ML20043B099
| ML20043B099 | |
| Person / Time | |
|---|---|
| Site: | River Bend  |
| Issue date: | 12/31/1975 |
| From: | Adams S GULF STATES UTILITIES CO. |
| To: | |
| Shared Package | |
| ML20042C775 | List: |
| References | |
| FOIA-89-559 NUDOCS 9005240188 | |
| Download: ML20043B099 (66) | |
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t Before the UNITED STATES NUCLEAR REGULATORY COMMISSION-Docket Nos. 50 h58. 50 h59' In the Matter of Gulf States Utilities Company r
River' Bend Station Units 1 and 2 AMENDMENT 3 TO THE LICENSE APPLICATION DOCUMZNT Gulf States Utilities Company, applicant in the above captioned proceeding, hereby files Amendment 3 to the License Application Document filed in connection with its application. Amendment 3 is an update to:
the most current, corporate and-financial information on Gulf States and River Bend Station.
Respectfully submitted, g-GULT STATES UTILITIES COMPANY-M S. L. Adams Senigr Vice President 032fs a
'9005240188 90 PDR : FOI A pDR GPECTORB9-DD9 '-
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LICENSE APPLICATION DOCUMENT AMENDMENT 3 C
INSTRUCTIONS Text Remove Innert New License Application cover License Application cover page and text pp.1-14.
pa6e and new text pp.1-14.
New Affidavit with correct Affidavit behind text date of Dec. 31, 1975 Exhibit A Remove Insert 1974 Annual Report after 1973 Annual Report Financial Review 11ated December 31, 1972 Prospectus dated
-. Prospectus dated September 21, 1972 April 29, 1975 e
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.g BDORE THE lui1TED STATES NUCLEAR REGULATORY Cole (ISSION 9
DOCKET NOS, so.hs8 & so hso IN THE MATTER OF -
GULF STATES UTILITIES COMPANY
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APPLICATION FOR LICENSES UNDER THE ATOMIC ENERGY ACT OF 19 %
- AS AMEhTED FOR RIVER BEND STATION UNITS 1 AND 2 w
Amendment 3 3
December 31. 1975 N
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BEFORE THE
' L"JITED STATES NUCLEAR REGUIATORY COMMISSION
= DOCKET 'NOS.= 50-Sk8 6 50-5k9 4~
IN THE MATTER OF QULF STATES UIILITIES COMPANY L
q APPLICATION FOR LICENSES Gulf States Utilities Company (hereinafter sometimes referred to as
]
" Applicant") hereby makes application, pursuant to the Atomic Energy Act of 1954, as amended and the provisions of the Nuclear Regulatory Comission's
-Rules and Regulations thereunder, for the necessary Class 103 construc-tion permits-and operating licen' es to construct, own, possess, use and s
~ operate two nuclear electric generating units to be located in West Feliciana Parish,', Louisiana, < a'nd.to be known as " River Bend Station, l
Unita 1 and' 2" (hereinafter sometimes referred to as " Facilities") as an i
'I integral part of its total operating system, together with appropriate-i source, special nuclear, and by-product material licenses. A description d
of the facilities and discussion of applicant's-contractors is contained' in the PSAR (See Chapters 1 and 13) submitted herewith.
This application consists of:
(a) The general information required hy 10 CFR Section 50.33, which is set out herein; (b) The technical infor-j matior. and safety analysis-report required by 10 CFR part 50, especially
,j Section 50.3k, which is set out in a separate document entitled " Preliminary j
Safety Analysis Report, (PSAR), River Bend Station Units 1 and 2, Gulf States Utilities Company", forwarded herewith and made a part hereof; (c) An 1.
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.3-Environmental Report ent.tled " Environmental Report - Construction Permit
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C Stage, River Be,nd Station Units 1 and 2, Gulf States Utilities Company",
t as required by 10 CFR Part 50, Section 50.30(f) and Appendix D of said part 50 forwarded herewith and made a part hereof; and (d) A separate document including information requested by the Att'orney General for anti-trust review of facility litunse applications entitled " Antitrust Review, River Bend Station Units 1 and 2, Oulf States Utilities Company", as required by 10 CFR Section 50 33a and Appendix L to Part 50, is forwarded herewith and made, a part hereof; and (e) General information required by 10 CFR Section 70.22, 10 CFR Section 30 32, and 10 CyR Section h0.31.
GENERAL INFORMATION A.
General Information required by 50.33 of NRC Regulations:
a.
Name of ADD 11 cant:
Gulf States Utilities Company b.--
' Address and-Princital Office of Apolicant:
P. O. Box 2951
' 285 Liberty Avenue Beaumont, Texas 77704 9
c.
Description of Business:
The Applicant is engaged principally in the business of generating electric energy and distributing and selling such energy at retail in southeastern Texas and south central Iouisiana in an area about 350 miles long, having an estimated population of 1,270,000 and comprising i
approximately 28,000 square miles. The Applicant sells electric energy
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at retail in 286 communities and surrounding territory; and sells for i
resale, electric energy to 10 municipal systems, 6 rural electric coop-eratives and one other utility. Natural gas is purchased at wholesale and distributed at retail in the City of Baton Rouge, Louisiana, and 2.
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vicinity.- The demand for electric service (peak load) in the area served by Applicant-has increased at an average annual rate of approximately 9%
1 during the period 1963,through 1974 and is expected to continue to increase at approximately 7% 'for the period 1975 through 1985 Yearl;' growth pro-jections through 1985 are given in the Appendix L responses and in the Environmental Report Section 1.
The proposed nuclear generating facilities-
+
' are a necessary part of Applicant's continuing construction of facilities--
. to provide electric energy to meet such increasing demand' and to offset
. increasing difficulties in obtaining fossil fuel for other generating units l
of Applicant'.
The business of Applicant is further described in the annual and finan-cial reports, Exhibit A, and By-Laws and Restated Articles of Incorporation.
Exhibit'B, filed as exhibits hereto, d.(1)
Not applicable, d.(2)
Not applic'able.
d.(3)(1) state of Incorporation:
The Company was incorporated under the laws of Texas on August 25, 1925, and in addition is qualified to do ' business in Louisiana.
- d. (3)(ii) Directors and principal Officers _:
All principal officers and directors of applicant aie citizens of the United States of America. Their names and res'. dent addresses are as follows:
DIRECTORS Name Addre ss Samuel L.. Adams 985 Dowlen Road Beaumont Texas 77706 John W. Barton Claycut Apt. #9 4900 South Foster Drive Baton Rouge, Louisiana 70806 3
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- Egy, Addreso Seth W. Dorbandt Plantation Apt. K-3 4 '
Conroe Texas 77301-Edwin W. Hiam 858 South Street -
Needham, Mass. 02192 Will(am H. LeBlanc, Jr.
6745 Goodwood Avenue
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Baton Rouge, Louisiana 70806 Normen R. Lee 1220 Wilchester Circle Beaumont, Texas 77706
~ Joseph R. _ Murphy 998 Goodhue Road
' Beaumont, Texas. 77706 Monroe J. Rathbone, Jr.
7225 Richards Drive Baton Rouge, Louisiana 70809 3
Alvin T. Raetzsch, Sr.
3900 Country Club Lane Lake Charles, Louisiana 70601 Floyd R. Smith-885 Belvedere k) rive Beaumont, Texas 77706 Bismark A. Steinhagen 155 W. Caldwood Drive
' Beaumont, Texas 77707
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4-James E. Tauseig, II Henderson Bayou Road Lake Charles, Louisiana 70601-P. O. Drawer N-Arthur Temple Diboll, T,exas 759h1
' PRINCIPAL OFFICERS Name and Office Residence Floyd R.' Smith Chairman of the Board of Directors 885 Belvedere Drive and Principal Executive Officer -
Beaumont, Texas 77706, Norman R. Lee 1220 Wilchester Circle President and Principal Operating Officer Beaumont, Texas -77706 Thomas A. Page 5535 Benaire Lane 3
Executive Vice President Beaumont, Texas 77706 h.
Amendment 3 Dec.1975 k
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W Name and Office Residence Samuel L. Adams Senior Vice President 985 Dowlen Road Engineering and Production-Beaumont, Texas 77706 Construction i
Joseph'R. Murphy..
Senior Vice President 998 Goodhue Road l
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Operations Beaumont, Texas 77706 P
Jerome M.' Stokes 57h0 Regina Lane Senior Vice President Beaumont, Texas' 77706 Joseph E. Bondurant-k910 Gladys Vice President Beaumont, Texas 77706 Charles D. Glass 6265 Wilchester Lane.
Vice P2tsident Beaumont, Texas 77706
' William E. Heaner, Jr..
Rt. 1. Box Kh03 Vice President Beaumont, Texas 77706
. Jasper F. Worthy Tk3 Rodney Drive 3
Vice President Baton Rouge, Louisiana 70808 Robert E. White 1535 Howell Vice President Beaumont, Texas 77706 Robert W. Jackson 725 Randolph Circle i
, Secretary and Treasurer Beaumont
- Texas 77706
' James L. Brasvell 4280 Park Controller Beaumont, Texas 77705' d.(3)(iii) Absence of Foreign Control:
- Applicant is not owned, controlled, or dominated by an alien, a foreign corporation or foreign government. No shareholder of the Applicant -
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owns 10%' or more of the outstanding Common Stock.
- d. ( h ).
Applicant is not Acting as Agent or Representative:
l The Applicant is filing this Application sole 4 for its own
. purpose and is not acting as an agent or representative of another person.
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Applicant,is hereby applying for such permits and licenses.as may be necessary or appropriate to _ the acquisition, construction, use,,
possession, and-operation of River Bend Station Units 1 and ~2 as described -
' in this. Application, which facilities are to be used as a part of Applicant's -
electric utility plant for the generation of electric energy Vy Applicant, including the following permits and licenses [
(1)
' Construction' Pemit Pursuant to Part 50 of the NRC Regulations.in title 10 CFR Chapter P
I, Applicant. applies for " Construction Permits" for a' class 103 facility (River Bend Station Units 1 and 2) to be used as a commercial facility to
' generate electric-energy for sale and distribution. This permit is re-quested.to be issued by April,1976, providing for completion of Unit 1 3
between March,1981 at the earliest and March,1983 at the latest and of Unit 2 between March,1983 at the earliest and March,1985 at the latest, and further specifying pursuant to 10 CFR Part '50 Section 50 51 that the oPerat-ing license ~ for each Unit will be issued, if approved pursuant to 10 CFR'
- Part 50 Section 50 56, upon substantial completion of the Unit for a period of h0 years. The latest dates for completion are given for purposes of
. construction permit duration. As shown in Section 1 of the Environmental Report, it,is essential to the Applicant's and the public's interests in reliability of electric power supply that operating licenses be issued by the earliest dates given.
