ML19308B189
| ML19308B189 | |
| Person / Time | |
|---|---|
| Site: | Oconee  |
| Issue date: | 02/09/1971 |
| From: | DUKE POWER CO. |
| To: | US ATOMIC ENERGY COMMISSION (AEC) |
| References | |
| NUDOCS 7912160018 | |
| Download: ML19308B189 (100) | |
Text
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BEFORE THE i UNITED STATES ATOMIC ENERGY COMAUSSION O o> ( Q 0001EIED IN THE MATTER OF S WE
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DUKE POWER COMPANY fEb blb7I emer u n unm MHc?rnJbo I8 OCONEE NUCLEAR STATIONS UNITS 1, 2 AND 3 Wa l Co i n3 DOCKET NOS. 50-269 50-270 ' 50-287 (~ * '
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ANSWER OF APPLICANT DUKE F 7WER COMPANY - 2. _ : - TO JOINT PETITION OF NORTH CAROLINA MUNICIPALITIES, STATESVILLE ET AL, ' FOR LEAVE TO INTERVENE AND OBTAIN ANTITRUST REVIEW The Applicant Duke Power Company, answering the Petition of the Nc,rth Carolina Mynicipalities, Statesville, et al, fildd on or about the 18th day of January,1971, alleges:
- 1. Paragraph 1 of the Petition to Intervene is admitted, except that it is denied that the Town of Newton, North Carolina, is a Petitioner. Applicant is informed and believes that the Town of Newton, 1 7912160 O/8 g
l D t on or about the 3rd day cf June, iD69, oy resolution of it Town Councti, formally withdrew as an intervenor and protestant in this proceeding. 2 Paragraph 2 of the Petition is admitted, except that it is denied that the municipalities are " captive" customers of the Appli-cant Duke Power Company. It is further cenied that "The availability and price of power to each and all of petitioners are initially and inextricably bound with and in the determinations in this proceeding. " 3 Answering Paragraph 3 of the Petitis it is admitted that the Applicant Duke Power Company together with Carolina Power & Light Company, South Carolina Electric & Gas Company and Virginia Electric and Power Company executed on July 9,1970, and filed with the Federal Power Commission on July 10, 1970, an agreement ter-minating the Carolinas-Virginias Power Pool Agreement, and at the same time filed with the Federal Power Commission a series of rate schedules under which they would in the future bey from and sell power to each other and buy from or sell to any other power supplier with whom they are interconnected, a copy of the July 9,1970, Agreement betng hereto attached, marked Exhibit A and made a part of this Answer. . It is denied that the power sales between Duke Power Company, Carolina Power & Light Company, Virginia Electric and Power Comoany and South Carolina Electric & Gas Company constitute a pool or - lotnt venture, or that t.ny pool or joint venture exist since termination of the C ARVA P:st Agreement. Appheant Du.se ?ower Ccapany is wdling to sell pow er, when avanacle, to an;, powe r suppiter w.th wt.om it is inter-
< , , o n . . t . ,1, tunter the rate eenesluieo net t.a u. to t.xiiii.u A. 't i.e Limited Term Power and Energy Schedule provides for pricing power and energy in essentially the same manner that these Petitioners' wholesale rates from Duke are fixed by the Federal Power Commission.
1: ts further denied that " Duke, a giant utility, is unable alone to reap the full economic benefits of nuclear power. " It is denied that "none of petitioners is able alone (nor by combination with one another) effectively to enjoy the benefits of this low-cost source of power." It ts denied that "Monopoli2ation of the benefits of nuclear power and of electric power marketing over petitioners' geographic area by Duke appears then imminent. " Petitioners themselves have publicly represented to the contrary. Ai .plicant is informed and believes and alleges that the petitioners are memtsers of ElectriCities of North Carolina, which together with the North Carolina Electric Membership Corporation, whose membership comprises the rural electric coopera-tives operating in North Carolina, have formed an organization known as EPIC (Electric Power in Carolina) which propcses to build three large scale nuclear generating plants, three fossil fuel plants and one pumped-storage hydroelectric plant in North Carolina, linking them with transmission grids of 500 KV and 230 KV, duplicating the genera-tion and transmission facilities of the Applicant Duke Power Company and Carolina Power & Light Company in North Carolina. Applicant is mt. informed and believes and so alleges that petitioners' attorneys, 1 Taity, Tally and Lewis and Crisp, Twiggs and wettn' and tra enpocera R. W. Beck and Associates and Southern Engineering Company of 1 I Georgia have recommended that such a generation and transmission
- plan u feasible for the long range power supply of the cities and j cooperatives of North Carolina. Copy of the EPIC plan is attached to this Answer as Exhibit B and incorporated herein by reference.
Except as herein admitted, the allegations of Paragraph 3 of the i Petition are canted, i 1
- 4. Answering Paragraph 4 of the Petition, Applicant admits that the petitioners are entitled to the " opportunity to enjoy equally i
with their competitors access to the miracle of nuclear generation. "
; Applicant avers that the question of what is petitioners' fair share j of the nuclear generation being constructed by Duke is a matter i
within the primary jurisdiction of the Federal Power Commission. Except as herein admitted the allegations of Paragraph 4 of the Petition are denied.
