power Ser. 1,023,6h9,738 T,896,553.h6 19 .53,876,302 ..T7 LIS Industrial Serv. h,hh7,102,610 25,973,001.h5 11 40k,282,055 58-Page 1 of 6';

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5

. ; ; 3:.

20. - Attachment Excerpts from pages hlkC and h1hD of FPC Form No.1 - Annual Report of Gulf St'ates

-Utilities Company to the Federal Power Conunission for the year ending December. 31, 1972. Average Kwh of Revenue-Number and Title of Rate ' Number of Sales per per Schedule Kvh Sold Revenue Customers Customer Kvh Sold kh2 Industrial Sales (Cont'd) i FC Facilities Charge 1,615,026.6h kb5-L Irrigation Pumping Serv. h3,7h6 1,h73.91 6 7,291 3437 SHL Street & Highway Lighting Serv. 153,76h 15,222.16 h(e) 9 90 DDL Dusk to Dawn Lighting Serv. 25h h08 12,777.5h 11(e) 5.02' FLS Flood Lighting 4.21-Service 7,360 310.09 LO7-L Large Pipe Line J Service 171,5h0,000 1,h61,805 9h 3 37,180,000 .85 GS General Service (and riders) 32,853,269 816,971.79 2,338 1h,052 2.h9 LGS Large General Ser. (and riders) -h28,2h5,765 5.392,277.h7 202 2,120.029 1.26 Total Industrial 6,111,h36,737 h3,350,867.09 2,741 2,229,638 71-(e) Excludes duplicate customers served under other rates also

20. - Attachment

. a Excerpts from pages h1h and' hlhA of FPC Form No.1~ - Annual Report - of Gulf States Utilities Company to the-Federal Power Commission for the year ending December 31, 1972. Average Kwh of' . Revenue Number of~ Sales per: per. Number and Title of Rate Schedule Kwh Sold Revenue Customers-Customer Kwhl$old Texas hh2 Commercial Sales SHL Street & Highway ~ 39,829 99 19h(e) 3 96 Lighting Serv. 1,00k,762 DDL Dusk to Dawn Lighting Serv. 3,827,575 191,003.11 22h(e) k.99-FLS Flood Lighting 3.66 Serv. 57,6h5 2,110 90 10-1 Comunercial Serv. Metered 9h6 72.38 1 9h6 7.65 305-T General Power Service 10 '58.22 10-5.82 LPS - Large Power Ser. 35,532,105-326,81h.37 ' 1 35,532,105 92 11,8h8.08 FC Facilities Charge GS General Service (and riders) kTh,310,911 13,h35,656.02 18,912 25,080 2.83 LGS -Large Gen. Ser-vice (and ders) h72,577,156 6,884,32h.79 h8h 976,399 1.h6-t 987,311,110 20,891,717.86 19,81T' k9,821 2.12; Total Commercial Page 3 of 6 q l l l

3, fj ' r" 1: g,, ~ ~ -y c.5 - - 1 o.

20. - Attachment L ". -

Excerpts. from pages h1h ' and' hlhA of FPC Form No.1 - Annual' Report of Gulf States Utilities : Company to the' Federal Power Comutission for the year ending December 31, 1972. Average Kwh of-Revenue-Number and Title of Rate Number of.. . Sales. per. .per Schedule Kwh Sold Revenue Customers-Customer Kwh Sold Texas - Cont'd hh2 Industrial Sales j h0h-T Oil Field and 011 Pipe Line S6ry. 6,795,683 151,865.Sh -130 .52,27h 2J23 h05-T Large Oil Fl' eld & Pipe Line. Sdhr. 27,139.161 hh6,172.63 9 3,015,h62- .1.6h-LPS Large Powerf er. I' B (and riders) hh6,029.616 h,109,131.00 lb 31,859,258 .92 LIS Industrial Ser. (and riders) 3,215,301,800 20,372,182 9h 13 2h7,330,908 .63-FC Facilities Charge 985,193 06 SHL Street & Highway Lighting Ser. 176,717: 3,7h6.26-16(e) 2.12 DDL Dusk to Dawn Lighting Ser. 303,197 15,177.h9 8(e)

5.01-FLS Flood Lighting Service 13,890

'565 60 k.07 305-T General Power Service-95,h0h 3,1h6.23 6 15,901 3.30 GS General Service (and riders) h6,776,15h 1,230,h65.56 2,810 16,6h6 2.63 LGS Large General Ser. (and riders)' 561,917,8h1 7,272,596.75 239 2.351.121 1.29 Total Industrial h,30h,5h9,h63-3h,590,2h3.06 3,2k5 -1,326,518' .80. (e) Excludes duplicate customers served under other rates also. % bvc4 -..-=.-a.