(2)
Class 103 Facility Overat'ing Licenses Applicant requests that upon subs,tantial completion of construc-tion of each Unit -(River Bend Units 1 and 2) Class 103 Facility Opcrating Licenses be issued upon subsequent submission to the Commission of additional data as required by Commission regulation. These operating licenses are P
requested to be issued for a period of h0 years.
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Source. Special Nuclear and By-Product Material Licenses Pursuant to Parts 30 et seq, kO and 70 of the NRC Regulations in 10 CFR Chapter I, Applicant vill require such source, special nuclear and by-product material licenses as are necessary or' appropriate authoriz-ing it to acquire, deliver, receive, possess, use, and transfer such materials - (and with respect to by-product materials, also produce and.own such material)' in connection with-the
- construction and' operation of each of the proposed River Bend Station Units 1 and 2.
It is requested that these licenses be granted for a term consistent with the rele.ted Class 103
' Facility operating licenses as requested above.
Applicant has combined its' application for these licenses in this single application as permitted by 10 CFR 50.31.
f.
Financial Recuirements:
(1)
Estimated Construction Costs _
The estimated construction costs for River Bend Staf, ion Units 1 and 2 including the first cord of nuclear fuel (which vill be purchased),
is as follows (stated in thousands "of dollars):
River Bend Station Unit 1 Unit 2 (a)
Total nuclear production plant,$ 934,261
$678,485 costs (b)
Transmission,' distribution, and general plant costs 29,062 3 (c)
Nuclear fuel inventory cost for first core 37.300 bl.300 Total Estimated Costs
$1,000,623
$719,785
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The above estimate of constructien costs for River Bend Station Units 1 and 2 are shown below (in thousande of dollars) as detailed by electric plant and nuclear fuel. inventory accounts as prescribed by the Federal Power Commission.
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Amount FPC Account Unit 1 Unit 2 Total 320 2,500
$ 4 2,500 321 381,731 181,83h 563,565 322 258,561 235,k3h k93,995 323 209,670 18k.5k8 39h.218 3
32h 76,158 72,598 148,756 325 5,6hl k,071 9,712 352-353 8,k62 8,k62 355-356 20,600
. 20,600 120.1 37.300 kl.300 78.600.
Total
.$.1 &QQ_ 622
$719.785
$1.720.kO8
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Construction expenditures of River Bend Units 1 and 2 by years are shown belovt Anss i +
Y Unit 1 Unit 2 Total 1972 5,862 5.862 1973 9,600 ' *),600 197h 23,073 1,220 2h,293 1975 35.572 3,046 38.618 1976 97.090 13.122 110.212 1977 139,566 43,836 183 k02 3
1978 208,962 55,186 264,1kB 1979 217,217 111.456 328,673 1980 181,31h 203,500 38h,814 1981 79,522 125,k19 204,9h1 1982 2,8k5 102.090 104,935 1983 55,968 55,968 1984 k.9k2 k.9k2 Total
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$719.785
$1.720.kO8 (2)
Source of Construction Funds During the construction period, the amount of internally generated cash to finance construction by. the Applicant is estimated to be between 3
35 and h5%. Such funds internally senerated' include, principally, 8.
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provisione for depreciation, retained earnings, deferred Federal income taxes, and Federal investment tax credits. Av. additional funds required i
vill be provided by external sources through the sale of additional debt securities and the sale of additional shares of preferred stock s.nd common stock, or other perinanent financing, the form, nature, time, and extent of which have not yet been determined. Any interim funds required in connection with the construction vill be supplied by cons:arcial paper and short-term bank loans. It is expected that capitalization ratios vill be maintained during the period of construction of River Bend Station at 3
approximately historical levels, viz., 55% long-term debt,10% preferred stock, and 35% common equity, although they may vary in the interval, pending subsequent issues of permanent securities. It is anticipated that additionti shares of cossmon stock vill be sold to the public to the extent required to maintain comanon equity at a level approximating 30% - 35% of total capitalization.
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'Ibe facility vin be financed as part of applicant's overan capital program. The types of securities v'hich vill be issued cannot be determined at this time. The market conditions at the time of ist le vill 1
be a factor as to which type of financing is to be undertaken. However, new permanent financings and securities issues vill be scheduled so that there, vin be as little distortion as possible in the above set forth i
capitalization ratio objectives.
(3)
Anolicant's Financial Statements See Exhibit A 1.
Annual Reports (1971,1972,1973 and'197h) 2.
Financial Review dated August.197h 3
C 3
Prospectus dated March 20,197h, November 18,197h, and April 29, 1975 s
I The present financial condition of Applicant and its historical earning ability and ability to obtain short-term and long-term financing as reflected in the financial exhibits filed herewith, as ven as.the ability to obtain rates prov1 ding a reasonable or fair rate of return', esta'611sh reasonable assurance that Applicant vill possess or be able to obtain the F
necessary funds to construct and operate the facilities for which permits and licenses are applied for hereby.
CONSTRUCTION EXPENDITURES 1963 THROUGH 197h (in thousands) 1963 29.505 196h 22,567 1965 h8.h79 1966 58,789 1967 T7,652 1968 129.k71 1969 123,273 1970 108,513 1971 91,020 1972 no.586 1973 106,804 1974 167.500' 3
Total
$1,074,159 9
Amendment 3 Dec. 1975
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FINANOING 1963 TDOUGH 1975 i'
001440W STOCK Naber Price Aggregate
,2313, of Shares _
, Per Shart,,,,,,
Proceeds,,,t,p_ 'Cesany#
May,1965 10,373,66h 2-for-1 Split
$ Feb.,1968 1,koo,000
$21.61 30,25k,000 Feb.,1970 1, Loo,000 420.155 28.217,000 Nov., 1971 2.060,000
$20.1h LO,280,000 April, 1975 3.000.000
$10 38 31.1h0.000 3
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Total' 18.173.66h
$129.891.000 P U FIRRED STOOK Dividend Wumber Price Aggregate pitg
' 3 ate of Shares-Per Sbare Proceeds to Cowany' oct., 1963
$ 4 52 100,000
$100.43 410,0h3.000 July,1967
$6.08 200,000
$100.215 20,0k2,600 Sept., 1972
$7 56 350.000
$100 1571 35,05k.985 619,d9,9,
$65.1ho.585 FIRST )CRTGAGE BONDS Principal Price Aggregate Data Series Amount Per Unit Proceeds to Com any#
Jan.,1966 5% dus 1996
$ 20,000,000 100 70999%
$ 20,1h1,998
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Feb.,1967 5 3/8% due 1997 35,000,000 101.k%
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35,k90,000 Feb., 1968 6 5/8% due 1998 25,000,000 101.3915 25,3k7.750 Oct.,1960 6 3/k% A due 1998 k0,000,000 101.175 ho,068,000 Mar., 1969 7 1/k5 due 1999 25,000,000 100.kkk%
25,111,000 Sept., 1969 81/8% A due 1999 25,000,000 99.k82%
2k,870,500 Feb., 1970 8.'./25 due 2000 30,000,000 99 789%
29,936,700 tp Dec. 1970 7 7/85 A due 2000 30,000,000 99.k2%
29,826,000 L
Nov.,1971 7 1/2% due 2001 35,000,000 99 56%
34,8k6,000 L
Aug., 1973 8 1/25 due 2003 50,000,000 99 21k%
k9,6073000 E
Nar., 197k 8 5/85 due 2004 60,000,000' 99 522%
59.713,200 April, 1975 10.15% due 2005 ko.000.000 -
99 125%
39.650.000 3
g Total
$h15.000.0t3
$h14.608.1h8
- Before Expenses POLLiffl0N CON-@0L REVENUE BORDS*
- Principal Price-Aggregate Date Series Amost Egy Untt Proceeds to Company Dec., 1974 6 3/4% dus 1984
$ 3,000,000 100.03
$ 3,000,000 Dec., 197k 71/k% due 1989 3,000,000 100.0%
3,000,000 Dec., 197h 7.7/8% due 200k ik 000.000 100.0%
1h.000.000
$20.000.000
$20.000.000
'#A portion of the proceeds from this financing are held by the trustee and will be disbursed as construction expenditures are certified.
10.
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Insurance Program Public liability insurance will be arranged through the Nuclear Etergy Liability Insurance Association (NELIA) and M.utual Atomic Energt Lia,bility' Underwriters (MAELU), or through or by any other nuclear under-writing source or through any combination of the foregoing sources, for coverage beginning at the tins nuclear fuel is shipped from fuel fabricator
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to the plant site. Applicant intends to purchase such coverage for the amounts and in the forms required by 10 CFR ikO.
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Applicant vill execute with the Nuclear Regulatory Commission an indemnity agreement as required by Section 170 of the Atomic Energy Act of 195h, as amended, and as provided in 10 CFR 1ho.,
(5)
Technical ' Qualifications A description of the technical qualifications of Gulf States Utilities and its principal contractors is contained in Section 13 of PSAR which is made a par.t of this application. A description of Gulf States' training program is contained in Section 13 2 of the River Bend i
,PSAR.
h.
Scheduled Completion Dates:
l 1
Reference; see Section e (1) 1.
(1}
Regulatory agencies which may have jurisdiction over the rates and services. incident to the proposed generation, sale and distribu-tion of electric energy.
(a)
The Fderal Power Ccusaission (b)
The Louisiana Public Service Connaission (c)
Municipalities served by Applicant in Texas will have jurisdiction over rates and services provided within their respective boundaries (2)
Trade and News Publications The following is a list of trade and news publications which circulate in the area vbere the operation of the River Bend Nuclear Power Plant vill be conducted and which are considered appropriate to I
give reasonable notice of this Application to those municipalities,
private utilitias, public bodies and coop'eratives, which ad ght have a potential interest in the River Bend Nuclear Power Plant Trade Publications (a)
Meiana Pa*ish Gove'rnment Magazine Police Jury Association Suite 200, Jack Tar Capitol House Baton Rouge, Iouisians 70801 11.
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Louisiana Meieiuni Review Louisinna.Maicipal Association Suite ' 301, Jack Tar Capitol House Baton Rouge, Louisiana 70801 (c)
The Boardman Louisiana School Board Association P. O. Drawer 53217 Baton Rouge Iouisiana 70805 (d)
_ Rural Iouisianan Association of Louisiana Electric Cooperatives. Inc.
P. O. Box Th9 Opelousas, Louisiana 70570 News Publications (a)
State Times /lbrning Advocate P. O. Box 588 Baton Rouge, Louisiana 70821 (b)
St. Francisville Democrat P. O. Box 7 St. Francisville, Icuisiana 70775 (c)
Zachary Plaim P. O. Box 279 Zs.:hary, Louisiuk 70791 (d)
West Side Journci EN. Jefferson Avenue Port Allen, Louisiana 70767 (e)
Denham Springs News P. O. Box 458 (125 Range Ave.)
Denham Springs, Iouisiana 70726 (f)
Livingston Purish h P. O. Box 98 Denham Springs,' Iouisiana 70726 (g)
Pointe Coupee Banner 123 St. Mary Street New Roads, Louisiana 70760 (h)
Baker Observer P. O. Box 517 Baker, Louisiana 7071h j.
Restricted Data:
No restricted data or other classified defense information is
-involved in this Application and it is not expected that any will become
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1i involved. However, if it does, applicant will appropriately. segregate and safeguard said information and, in compliance with 10 CFR 50 37, Applicant hereby agrees that it will not permit any individual to have access to restricted data (as defined by the NRC Regulations) until the Civil Service Connaission shall have made an investigation and report to the Conunission on the character, associations, and loyalty of such indivi-dual and the Connaisson shall have determined that permitting such person to have access to restricted data vill not endanger the consoon defense and security.
k.
See information filed in response to Anti-Trust review inquiry of the Attorney General pursuant to 10 CFR 50 33a of the NRC Regulations.
(See Appendix L part 50 forwarded herewith as part of this applicat. ion)
B.
Information required by 10 CFR 70.22 of NRC Regulations:
Applicant hereby cdopts and incorporates by reference the information contained in this Application for construction permit and operating licenses for River Bend f.tation Units 1 and 2.
C. ' Information required by 10 CFR 30 32 of NRC Regulations and Form NRC 313:
Applicant hereby adopta and incorporates by reference the infomation contained in this Application ~ for constauction permit and operating licenses for River Bend Station Units 1 c.nd 2.
D.
Information required by 10 CFR h0.31 of NRC Regulations and Form NRC-2:
Applicant hereby adopts and incorporates by reference,the informat, ion contained in this Application for construction permit and operating licenses for River Bend Station Units 1 and 2.
E.
Consnunications :
All communications to Applicant pertaining to this Application shall be sent to:
13 Amendment 3 Dec.1975 i
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S. L. Adams Senior Vice President Gulf States Utilities Company P. O. Box 2951 Beaunent, Texas 7770h and J. E. Booker Licensing Gulf States Utilities Company 1
P. O. Box 2951 Beaumont, Texta 7770h and Stanley Plettaan Orgain, Bell & Tucker Beatanont Savings Building Beaumont, Texas 77701 and Troy B. Ccnner, Jr.
Conner & Knotts 17h7 Pennsylvania Avenue. N. W.
Washington, D. C. 200')6 GULF STATES UTILITIES COMPANY L
S. L. Adams s
Senior Vice President ik.
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UNITED STATES OF AMERICA NUCLNAR REGULATORY CO2(ISSION STATE OF TEKAS l
I COUNTt OF aurup0N l
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Docket Nos. 50-h58 In the Matter of i
50-h59 GULF STATES U1'ILITIES COMPANY l
(River Bend Statics, j
Units 1 and' 2)
AFFIDAVIT S. L. ADAle, being duly sworn, states that he is a Senior Vice President of Gulf States Utilities Company; that he is authorized on the part of said Cogany to sign and file with the Nuclear Regulatory Comunission the documents attached hereto; that he has read all of the statements contained in such documents attached thereto and made a part thereof; and that all such statements made and matters set forth therein are true' and correct to the but of his knowledge, information and belief.
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S. L. ADAMS Subscribed and sworn to before as, a Notary Public in and for the State and County above named, this N day ofl EM) 1975.
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..g LICENSE APPLICATION ANTI-TRUST REVIEW INPDRMATION APPENDIX L - 10CFR50 RIVEH BEND STATION UNITS 1 AND 2 O
DOCKEI' NOS.
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,D0,4 69 GULF STATES W ILITIES COMPANY Mi )
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9 1.
State separately for hydroelectric and thermal generating resources applicant's most recent peak load and dependable capacity for-the same time period. State applicant's dependable capacity at time of system peak.fer each of the next ten years for which information is available. Identify each new unit or resource. For hydroelectric generating capacity 3 indicate the nunber of kilowatt hours of use associated with each kilowatt of capacity during the ' adverse vat'er year' upon which dependable capacity is based. Indicate average.
ennual kilowatt hour loads per kilowatt, associated with each system peak shown (exc1'asive of interchange arrangements).
Response
A.
Peak Load The 1972 summer peak load was 3,602,700 KW.
- B.
Dependable Capacity at time of most recent peak load.
Owned hydroelectric capacity None Owned thermal capacity h,0h2,000 KW Purchased hydroelectric capacity v/o Reserves 98,000 KW
. Purchased thermal capacity v/o Reserves 106,000 KW Diversity interchange capacity with Reserves 215,000 KW C.
Dependable Capacity at time of system peak for each of the next ten years.'
Dependable Capacity in Kilowatts Purchased Purchased of Diversity Kydro Vith-CEPCo## With-Interchange Owned Ty;3?.s1 out Reserves out Reserves with Reserves
. Total Year 1973 h,56h,000 98,000 70,000 215,000 h,9h7,000 197h.5,1hh,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' 1978 7,150,000 98,000 215,000 7,h63,000
'1979' 7,690,000 98,000 215,000 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
- This is an estimate which may vary due to load growth changes, construction completion dates, fuel availability, license and permit contingencies.
- Tentative purchase from Cajun Electric Power Cooperative.
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D.
- New Units' Plant Name and Unit No.
., Capacity In Service Date Willow Glen No. k 522,000 KW Spring 1973 Sabine No k 580,000 KW September 1973 Convert Nelson No. h to Oil KW December 197h
- +.
Derate Willow Glen No. 3
-58,000 KW April 1975 Willow Glen No. 5 580,000 KW September 1975 Derate Nelson No. 2
-11,000 KW October 1975 9
Derate Willow Glen No. 2
-22,000 KV March 1976 Derate Nelson No. 3
-16,000 KW June 1976 Derate Willow 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 2dgerly Unit 1 5h0,000 KW September 1977 Edgerly Unit 2 5h0,000 KW April 1978 Edgerly Unit 3 Sho,000 KW September 1978 River Bend No.1 940,000 KW February 1980 Blue Hills No. 1 930,000 KW September 1980 River Bend No. 2 9h0,000 KW September 1981 Blue Hills No. 2 9.10,000 KW September 1962 ?
Undetermined 1,100,000 KW September 1983
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'This is an estimate which may vary due to load growth changes, con-struction completion datas, fuel availability, license and permit contingencies.
E.
Hydroelectric Capacity and Energy: Sam Rayburn Dam and Reservoir.
(Purchased)
Page 2 of 3
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52,000 KW Average Annual Energy (6 years) 56.h60,600 KWHR Mininnun Annual Energy 18,900,000 KWHR KWHR use/KW Cap = 36h
+
Hydroel,ectric Capacity and Energy: Toledo Bend Dam and Reservoir.
(Purchased)
Installed Capacity 92,000 KW (Total)
Installed Capacity h6,000 KW (OSU Share)
Average Annual Energy (3 yrs.)
102.12h,332 KWER (Total)
Average Annual Energy (3 yrs.)
51,062,166 KWHR (OSU Share)
Minimum Annual Energy 65,700,000 KWHR (Total)
Mininnan Annual Energy 32.850,000 KWHR (03U Share)
KWHR use/KW Cap =,715 F.
System Peak Loads and Average Annual Kilowatt Hour Loads per Kilowatt:
Estimated Estimated Year System Peak Load Average Annual KW KWHR /KW#
1973 3,852,000 0.68 197h h,238,000.
0.68 1975 h,661,000 0.68 1976 5,127,000 0.68 1977 5,6ho,ooo 0.68 1978 6,20h ooo 0.68 1979 6,82h,000 0.68 1980 7,506.000 0.68 1981 8,257,000 O.68 1982 9.083,000-0.68
- Calculated as.'ellows Estimated Annual KVHR used Total hours in year X Estimated annual peak e
Page 3 of 3
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2.
State applicant's estimated annual load growth for each of the next twenty years for the period applicant utilizes in system planning.
Indicate growth both in kilowatt requirementr and kilowatt hour re-quirements.
Besconset Year IN orowth KWHR orowth 1973
'350,000 2,08h,880.000 197h 385,000 2,293,368,000 1975 h2h,000 2,525,683,200 1976 466,000 2,783,kT3,920 1977 512,000 3,ok9,681,600 1978 56h.000 3,359,635,200 1979 620,000 3,693,216,000 1980 682,c00 k,073,667,8ko 1981 751,000 k,k73,556,800 1982 826,000 k,920,316,B00 1983 908,000 5, hob,77k,koo 1984 999.000 5,967,1k6,880 1985 1,099,000 6,5k6~,523,200 1
- Difference between estimated peaks of 1972 and 19'i3 and the KW growth for 1973 is due to CEPCo load. See question No. 8.A.1(d).
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3.
State estimated annual,i.oad growth in kilowatts and kilowatt hours of.
companies or pools apon which the economic justification of the subject unit is based for each of the next 20 years, or for the period Appli< "M utilizes in system planning. Identify each company or pool member.
Besponset No pool studies were made for economic justification. Studies were,made based on Gulf States' load and needs.
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For the year the subject' unit would first come on line, state estimated annual load growth in kilowatts and kilowatt hours of any coordinating group or pool of which 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.
Identity each company or pool member whose loads are indicated in the response thereto.
Responset A.
Southwest Power Pool estimated annual load growth:
Year KW Growth KWKR Growth 5
1980 h,519,000 Not Available 1981 h,890,000 Not Av=.ilable B.
Members of Southwest Power Pool:
Arhansas Electric Cooperative Corp.