20. - Att chment

~ ~ ~ ~~-~~ y: 3, ;. t-l M-csosownts ' ..F Culf States Utililles Company Schedule WHS - l m, Temas I e RfDER FOR WATER HEATING SERYlCE 1, 7 3. APPlJCABILITY his ridet h applicable under the regulet terms and conditions of the Company to' Customets served under i General Service or Large General Service Schedules, hoeinafter referred to as the ' tegular schalute", who have electric weser bestets meeting Company's specifketions for time. controlled water heeting of the automatic storese type. 11. MODIFICATION OF REGULAR NET MONTillir MATE %e set monthly rete of the regular schedule is modified to include the following procedures: K Service 'to seter hester customers will be billed in accordance with Procedure "A" or Procedure "B" specified ~ below. A. De Company will determine Customer's water heating use by separate sneter if. Customet's wiring is so et. ranged that werer heating use con be segregated for billing purpows et point of delivery from belence of Customer's loed. In such cow Company will bill water heating wavice et 1.35e net per kwbt.- e Whete water heating utvice has been separately metered and monthly uw het everaged less than the ellowances under Procedure '8" below for a year, Company will, upon request of Customet, remove sepe. rete metet and thereelier bill according to table listed under Procedute "B" below. B. There water heating service is not separately metered the following final blocks of kwhr become effective and will be billed et 1.35e net per k=bt, provided, however, that the first 150 kwht of total service uwd in e any toonth must be billed in accordance with the regular whedule and that not Icis then one half of the kwht of total utvice will be billed.in accordance with the regulet rete whedule and applicable tiders other then this rider: i i Tonk Cepecily Final Block 30 to 45 gallone - 300 kwht -t 46 so 70 gallons. 400 kwht 71 gefloos and larger $ kwbt per gallon, but oos less than 500 kwbt De billing loed as determined in the regular rete schedule will be reduced by the greater of 3 kw ot 0.03 kw per galloe of total tank cepecity, provided, however, that such reduction in billing load shall not c*perate to reduce the billing load below one.helf of the billing Iced that would otherwise be opplicable under the regulet rete schedule. Procedures "A" and "B" ste normally on et leert a twelve month basis and Customer man remele on one pro-cedure et least twelve months before changing to the other procedute unless Customet installs additional water hesters @.5., or respovos enhting wowt bestees. ePlus applicable fuel and mz odjustments specified in reguist schedule. .l. 6/73 Page 5 of 6

20. - Attachment

,s a CSU1084 e943 Gulf State. Utilitice Company Schedule SCS Tenas MIDER FOR SPACR' CONDITIOMNG SERVICE I. APPLICABILITY nis rider is applicable under the regular terms and conditions of the Lompany to Customers served under Schedule G5 or LG5 who have one or more of the following types of equipment (1) Electric heat pump and'or resistance < > ps space heating equipment for the primary continuous, year-round cooling and beating equirements of the spese with which it u associoned. (2) 25 H.P. or more of connected electra air cond itioning. In order to quabiy for this rider, the applicable equipment installation, control, operation, siaes and types of motors and supplementary resistance heating elements must meet Company's specifications. The wiring for equipment subject to this rider must be arranged so that such equipment may be wgregated for billing purposes from the balance of Customer's load. II. NET MONTHLY RATE he net monthly rate of the regular schedule is modified to include the following procedures. Billing will be in accordance with procedure "A" or ' B specified below, whicheser results in the leer cost for service used for electric air conditioning, heat pump and/or space heatin6 service. A. Service to Customer for electric air conditioning, heat pump and/or space heating will be billed at 1.654' net per kwbr during " Winter Monchs" and 3 354' net per kwbr during " Summer Months

  • Balance of Customer's service will be billed on Schedule GS or LGS, tshichever is applicable, except that for purposes of computing the minimum net monthly charge the billing load for the currens month will be used.
  • Plus applicable fuct and esa clause adiustments specified in Schedule G5 or LGS, whichever is applicable.

B. Customer s total servue including electric air conditioning, heat pump, and/or space besiing will be billed oo Schedule GS or LGS, dichever is appliable. III. DESIGNATION OF WINTER AND St MMER MONTHS Winter Months will be the months of November to the following April. inclusive, and Summer Months will be the months of May to October, inclusive, as used for billing purposes. 6/72 Page 6of6

g-y;ZZED % A. ~ UNITED STATES h ATOMIC ENERGY COMMISSION i 'l V* wAsmsovos. o c. som ff-JQ n.98 bN 'Jf y,

y,! 't i git (20 mince Joseph J. Saunders. Esq.
c. r7 rite NUMBEll Chief, Public Counsel and I

. TEASE ADVISE Legislative Section 'h r Antitrust Division CORRESPONDENCE UNIT Department of Justice ROOM 3218 EXT. 2450 In the Matter of Gulf States Utilities Company Nuclear Power Plant

Dear Mr. Saunders :

We understand that Gulf States Utilities Company intends to apply shortly to the Atomic Energy Commission for a license to construct a nuclear power plant. In accordance with section.105c of the Atomic Energy Act of 1954, as amended (the Act), copies of the applicatiort - and infonnation requested by the Attorney General relative to hS aTti-trust review will be transmitted promptly upon receipt. O ~ In an effort to avoid delays on decisions for construction permi? .s-applications as a result of prelicensing antitrust review, we hag attached a listing of smaller municipals and investor-owned utilt41 who purchase bulk power from, interconnect with, adjoin service e 't with or may in some way be affected by the operations of the pro c84ve applicant. We believe that by providing you with this information pFftr to the formal submission of the applicant to the AEC, the Attorney General will be able to initiate his investigation as soon as this material is received. Through this procedure potential antitrust problems may be identified quickly and me hope reduce the review time to less than the 180-day period pmvided by the Act. Sincerely yours, \\ l b ~' oseph Rutberg i Antitrust Counsel for '\\ AEC Regulatory Staff 9 Inclos ure: )3 As stated f. x, @y og-D v2 s[ ~ ?! JUL 3 1972 L, 1 @y-jN ,c. j Q~~TNTITRUS1 L i >&n. i ,}}

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