8000 Interstate Drive Little Rock, Arkansas 72209 Arkansas-Missouri Power Company 405 West Park Street, Blytheville, Arkansas 72315 Arkansas Power & Light Company 9th and Louisiana, Little Eock, 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, Pineville, Louisiana 71360 Chanute Municipal Utilities Chanute, Kansas 66720 c
Coffeyville Municipal Water & Light Dept.
605 Sante Fe Street, Coffeyville, Kansas 67337 Empire District Electric Company E_
602 Joplin Street, Joplin, Missouri 6h801 Grand River Dam Authority Vinita, Otlahoma 7h301 Gulf States Utilities Co.
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P. O. Box 2951. - Beaumont, Texas 7770h Page 1 of 3 Y
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s Independace Pwer & Light Dept.
21500 E. Truman Rd., Independence, Missouri ph056 Kansas City Board of Public Utilities 1211 No. 8th St., Kansas City, Kansas 66101 Kansas City Power & Light Company 1330 Bratimore Ave., Kansas City, Missouri 6hlk1-Kansas Gas 'and Electric Company 201 N. Market Street, Wichita., Kansas 67201 Kansas Pwer & Light Company 818 Kansas Ave., Topeka, Kansas 66601 Louisiana Power & Light Company lh2 Delaronde Street New Orleans, Louisiana 7011b Mississippi Power & Light Company Electric Bldg., Jackson, Mississippi 39205 Missouri Edison Company 202 South 3rd Street, Louisiana, Missouri 63353 Missouri Power & Light Company 101 Madison St., Jefferson City, Missouri 65101 Missouri Public Service Company 10700 East 50 Highway, Kansas City Missouri 6k138 Missouri Utilities Company h00 Broadway, Cape Girardeau, Missouri 63701 New Orleans Public Service. Inc.
317 Baronne Street, New Orleans, La. 70160 Oklahoma Gas & Electric Company 321 N. Harvey Ave., Oklahma City, Oklahma 73102 Public Service Co. of Oklahoma 600 South Main St., Tulsa, Oklahma Southvestern Electric Power Company h28 Travis Street, Shreveport, La. 71102 Southwestern Pover Administration P. O. Drawer 1619. Tulse, Oklah ma 74101 Page 2 of 3
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Springfield City Utilities 301 E. Central Street, Springfield, Missouri 65801 St. Joseph Light & Power Ccanpany 520 Francis St., St. Joseph, Missouri 6h502 Western Farmers Electric Cooperative Andarko, Oklahoma T3005-Western Power Division, Central Telephone & Utilities Corp.
Broadway at Morton, Great Bend, Kansas 67530 Winfield Municipal Electric Light Dept.
P. O. Box 6k6, Winfield, Kansas 67156 e
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state applicant's minimum installed reserve criterion (as a percentage of load)* for the period when the subject unit will first cone on line.
If the applicant shares reserves with other systems, identify the other i
systems and provide miniaram installed reserve criterion (as a. percentage of load)# by contracting parties or pool for the period when the pro-i pose.d unit vill first come on line.
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' Indicate whether loads other than peak loads are considered.
i ResDonset I
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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.
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" 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 C
predicted annual peak load obligation by a margin E
of 15%, or as an altern'ative, a probability study made so as to insure that the probability of load j
exceeding capacity available to such Group shall not be greater than one occurrence in ten years provided that f n no case shall the reserve be less than 12% of the peak load obligation of the group.
"The method of calculating the probability, of load exceeding available capacity shall include considera-i' tion of uncertainty in prediction of load and shall l
employ the best available statistical data on genera-tor forced outage rates. The method vill also con-sider hour-Fy-hour characteristics of the load, availability of quick-start generation and effects l
of interconnections and agreements with neighboring campanies. 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 to any generating unit shall be that which has been L
demonstrated by actual test under the most adverse conditions that might exist duYing the loading period being considered".
NOTE: The above statement of Reserve Policy was included in the April 1971 Southwest Power Pool report of " Reliability and lequacy of Electric Power".
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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 snount of-installed rererves.
(e.g., (a) single largest unit down, (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 (d) judgement.
List contingencies other than risk of forced outage that enter into the determination. )
Bisconset
' Minima installed reserve criteria is bas'ed.on probability of loss of load of one day in 10 years., In no case vill reserves be less than 12%.
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Indicate whether applicant's system interconnections are credited explicitly or implicitly in establishing applicant's installed reserves.
Resnonset Gulf States Utilities Company does not consider the capacity of the interconnections as part of installed reserves. However, the system interconnection capacity does affect installed reserves in the follow-ing manner. The system interconnection capacity is verified by load flow studies. This capacity is used in making loss of load probability stud (es. The capacity from the interconnections is never greater than c,..-
that of the excess generating capacity of the adjacent companies.
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8.
List rights to reMite emergency power and obligations to deliver emergency power, rights or obligations to receive or deliver de-ficiency power or unit power, or other' coordinating arrangements, g
by reference to applicant's Federal Power Constission (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 copiess or where not reduced to writing describe arrange-ments.- Identify for er;.ch 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.
transmission facilities constitute a part.
- List separately and identify certificates of concurrence.
Responset A.
Rights to receive emergency power and obligations to deliver emergency power.
1.
Agreements:
(a.) Central Louisiana Electric Company and Louisiana Power and Light Conapany, 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., FPC Schedule No. 10k.
2.
Certificates of Concurrence:
(a.) Interconnection Agreement among Central Louisiana Electric Company, Gulf States Utilities Company, and Louisiana Power and Light Company.
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 s
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.8. - Continued Document Supplement No. 2 Supplement No. 1 to Supplement No. 2 Supplement No.* 2 to Supplement No. 2 Supplement No. 3 Supplement No. k Supplement No. 5 Supplement No. 6
+
Supplement No. 7 Supplement No. 8 Supplement No. 9 Supplement No. 10 Supplement No. 1 to Supplement No. 10 Supplement No. 2 to Supplement No.10 Supplement No. 3 to Supplement No.10 Supplement Fo. k to Supplement No. 10 Supplement No. 5 to Supplement No. 10 Supplement No. 6 to Supplement No.10,
Supplement No. 11 Supplement No. 12 Supplement No. 1 to Supplement No. 12 Supplement No. 13 Supplement No. lb Supplement No. 15 Supplement No. 1 to Supplement.No. 15 Supplement No. 2 to Supplement No. 15 Supplement No. 3 to Supplement No.15 Supplement No. k to Supplement No.15 Supplement No. 16 Supplement No. 1 to Supplement No. 16 Supplement tv, 17 Supplement No. 18 Supplement No. 19 Supplement No.1 to Supplement No.19 Supplement No. 20 Supplement No. 21 Supplement No. 22 Supplement No. 23 Supplement'No. 2h*
Supplement No. 25 Supplement No. 26 Supplement No. 27 Supplement No. 28 Supplement No. 29 Supplement No. 30 B.
Rights or obligations to laceive or deliv,er deficiency power or unit power.
Page 2 of 3
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None. Firm power is sold pursuant to various filed schedules.
See attachment to answer of question 15.
C.
Other Coordinating Arre.pments
. 1.
None.
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- 9.. List non-artiliated electric utility. systems with peak loads smaller than applicant's which serve either at wholesale or at retail sujacent 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 their generating c, ate if available their load, their annual load growth, such systems indic apacity, ttleir largest thermal generating unit size, and their minima reserve criteria.
Responset A.
Investor-owned Utilities:
l.
Central Lou'.siana Electric Company, Inc.
bl5 Main Street, Pineville, Louisiana 71360 System Peak Load 518,500 KW Generating Capacity 565,300 KW Largest Thermal Generator 117,000 KW 2.
Kirbyville Light & Power Company 7922 West'Glern, Houston, Texas 770h2 System Peak Load 2,30h KW Generatign Capacity 850 KW Largest Thermal Generator h50 KW 3.
Louisiana Power & Light Company lh2' Delarunde Street, New Orleans, Louisiana 70114 System Peak Load Not Available Generating Capacity 1,892,000 KW Largest Themal Generator 5k9,000 KW k.
Mississippi Power & Light Company Electric Bldg., Jackson, Mississippi 39205 System Pehk Load 1,3h3,000 KW Generating Capacity 2,007,300 KV Largest Themal 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 Thendal Generator 565,000 KW B.
Municipalities:
Page 1 of 7 i
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Bryan Municipal Electric System P. O. Box 1000, Bryan, Texas 77801 System Peak Lead 81,500 KW Generating Capacity 120,000 KW
, Largest Thermal Generator 50,000 KW 2..
Caldwell Municipal Light Dept.
214 V. Buck, Caldwell, Texas 77836 System Peak Load 2.558 KW Generating Capacity None Largest Thermal Generator None 3.
College Station Elsetric Dept.
P. O. Box 9960. College Station Texas 778h0 System Peak Load 15,5kk KW
=,.
Generating Capacity None Largest Thermal Generator None h.
Hearne Municipal Light Dept.
200-20 Cedar Street, Hearne, Texas 77859 System Peak Load 6,700 KW Generating Capacity 7,775 KW Largest Thernal Generator 2,500 m 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 & Pcnter Dept.
1829 Sam Houston Ave., Liberty, Texas 77575 System Peak Load 10,530 KW Generating Capacity k,k90 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 Thezzal Generator None Page 2 of 7
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Newton Municipal Utilities i
P. O. Box 86, Newton, Texas-75966 I
LSystem Peak Load 3,192 KW J
Generating Capacity None Q
4 Largest Tneraal-Generator None 9
Abbeville Municipal Water & Light Plant A
Box Tho, Abbeville, Louisiana 71510 J
System Peak Load' 12,228 KW Generating Capacity None Largest '2hemal Gencrator None 7,
I 10.
Erath Electric Dept'.
Erath, Louisiana 70533 3
System Peak Load a,176 KW 3
Generating Capacity None Largest Themal Generator None 1
11.-
Gueydan Municipal Light & Water Dept.
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' Gueyden, ^ 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 i
Largest Thermal Gerrarator None 13.
Lafayette Utilities System 733 Jefferson St., Lafayette, La. 70501 3
Systen Pesk Load 104,500 KW Generating Capacity 189.950 KW Largest Thermal Generator 90,000 KW lb.
New Roads Municipal Water & Light Plant New Roads, La. 70760 g
System Peak Load Not Available Generating Capacity Not t.vailable 1
Largest Therms]. Generator Not Available
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15 Opelousas Municipal Electria. Dept.
Opelousas, Louisiana 70570 System Peak Load 2k,500 KW Generating Capacity 50,690 KW Largest Themal Generator 26,000 KW
- 16. Plaquemine Li ht Dept.
E 209 Main, Plaquemine, %. 7076h System Peas Load Not Available Generating Capacity 8,800 KW Largest Thermal Generator Not Available 17 Rayne Municipal Utilities Rayne, Louisiana 70578 System Peak Load 3,918 KW Generating Capacity 7,020 KW Largest 'Ibemal Generator 1,75,0 KW 18.
St. Martinville Municipal Light Dept.
St. Martinville, La, 70582 Systen Peak Load 5,799 KW Generating Capacity Not Available Largest Thermal Generator Not Available 19 Vinton Electric Light Dept.
1200 Horridge St., Vinton, La. 70668 System Peak Load 3,h56 KW Generating Capacity None La: gest Thermal Generator None 20.
Welsh Municipal Light Dept.
Welsh, Louisiana 70591 System Peak Load h,032 KW Generating Capacity None Largest Thermal Generator None C.
Rural Electric Cooperative Systems Page h of 7 M
m
'at a b
mmmy
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- p
'[~
- 9. - Continued ~
s.
1.
Brazos Electric Power Cooperative, Inc.
P. O. Box 6296,- Waco, Texas 76706 System Peak Load 183,k00 KW Generating, Capacity 155,000 KW Largest Therinal Generator
- 66,000 KW 9
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-Bewton Electric Cooperative, Inc, 812 S. Margaret, Kirbyv111e, Texas 75956 System Peak Load 22,h73 KW Generating Capacity None Largest Thermal Generator None 4.
Mid-South Electric Cooperative Association i
Highway 6 & Stoneham, Navasota. Texas 77868 k[
System Peak Load Not Available Generating Capacity-None Largest Thermal Generator None 5
Robertson Electric Cooperative, Inc.
P. O. Box E, Franklin, Texas 77856 4
L'
-System Peak Load 5,141 G Generating Capacity None Largest Thermal Generator None lj 6.
Sam Houston Electric Cooperative, Inc.
P. O. Box 1121, Livingston, Texas 77351 System Peak Load 35,69h KW Generating Capacity None
- ..'\\
Largest Thermal Generator None 7
Sam Rayburn Dam Electric Cooperative, Inc.
P. O. Box h30, Kirbyv111e, Texas System Peak Load Not Available Generating Capacity None Largest Thermal Generator None
- 3
^
Page 5 of T 3
1
( h.,,.
i
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8.
Houston County Electric Cooperative Association Crockett, Texas 75835 System Peak Load Not Available Generating Capacity Hone Larcest Thermal-Generator None 9
Dixie Electric Membership Corp.
P. O. Box 15659, Baton Rou6e, Louisiana 70815
\\
System Peak Load 55,548 KW Generating Capacity None Largest Thermal Generator None 10.
Jefferson Davis Electric Cooperativo, Inc.
P. 0. Box 1229, Jennings, Louisiana-705h6
' System Peak Load 18.581 W Generating Capacity.
None i
Largest Thermal. Generator None 11.
Beauregard Electric Cooperative, Inc.
Lake Charles Highway, Deridder, Louisiana 7063h System Peak Load-23,367 W~
Generating Capacity None i
. Largest Thermal Generator-None y
12.
Pointe Coupee Electric Membership Corp.
New Roads, Louisiana 70760 i
System Peak Load h,800 KW-Generating Capacity.
None Largest Themal Generator None 13 Southwest Louisiants Electric Membership Corp.
271 N. University Ave., Lafayette, Louisiana 70501 System. Peak Load 115,17h KW Generating Capacity None Largest Thermal Generator None 1h.
Cajun Elec. Power Cooperative, Inc., as_ power supply agent for_ cooperatives listed above as nos. 9-12.
System Peak Load Not Available l
Generating Capacity 220,000 KW Largest Thermal Generator 110,000 KW Page 6 of 7 menwetwnenwenmerammwawareavmmtunwon.wieanvaaeme ero1 ewer; wet ~:m ___.
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- NOTES
- - (1)' System peak loads', generating capacities, and largest'--
1 bg
.thezinal generator sizes shown above are tabulated as
- -X of January 1 - 1971, from Electrical World Directory of s
~
n-m iv
. Electric Utilities, McGraw-Hill Inc., New York, N..Y.,
j f
~ 80th Edition,1971..
' f.i
. 'l (2). Annual. load growth and minimum reserve criteria for systems listed above-are not available from records of applicant.
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- 10. -List separately those systems in Item 9 which purchase from Ap;ilcant (a) all bulk power supply and. (b) systems which. purchase partial bulk power supply requirements. Where information is available to Appli-cant, identify those Item 9 systems purchasing part. or all of their
. bulk power supply requirements from suppliers other than Applicant.
Response
s
.. Systems which purchase all bulk power supply from Applicant:
A.
-(1):-Investor Owned Utilities:
Kirbyville Light- & Power Company (2) Municipalities:
Caldwell Municipal Light Dept.=
- Newton Municipal Utilities
. Gueydan Municipal Light &. Water Dept.
Kaplan Municipal Water 6. 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 Systems:
- Jefferson Davis Electric Cooperative, Inc.
B.
Systems which purchase partial bulk power supply from Applicant:
(1) Invo: n Owned Utilities:
None i
(2) Municipalities:
Rayne Municipal Utilities
- Jasper Electric System
- Jefferson Davis Electric Cooperative, Inc. is a member of Cajun Elec.
Power Cooperative, Inc. All purchases by these Coop. 's are made by and through Cajun Electric Power Cooperative, Inc.
- Members of Sam Rayburn Dam Electric Cooperative, Inc.
Page 1 of C Y
- Mtff,M MWA/. MG GT A XMAt WR_fRWMT9 B*bi.?Ot# 1**.MRCfa**ffv?M4W'_i"f%54* e 6? 1*LF o*~^W'/Cff s o.4.s*f T3elt%* J**m*9' t11nNN _. _
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. 10.:- Continued'
- 0..
Yl (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.
t*
- Jasper Newton Electric Cooperative, Inc.
d-
- Dixie Electric Membership Corp.
Southwest Louisiana Electric Membership Corp.
- Pointe Coupee Electric Membership Corp.
- Beauregard Electric Cooperative, Inc.-
C..
Systems which purchase all or part of their bulk power supply from suppliers other than Applicant:
(1) Investor Owned 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.
Southwest Louisiana Electric Membership Corp.
- Dixie Electric Membership Corp.
' Pointe Coupee Electric Membership Corp.
- Beauregard Electric Cooperative, Inc.
- These are members of Cajen Elec. - Power Cooperative, Inc. All purchases F
by these Coop.'s are made and through Cajun Elec. Power Cooperative, Inc.
h4
- Members of Sam Rayburn Dam Electric Cooperative, Inc.
1 eseMembers of Brazos Electric Porst C(Prative, Inc.'
Pate 2 of 2 y
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lli. State as to all power generated and sold by applicant the mon + --cent average cost of bulk power supply experienced by applicant,2) r.t site o( generating facilities, (b) at the delivery points from the primary trandinission (backbone) system, (c) at delivery points from the secor.-
dary transmission system,.and (d) at delivery points from the dis-tribution system, in terms of dollars per kilowatt per-year, in zills
- per kilowatt-hour, and in both the kilowatt costs and kilowatt hour costs divided by the kilowatt hours.,If wholesale sales are made at varying voltages, indicate' average cost' at each voltage.
Responset
.g.
The following information 10 furnished in response to question no.'11
. from cost of service data prepared in con, junction with a current filing before the FPC covering sales by Gulf States Utilities Company at whole-
- sale. The highest voltage listed is 138 KV which is pres'ently a part.
of the primary transmission' (backbone). system. We would combine 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-ting 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 generating facilities. The 69 KV voltage level figures vould answer (c) above and 13.8 KV voltage level would answer (d) above.
ESTIMATED COST OF BULK POWER - YEAR ENDING MAY 31. 1972 Total Cost Cost in Mills per Kwhr
$/Kw year Total-Demand Energy 1.
at 138 KV 36.02 8.9h
,6.70 2.2h 2..-
at 69 Kv
.h1.83 10.38 8.11 2.27 3
at 13.8 Kv h5.h5 11.28 8.90 2.38 Note: Sales are at h6% load factor based on non-coincident peak loads.
B B
I C
u *.ev. m te a mr rw:r r* + - ww.s 4. r,
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_= -. - mum wn..u...;.w u.u m.v. m,a w.w.. un., a..m.1.
- w.. m. x a,
.. 4 A:
j
- l'2. - State _ (a) for generating facilities and (b) for transmission rub >
divided by voltage classes, the most recent estimated cost of applicant?s bulk power supply expansion program of which the sub-y",
ject 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 se;srately
-- the most recently ~ estimated cost of the subject units.
Response
~.
_ Gulf States Utilities Company's " bulk power supply expansion program.
of yhich the subject units are a part" is complete' 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 in
- Tvice dates of fossil fired generating units between 1973 and' l'981 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 chort of present-estimates. We have= not made detailed cost estimates relative to our transmission system for the time span here under consideration. Any sale of bulk power would include transmis'sion_ costs since both _ types
' of facilities are required to supply any bulk power.
The following tentative cost data is computed on the basis of a 60%
~
- capacity factor. The cost data is based upon only gas and oil-fired units beinE 3rstalled 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 Demand Costs Energy Costs
$/Kw/ Year
. Mills /Kwbr Mills /Kwbr Mills /Kvhr (a) Oeneration 75.67 1h.40 10.75 3.65 (b) Transmission (See above discussion)
Estimated Installed Costs Unit Cost
- Expected Rating Cost per Kw River Bend unit #1
$379,927,000 9ho,000 Kw
$kok
. River' Bend unit #2
$3h7,h17,000 9h0.000 Kw'
$370
- Includes transformers, but excludes switchyrd, transmission lines and fuel.
9 D'
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- 13. List and describe all requests for, or-indications of interest in,
?
interconnection and/or coordination and pechases or sales of co-ordinating power _ and energy from adiacent utilities' listed in Item 9 since 19t'0 and state applicant's. response thereto.. List -and 4
describe all requests for, or. indications of interest in, supply of:
b
' full or partial requirements of bulk power for the same period and
' state applicant's response thereto.
4 Responset'
'A.
Inquiries for interconnections to accommodhte the sale of coordinating power or foir full or partial requirements.
- of bulk power have,resulted in negotiations and signed i
contracts which are now in force with all of the adjacent utilities listed in Item 10.A and B.
u
[
B.
Inquiries which have not resulted in signed agreements and the applicant's responses thereto are as follows:
1.
- City of Hearne. Texas. Hearne was experiencing difficulties with their electrical plant in 196h and made an inquiry to the applicant. Applicant made a proposal to serve Hearne with bulk power under the provision of Rate Schedules h23 and h23A.
Hearne elected not to buy the power.
h 2.
City of Lafayette. Louisiana. A verbal' request for 200 W of interconnecting power was made by the city of Lafayette on August 2, 1972. Negotiations are still undervsy.
3 City of Plaouemine. Louisiana. A verbal request was y
made on August 2,1972 for applicant to supply 20 W of interconnecting power to Plaquemine. Negotiations
- are in abeyance'pending completion of negotiations -
with city of Lafayette.
O h.
4 a a A
6.
M
.. max:sn.w.m.,am=w;wmu.yser, ww. m V'
ik. List (a) agreements-to which ~ applicant is a party (reproducing relevant
' paragraphs) andL (b) state laws (supply citations only), which restrict lor preclude. coordination by, with, between, or among any electricz x
- 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 i
a federal agency, identify each in the same' fom as in previous responses.
Where the contract has not been filed with a federal agenef, a copy ~
should be supplied unless it has been supplied pursuant to another ite,m'-
hereto. Where it 'is not in writing, it should be described.
- Respons'e :
With the possible exception noted below, applicant does not believe that any agreements to which it is a party restrict or preclude (i) 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-f.
No.198. Sam Dam contracted with four member municipalitien,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 Dcm 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 would be temporary and at the vill-of the members.
(excerpts attached)
Statutes which may affect substitution of service are LME 45:123; Tex.
Rev. Civ. Stat. Articles lk36a and 1175(12).
s l
_m_
' ;g _
e q ig, ' Attachment f: _
ARTICLE 'HI,
' SALE OF POWER AND ENERGY BY THE COMPANY TO SAM DAM CO-OP t
_ POR DELIVERY TO CERTAIN SPECIFIED MEMBER M:!NICIPALS Section 1. ? Electric Service by the Company. Gulf States 'shall sell
' to the Sam.Dem Co-op, end deliver for +be account of San Dam Co-op, and th'e Sam Dan Co-op'shall purchase and cause to be received, the amounts of electric pwer capacity and the accompanying energy necessary to fulfill the electric service requirements of the Member Munic,ir;ds listed below in
- {
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:
l (i). City of Jasper, Texas (ii) City of Liberty, Texas (iii)- City of' Livingston, Texas (iv) Town of Vinton, Louisiana l
s i
t ARTICLE IV i
SALE Ol' POWi"4 AND ENERGY BY GULF ' STATES TO THE. SAM DAM CO-OP
- POR DELIVF".v 7J.,TAIli SPECIFIED RURAL ELECTRIC DISTRIBUTION COOPERATIVES Section 1.
Mectric Service by Gulf States.
(a) Gulf States shall sell to the San Dam Co-op, and deliver for the account of the Sam Dam Co-op, 1
and the San Dam Co-op shall purchase and cause to be received, the amounts of electric power capacity and the accompanying ene'rgy necessary to fulfill the electric service requirements of the Member Cocteratives listed below which desire to purchase such wervice, at the points of. delivery detailed I
on Exhibit "4",
a copy of which is attached hereto and by this reference made'a part hereof.
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- 15. ' State, at point of' delivery, average future cost of power purchased from applicant to adjacent systems identified in argt scant's response
.to Item 9 in tems of dollars / month /kv for capacity. mill / kwhr for energy and udlls/ kwhr for both power and energy at purchaser's present load factor (a) at present load, (b) at 505'i.ieresse over present load,- (c) ~ at 100%. increase over present load, and (d) ' at 200% increase y4 over present load.
(All costs should be determine'd under present rate schedules.) - Where sales are made itnder contract or rate : schedules on 3-file with r. 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-agency, a copy should be
~
- suppl.ied..
. Response Gulf States Utilities Company's sales of electric energy to systams identified in applicant's response to Item 9 are reported to the Federal h
Power. commission annually in Fom No. l.. Such reporting details by.-
b points of delivery, the delivered voltage, Kw demand, Kwhr sales, revenue from demand, energy and other charges, and the unit rate. A copy of the applicable data for the year 1972 is attached. 7f addttional power is furnished under present rate schedules and assuming the customer'a' load' factor is' constant, the unit rate for energy in mills / kwhr would be cohstant. The dollar / month /Kv vould also remain constant. Only tht:
total bill would increase in proportion to the. increased requirements.
Future costs vill'be ' determined by such rate schedules as changed from time to time under applicable regulatory procedures.
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martyrulett.arr.co. ea :)
81 zirtyvine, Tex.
jos 1,e12 2,52 3010s. 1st.
4,160 9.370.560 26.006 61,626 (7.686) 79.9hb J e
0
. na._s oeter d cas.
s 1
8
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city of cald n rr(:
99 Caldwell. Tex.
Bs 2,933 4,158 13,200 15.996.400 60,718 101,378 5,625 136,b71
.85 s
a-8 abanicipalities e
City of newton rr( :
85 m.vton, Ten.
Bs 2,886 3,780 13,200 12,.3,600 43,121 8e,882 1,608 124,395
.96
- s
- City cf Livingston*
FP 86 Livtagston, Tex.
BS.
5,327 7,209 4,160 27, 800 105,141 81,610 1M,751
.M r
~ \\
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13,200 h6,492,700 177,097 135,705
,802 67 e
f
- City of Liberty
- FP 96 Liberty. Tex.
RSI 9,142 11,86b
' City of Jasper
- FP( O 95 Jasper, Tex.
8t3 10,941 13,020 13,200 60,095,200 219,750 1k,370
.67 e
- 1 2%
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=
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To.m of Welsh Q
51 welsh, La.
R$
3, t33 4,790 2, BOO 17,629,000 50,bok
.111,17% it),3bby 9,351 89 u
t
?
67,3 2,925 10.320,000 27.956 u8,7 20 b,m2?
2>.. m.=
t se 1,b) 3,OF2 2,400 28,8,0,000 77,m
- )
49 Gueydma, La.
.RS 5,558 8,8m 0
g
.To.as of Deeyden 2,
3b,500 61,9hh,000 173,521 377,06b (30,99bl
' 519,5W
'8
,e s
of in,1-Fe( y 56 1., ta.
a
= *
- 2, BOO 9,020,000 27,602 59.525 87,127
.9T w
To m of Abbeville PF( U 91 Abbeville, La.
Rs 10.873 15,350 7j ttime of Breth FP 20 treth, La.
R$
1,813 2,68R p
2,400 23,86b,460 67,WT
- 148,587 (900) 215.07%
.90
,o es Toua d St. Itar*4eville FP( :)
30 St. Beartiaville. La. RS 4,441 6,606
" ttius of Vinton*
FF 24 T1 stoa La.
RS 2,824 4,128 2,400 14,76%,800 56,6b5 b3,368 100,013 68 m
3b,500 53b,000 865 4,005 213 5,064
.95 d
. = =
Toun of new moede 0
101 - Roses, La.
Cs 190 960
Taun of Reyne FF( F)
-6
<ae e, La.
35 1,3bb 2,730 13,200 3.624.600 P4 1.08
~
- M 333,39g,3eo 7,
{%5) 7 3
w se p
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Satytotal
~
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f
'1,178,400
- 4,283 2.972
-7.255 2
6 l
R.E.A. Cooperatives
- 198,281,650 742,256 488,558 1,218 1,229,596 6e se j
napaust sans am:. Co.
Fr(
-s Cs #
- = =
%,708,800 20,50T 9,884 1,520 28,9T1
.61 se j
sem mustom al. Coop.* rt(
69 #
A Robertaos D ec. coop. PP(p) 87 8 8
g 105,808,950 382,710 265 8T3 (11,758) 636,825.60 m
- Jesper-Bewtos noe.
56 08r 147,86e.64 m
Coop.*
71 #
8 23,124,150
- 77ai, 88, (103?
231,830.62 w
= *
- i nonston Co.31. Coop.
79 #
10e,ni,414
- 324, 285, (7,8 91) 603,039.59 m
37,130,550 1
=
[
nie south Elec.cnop. PF(P 76 #
255,564,000 922.c">5
' 648,775 25,755J 1,545,115 60 Jeff-Davis D.c4 f PP 70 #
g 445,376,661 LJhar18 1,10r,619 57,259J 2,603,578 60
's 74 #
g p)
oisie n.sesab. carp.p
- 31,769,850 119,156 Tr 9 6,200 203,355 6b 6
72 #
ecathuestIa.
=
36.237.600 1
86 233 MA 6k se s<
ll Itestchuyse E1. stme6
?
75 #
{
gueurusarit E1. Coop.p P?
72 #'
1.2tl.242.q25 3.116.b51
)
7.500.d 2
.{
a 8'
2 Sabtotal 1.584.ML9b5 5641.58s*
4.776.566[159.6 4 )
10.258.420 g
=m f
(
est %13C.
[
- See detail on pages d2A 4129, b12C, b13A, b1A f3) on page 412C.
t' See Notee (1), ( ?),
and 4
- Became members ar Saa Bephesr Das Electric Coopenat2ve on Juty 1, 1566.
" h 8'
p Became enebers or Lcatsimma Electric Cooperative, W. on Daeember J 1970.
s
= 1
[ No FFC rate schehtle muslier has been ftarnished tc
.".te.
I t
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69 sparser Texas 1,705 2,w 33,,,a gu, 3,109 1,632 b,141 k
e E8"stre #1, semas 1,#3 1,12%
7,620 1,581,30G 5,898 3,896
-.794
.62 8
13,200 2,260,300 10,325 b,ho8
_ 1,733
.45 s
e Mountee #2, Temas 317 424 a
=
=
Winister, Texas 555 693 13,200 7.321,650 27,3b) 18,019 b5,36e e
5 Dnacette, Temas its 1,47o 1,859 13 8,120,000 30,o11 20,176 Jo,19T
.68 3
s a
=
e 100,924
.62 e
Fork creek, Texas as 1,61%
2,394 13,200 16,371,600 59,827 bl.097 a
=
mammyer, Tomma 3,217 b,536 13,200 18,63b, coo 68,550 is6,497 n 5,047
.48 i
=
4' 13,200 39,950,400 169,404 98,194 24T,598 R
y 9'$
Touteist= arairk T==- 88
,686 13,2o0 1,569,750 5,4 33 4,126 9,55p
.61 n
Livisestam, Tomas as
,o33 a
13,200 10,2n 60o n,co7 21,533 65,5bo
.A
=
Cold sprimes, Tesas 292 El cor rich, Teams 35 2,366 3,192 13,200
- 30,587,200 in,G.
- 77,2Po 18.280 M
M y
a 88 67,3Fr Snesvil sub., Temes as 5,9T1 8,06b 13,200 10,480,b00 45,M 21,892-45,6o6 A
g
'8 Caritsle. Temas 2,447 3,9o6 13,200 7,657,800 26,302 19,304 nesteville, Texas 1, bib 2,016 13,200 5,99,800 22,4h0 15,480 (1,218) 36,7tw
.62 3
'8 Nomey Islesse, Texas 1,
1.1#
13,200
% 94L ooo 35g7 25,762 60,819
.6&
'r Batsam, Texas 1,
2,W 7,620 1,681,400 6,662 3,90b 10,566.63 i
=
7,62o 93,800 357 227 58b.6e sour IAbe, TeESS 35O I0f
=
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=
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189 224 2,28,6,80. 5.62 24,831 a
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teameram,samme, mas et 1,339 1,512 7,62o
. 3,673,950 11,996 10,099 22,095.40 8'
t shepherd, Teses r
1;9T1 2,604 13,200
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1s assnytisp maamen,1k-15 15 13,200 5.600 7 -TI Elif 1.2evase 8'
=
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=
3b,5co 4.To8.8ao 20.5er 9.884 (na2o) 20sta JL.s' u tocei non.rt.on rise. coq, or moramas=e, Te=e=
C8 2,o23 1,548 13,200 13,283,200 69,416 32,771 82.247 M Jesper.sewtaas1.o in 71 ns==rvine. Texas.
m 2.660 3,36o 13,200 13,722,800 47,328 36,116 83,504.61
=
girtywine, tenes M
2,545 2.982 69,000 9,b60,500 32,3pb 25,o83 (2,974)
Sb,603.38
=
=
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se=toib a. 8i, Tom.
ci 1,742 2,258 69,000 20,73b,35o 15,975 50,o13 2,155 127,743.4e
=
L Jesper Ttzes N
b,n2 5,16 6 69,000 35,796,000 131,13e 89,66 (n,039) 209,752.59 amma. Tesee C
7.050 9,12 13,200 12.812.100 46 32.16s 18.934 R
svedale. Texas a
2,517 3,23b lo5.aos.gp 205.573 DM 6us.ur 3 "8'
k 5
=
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sottotal 13,200 3,953,600 17, 8.305 25,395 8'
nousteiomenty n. asp.
70 Trinity. Texas
(.3,p 858 1,407 13,200 6,916,000 24, 17,968 42,251 A s,
ormeton, Twzes (3p 1,306 1,164 13,200 2,795,100 21,805 1,6 35 23,bbe.84 8'
3 a
26 0 26.179 16.7T 1,011 1,670 13,200 slidumF, TeEas I
rersesan pers, Ten, ch 1,645 1,890 se.ouf Iw.au
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Dabbia, Texas as f
' 90e 1,218 13,200 b,758,600 16,18e 12,316 29,100
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Mid-south Elec. Coop.
76 Conroe, Texas M
(3) 2,426 3,40e 13,200 5,516,000 23,958 n,517 35,b75
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as J
1,262 1,869 nuntsvine fe, ten.
L 1,189 1,596 13,200 5,908,500 22 nB 14,509 36,97
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8 movesota, Texas as
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914 1,197 r
Midump, Texas (9
94 126 7.620 bb8,000 1,749 1,056 2,805
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borth Zulch, Texas as (3) 451 630 13,200 2,b21,300 8,3DT 6,361 14,148
.6a nuatsvine #3, Tom.
876 903 13,200 1.e 5.6co 8b 2
10 10.837 * '.67 y.
yy 2 Lum 3 setotal
Jerr-Davis mee.cm 70 naetherry, touteiana es 2,664 3,960 69,000 16,481,184 68,37b 68,637 (1,479) 95.53e
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1,236 1,fb6 13,200 6,7'2.100 n 112 17,151 j
(776 37,3sb
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Cs 1,260 1,800 3b,5co 6,05b, coo ab,086 13,994 69,00 5,166,oco 18,723 13,o63 L581;
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t 13,20.0 2,031,330 7,187 5,Mb 383 12,8ab
.6) d Lake Arthur, La.
Cs 975 1,440 titco, imisiana as 377 694 chloe,Immistana 9,950 13.560 69,000 63,204,000 190.8b5
' 183 (7,r70) 366,8eb
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loma, Imissema 6of 840 13,200 2.452.800 11 661 S
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Egm, Imisiana as 721 1,050 13,200
~ 3,733,800 Ig h5 9,b95 22,360
.e 359 n,2E1 19,380
.97 "
merusates, Louisiana 494 13,200 3, % o,850 3
3, Iota, Louistama 1,
1,%9 13,200 5,269,600 19,223
.13,2b9 32,472
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omeyees, Louist m a 1,530 2,1%
13,200 7,590,800 28,514 18,J80 47,oph
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3 608 26,03e
.e Norse, Imtsiana 8bo 1,05o 13,200 4,207.150 15,6eb 10,873 16,ose
~.63 "*
G Neams, Emistana es 5b6 683 13,200 2,5b7,300 10,199 5
E. Abbevule,14.
cs 2,21 3,087 13,200 10,8b8,6co 41,160 26,3ob 67,46b
.6e 4
FP184 88"uu18. Ia.
1, 2,520 13,200 9,250,500 35,121 22,41L l 57,535
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is Esplan, Louisiana 2,056 2M 13,200 9,525,600 38,23b 21,813 60,cb7
.63 9
=
Dubon Suh..thplan, La 7,14 9,180 69,000 39,672,000 132,804 1er,cb6 (n,993?
227,857
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.99 (6{3a8p LeBlane SA, Erath, La b,190 5,040 69,000 20,292.000 77.934 68,621 316J 23,2e8
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.63 8
Billeense Louisieme as 2.405 1,785 Lafayette,Ia.$tamet.) as 7,196 9,408 IW 6Am ' 26,138 15,00e 788 kt,9e8
.63 I* sert-et..Tohm,La.
4,715 5,880 13,200 M,68n,800 133,866 77,99?
(605) 2n.2J3
.63 13,200 26,91o,000 87,699 7b,072 (8,o89) 153,65e
.57 e
am mevine,14.
1, 2,205 Cecelia. Imaistama 4,1%
b,914 13,200 8,775,900 33.7%
21p 54,748
.62 8I0 " mo"*d, La.
2,578 3,245 1,3,200 19,61b,000 76,883 b6,%5 122,9a8
.63 8 8 0 1a.
I Ridge e 13,12o 18,000
,3,200 12,310.200 47,951 29,08b 77,03*
.63 8
b o9,00o n,8a, coo 2 %,032 158,3h6 (20,u9) 92.259
.59 tandry name, k 1,W 2,352 13,200
-7,501,200 30,076 17,197 47,273
.63 as Airport,Immisiana 5,621 7,39e 13,200 26,o16,760 1 %,551 59,500 166,051
.63
=
uneth ceremero,la.
I',577 1,890 13,200 7.515,900 29,)27 17,726 47,053
.63
=
caramero,toutoiana 5,098 6,300 13,200 25,oeb.3ao-94,518 60,751 1'5,569
.6e w
8", L*'him 2,819 3,465 13,200 13,932,650 52,ul M,o38 86,b79
.62 Breneh,Immisians.
30 1,7%
2, o
13,20 1o,159,800 32,615 28,269 60,8s4
.60 w
O'urch Point, La.
M 2,429 2,
hbtotal 13,200 12.363.196 4 181 31.035 76.216
.62 es 445.376,64E
,1.107.619 Mf"S) 2.693.575~"E w
=
ftriate coupee E1. som si.
- ory, 75 stareassa, Loutstans as 2,10e 4,200 13,200 14,128,8oo 52,698
$,813 2.77b
,90,285
.A Livonia, Louisiana 2,030 2,940 13,200 10,476,900 37,953 26,50b 2,051 66,5c8
.63 m
or**** 1***, La.
be5 588 Bayou Flace==* =, la.
1%
13,200 2,097, 7,899 5,124
- 9 13,b72
=
13,200
- 639, 3,oe9 1,22b 131 b,$
.69 s,
Brwierille, La.
Ed 921 1,
fJbtotal 13,200 h.426.800 1
10.2%
28.706,,,,,gg as 31.769.550 77.919 2pLIB
.En s,
SP Doetregard Elec. CoeF.
73 NA.r, Louisiana RS 1,743 2,80%
13,20o
),3b9,20o
%,514 23,255 1,830 59,599
.6%
se sense Bierf, La.
2,867 b,158 13,200 12.650.400 50.599 29.077 2
,6TT
.6b p
13,200 14,238,000
%,718 3b,o4b 2,865 teostlake, Immistaan 2.660 3 h86 228
.65 m
8'IPtotal u
36.237.600 139.531-56.426 23L5at
.64 m
w
" (1) Infhrmation mot areLlabLe.
See previous e.
_.5are IT.I.
s.
- wita the se Ce estem in rigeri te reparting data for F.P.C u (2) Repressets valtice adjastumsta,ftsel elemme.ap
-te and 88
' allouemees flor.taperity maist.i d by easte er ier stammy purposee.
86
,(3) Bo Jostract ennled myeeLfieI flor individual poisto >f servtre but contreet with euch roogtratLve specifies limit toaacust te capnettr intich campany 1 i reguired t> ftarnish.
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b 16,. _ State whether applicant has p,repared, caused to.be prepared, or received engineering studies for generation and transmission expan--
'sion programs which include 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
.following:
'?
A.
' Central Louisiana Electric Company, Inc.
.B.-
Louisiana Power and Light Company C.-
Dixie Eleetric Membership Corporation D.
. Jefferson Davis Electric Cooperative, Inc.
E.
Beauregard Eler/aric Coe wrstive, Inc.
F., Southwest Louisiana Electric Membership Corporation G.
Cajun Electric Power Cooperstive, Inc.
H.
- Lafayette Utilities System 4
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17., List adjacent systems. to which applicant has offered to sponsor or
_ to conduct syst'em surveys in contemplation of an offer by. applicant to purchase, merge or consolidate with said adjacent system, subse-quent to January 1,1960.
Response
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.
6 19 5 Hearne, Texas - GSU made study of the electric system of 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 3
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..
1972 L Opelousas, Louisiana - Study of city's facilities made with respect to GSU's making a bid as requested by the city.
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- 18. List applicant's offers or proposals to purchase, merge or consolidate
! with eltatv% stilities. subsequent to January 1.1960.
' Responset.
V
- 1960-1962 Liberty, Texas - Offer made by OSU to purchase the electric
. system of the City of Liberty.. Offer rejected. Instead, city bought GSU facilities.
- 1965 Hearne Texas - GSU made offer to the city for the purchase of its electric system. Negative _ vote-2/5/67 by citizens.
1972 Opelcusas, Louisiana - GSU made a bid, ca requested by the -
city to purchase electric system belonging to the city.
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- 19. List all' acquisitions of or mergers or consolidations with electric utilities by_ applicant, subsequent to January 1,1960, incluiing:
(a) The name and principal place of business of the system prior to the acquisition, merger or consolidation; W
(b). The 'date the acquisition, merger or consolidation was consummated; F
(c) Gross annual revenue and most recent pe'ak load, dependable capacity and the largest themal generating unit of the system, prior to the dates-of consummation.
Response
There have been none.
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State applicant's; six (or fever if there are not six) lowest industrial or large commercial rates for firm electric power supply in tems, of cost for.. power and energy in mills per kilowatt hour (and separately, the damand and energy ecmponents) 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) promotional services such as electric space heating, electric hot water heating, and,the like, 'in terms of mills per kilowatt hour for power and energy and indicate the portion of the rate of rate blocks attributed to bulk power supply.
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 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 schedules 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.
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- 20. - Attachment Excerpts from pages klkC and 41kD of FPC Form FO. 1 - Annual Report of Gulf States Utilities Company. to the Federal Power Co:nmieston 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 hh2 Industrial Sales (Cont'd) 1,615,026.6h FC Facilities Charge hh5-L Irrigation
)
Pumping Serv.
h3,746, 1.473 91 6
7,291 3.3T -
i SHL Street & Highway 5
Lighting Serv.
153,764 15,222.16 h(e) 9 90 DDL Dusk to Dawn
'25h,h08 12,777 5h 11(e) 5.02 Lighting Serv.
FLS Flood Lighting Service 7,360 310.09 k.21 40'i-L Large Pipe Line Service 171,540,000 1,h61,805 9h 3
37,180,000
.85-1 GS General Service k
(and riders) 32,853,269 816,971 79 2,338 14,052
-2.h9 1
LGS Large General
..i Ser. (and
^
riders) k28,2h5,765_
5,392,277.k7 202 2,120,029 1.26 Total Industrial 6,111,436,737 h3,350,867 09 2,741 2,229,638 71 (e)
Excludes duplicate customers served under other rates Also
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'20. - Attachment 2-i 4
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j i
Excerpts from pages hlh and k1kA of FPC Form No.1 - Annual Report of Gulf States
-i 3
Utilities Company to the Federal Power Commission for the year ending December ~
31, 1972.
5 j.
Avera6e Kwh of Revenue s
Number and Title of Rate Number of
' Sales per -
lper.
[
Kwh Sold 5
Revenue-Customers Customer i
Schedule Kwh Sold i
1 Texas
.4 i
.}
i hh2 Commercial Sales SHL Street & Highway j
j Lighting Serv.
1,004,762 39,829.99 19h(e) 3.96
{.
DDL Dusk to Dawn
-t Lighting Serv.
3,827.575 191,003.11 224(e) k.99
(
T FLS Flood Lighting 3.66
[
4 Serv.
57,645 2,110.90
-- }
)
10-1 ' Conunercial Serv.
Metered 9h6 72.38 1
9h6 7.65 i
305-T General Power
{
{
Service 10 58.22 1
10 5.82 x
l LPS Large Power Ser.
35,532,105 326,814.37 1
35,532,105 92
{
't FC Facilities Charge 11,848.08 f
GS General Service (and riders) h74,310,911 13,h35,656.02 18,912 25,080 2.83
[
LGS Large Gen. Ser-7 i
vice (and riders) h72,577,156 6,88h,32h.79 h84 976,399 1.h6 j
Total Commercial 987,311,110 20,891,717.86 19,817 49,821 2.12 g
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' 20. - Attachnent -
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' Excerpts from pages hlh' and~ k1hA of FPC Form No. l'- Annual Report of Gulf States '
_'3 Utilities Company to the Federal Power Commission for the year ending December 1
3 31', 1972.
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Average Kwb of Revenue
{
j Number and Title of Rate Number of Sales per_
per.
l 3
Schedule Kvh Sold Revenue Customers' Customer Kvh Sold.:-
1 A
~
Texas - Cont'd i
hh2 Industrial Sales 5
.j
)
h0h-T 011 Field an'd Oil
- (
j' Pipe Line Serv.
6,795,683 151,865 5h -
130 52,27h 2.23:
a 405-T Large 011 Field &
- d
)
-Pipe Line-Serv.
27,139,161 hh6,172.63 9'
3,015,h62 1.6h 3
LPS Large Power Ser.
-)
(and riders) hh6,029,616 h,109,131.00 14 31,859,258 92 j
f LIS Industrial Ser.
3
'j -
(and riders) 3,215,301,800 20,372,182 9h 13 2h7,330,908
.63-
-l j
FC Facilities Charge 985,193.06 3
SHL Street & Highway 2.12 l
j Lighting _Ser.
176,717 3,746.26 16(e)
'll DDL Dusk to Dawn
}
Lighting Ser.
303,197 15,177.h9 8(e).
5.01 j
FLS Flood Lighting.
7 Service 13,890 565.60 k.07 I
}
305-T General Power j
Service 95,40h 3,1h6.23
-6 15,901
~3.30 j
1 GS General Service' i
l (and riders) h6,776,15h 1,230,h65 56 2,810 16,646 2.631 2
1 LGS Large General Ser. (and riders) 561,917;8h1 7,272,596.75 239:
2,351,121 1.29 i
i
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~
i Total Industrial h.304,549,463 34,590,2h3.06' 3,245 1,326,518
.80
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Excludes duplicate customers served under other rates ulso
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- 20. - Attachmeng J.s osusea6.co 't 4
I Golf States Utilities Cornpany Schedule WHS.
Tease -
RIDER-FOR WATER HEATING SERVICE I.
APP!JCABILITY
. nis rider is applkable under the regular terms and conditions of the Cornpany to Customers served under b,.
General Service or Large Getweel Senice Schedules, hercinefact referred to es the " regular schedule", who have electric water baters snevnes Company's specifications.for time-controlled water heating of the automatic storese type.
. 11.
MODIFICATION OF REGULAll NET MONTill Y RATE ne met snonthly rete of the regular schedule is modified to include the following procedures:
service to mater hester cunomers will he billal in accordence with Procedure "A" or Procedure "B" specified below.
A. De Coenpeny will determine Customer's water heating use by separate meter if Cunomer's wiring is so ar.
reased that water heatiog use.can be segregated for billing purposes at pui.nt of delivery from belance of Cumomer's load. In such case Company will bill water heating service at 1.35e* net per kwhr.
t There weser heating service has been separately metered and monthly use has averaged less than the allowances under Procedure "B helow for a year. Company will, upon requept of Cunomer, reinove sepe-rate enter ar.d thereafter bill accoeding to table listed under Procedure "B" below.
B.' Where water heating service is not separately metered the foilowing final blocks of kwhr become effective
and will be billed at 1.35e* net per kwhr. provided. however. that the first 150 kwhr of total service used in any amonth must be billed in e.ccordance with the regular schedule and that not less than one half of the kwhr of total service will be billed in accordance with the regular rate schedule and applicable riders other than this rider Tank Casocitr_
Final Binck 34 to 45 gallone 300 kwhr 46 so 70 gallone 400 kwhr 71 galloos and larser 5 kwbr per galloa but not less rhea 500 kwbr ne billing lord as de. ermined in the regular rate schedule will be reduced by the greater of 3 kw or 0.03 kw per galAos of soud tank capacity, providel, however, that such reduction in billing toed shall not operate to redace the billing load below one half of the billing load that would otherwise be applicable under the regular rose schedule.
., Procedures "A" and "B" are ownielly on et least a twelve month basis and Cumonwr must resnela on one pro-cedure et least twelve smonche before changing to the other procedure mdees Customer installs additional water heaters -
ce reenovan austaus weser heeters..
- Plos applicable fuel s'ad tas edjumments specified in regular achedule.
.6/72 Page 5 of 6 a
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- OgU1044 99431 Gialf States Utill!!ss Contpany Schedule SCS Teane -
RIDER FOR SPACE CONDITIONING SERVICE I.
APPLICABILITY '
This rider is applicable under the regular terms and conditions of the Company to Customers served under Sch'edule GS or LGS.who have one or more of the following types of equipment:
, (1) Electric heat putop and/or resistance type space heating equipment for the primary conti uous, year.
round cooling r and beating requirements of the space with which it is associated.
(2) 25 H.P. oc saore of connected electric air conditioning.
In ossier to. qualify for this rider, the applicable equipment installation, control, operation, slaes and typa of snotors and supplementary resistance beating elements must meet Company's specifications. The wiring for equipment subject to this rider must be arrangal so that such equipment may be segregated for billing purposes fross the balance of Cussotaer's load.
e
+: '
II.
NET MONTHLY RATE N not monthly rate of the regular schedule is modified to include the following procedures. Billing will be in acceedence widi procedure "A" or "B" specified below, whichever results in the lower cost for service used for electric air conditioning. heat pump and/or space heating service.
A. Service to Customer for electric air conditioning, heet pump and/or space hcoting will be billed at 1.654' not per kwhr during " Winter Months" and 3.364* net per kwhr during " Summer Months".
Balance of Casecawe's service will be billed on Schedule GS oe LGS, whichever is applicable, except that for purposes of computing the minimum net monthly charge the billing load for the current month will be und.
- Plus applicable fuct and tas clause ediustments specified in Schedule GS or LGS, whichever is applicable.
B. Customer's total service including electric air conditioning, heat pornp, and/or space beating will be billed on Schedule GS or 145, whichever is applicable.
Ill.
DESICNATION OF WINTER AND SUMMER MONTHS Winter Months will be the months of November to the following April, inclusive, and Summer Months will he the months of May to October, inclusive, as used for billing purposes.
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