- 5. The allegations of Paragraph 5 of the Petition are denied.
j Applicant further alleges alat the justness and reasonableness of its I wholesale power rates to these petitioners, and to its other municipal and rural electric cooperative customers in Nortn and South Carolina $ i ts now at issue in a proceeding pending before the Federal Power i Commission in F. P. C. Docket No. E -7557, In the Matter of Duke Power Company. in which proceeding the Applicant here is seeking a 17% increase in its -wholesale rates to these petitioners and its o...er
roantelpal and rural electric cooperative customer 3. Petitioners here a re intervenors and protestants in that proceeding pending before the Federal Power Commiss:ca, which proceeding when finally concluded wiu of necessity catermine the justness and reasonaaleness of the v.nolesale rates of Duke Power Company to :hese petitioners. In this proceeding the fair share of these petitioners in the economies of nuclear generation, as well as their fair share of the economies of conventional generation and large scale transmission will be determined by well-settled public utility regulatory principle of cost of service to each class of customers. At present these petitioners enjoy the lowest rate of any class of customerr, in Duke Power Company's rate structure. It is denied that these petitioners' wholesale power costs from Duke Power Company place them at any competitive disadvantage to Duke Power Company with respect to new retail customers.
- 6. Answering Paragraph 6 of the Petition it is admitted that in the hearing on Duke Power Company's Application for a construction pe rmit , these petitioners were permitted to intervene and that they did make formal demand upon Duke to sell these petitioners a 47o undivided interest in the entire Oconee Nuclear Station, and that the Applicant Duke Power Company denied that demand on the grounds that (1) it i
would cause a discrimination against Duke's other large customers similarly 3;tuatec, contrary to tc.e Federal Power Act anc .he Puoiic C:iiny Re::ulatory Laws of South Carol;na; (2) t.nder the laws of North Carolma anc South Carolma the petuioners have no legal authority to , own an interest in the Oconee Nuclear Station. In response to the
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n nc a ci of t ha t i rquen t a nd ac o,ania in l'u ra g niph n . ,i uc l 'e t it o ,n . the Applicant Duke Power Company again cenies same, and for the same reasons.
- 7. Paragrapn 7 of the Petition is cemed.
AND FOR A FURTHER ANSWER TO THE PETITION TO INTERVENE, Applicant Duke Power Company alleges:
- 1. Unit No. 1 of the Oconee Nuclear Station is now scheduled for commercial operation on or about September 1,1971, and the capacity and energy to be produced by this unit will be badly needea in the Applicant's service area at that time. The Applicant therefore requests,in the interest of its electric customers, including these petitioners, that if the Commission determines that a hearing on anti-trust issues is necessary, that pursuant to Section 105 (c)(8) of the Act, as amended, and the Commission's Regulations pursuant to the Act as amended, Section VIII. Anoendix A. 10 CFR Part 2. Subsection (e),
the Commission issue to the Applicant Duke Power Company the operating license for Oconee Unit No. 1, conditioned upon the final outcome of the hearing on antitrust issues as specified in Section 50. 55 b of the Regula-tions. 2 Applicant respectfully requests that the Commission trans-mit a copy of this Answer and its exhioits to the Attorney General when it submits the Application and Petition to nim pursuant to Section 105 (c) of the Act as amended. Applicant incorporates oy reference into this e e
1 Answer the Joint Appendix in Cities of Statesvil'e et ai v. Atomic Enerav Commission, U. S. A. , and Duke Power Co. , Case No. 2 ',706, U. 5. Court of Appeals fcc the District of Columbia C i rcutt. 1968, (Juc'gment entered Dec. 5,1969) which contains a summary of proceedings at the construction permit stage.
- 3. Applicant is ready and willing to furnish to the Attorney General such addi'.ional information as the Commission may direct.
Respectfully submitted this 4tn day of February,1971. DUKE POWER COMPANY By s/ Carl Horn. Jr Carl Horn, Jr. , Executive Vice President and General Counsel 422 South Church Struct, ! Charlotte, North Carolina l s/ Rov B. Snaco ROY 3. SNAPP 1 Bechhoefer, Snapp & Trippe Suite 512, 1725 K Street, N. W., ' Washington, D. C. 20006 ! Attorne . for Apphear,t i l WALD, HARKRADER, NICHOLSON AND ROSS i By s / Willia.- W Ross William W. Ross 1 Suacerland Building 1320 19th Street, N. W. Washi .;; ton, D. C. 20056 Attorr.eys ir A;plicam l l l l
*l itM14 ilm YllE UNITED STATE.s ATOMIC ENEttGY CO?,1 A115510N In the Matter of )
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3~~KE ? OWE A CCM?AT" ~ "* Nco. K-2 0
-s (Oconee Nuclear Station, <
h-257 Units 1, 2 and 3) ) CERTIFICATE OF SERVICE I hereby certify that copies of " Answer of Applicant Duke Power Company to Joint Petition of North Carolina Municipalities, - Statesville et al, for Leave to Intervene and Obtain Antitrust Review", dated February 4,1971, in the captioned matter have been served upon the following by deposit in :he United States mail, first class or air mail, this 9f/. day of February,1971: M r. Stanley T. Robinson, Jr. , Spencer Reeder, Esq. Chief, Public Proceedings Branen Spencer Building Office of the Secretary of the Saint Michaels, Maryland 21663 Commission U. S. Atomic Energy Commission Jack R. Harris, Esq. Washington, D. C. 20545 Suite 207, Stimpson-Wagner Bldg. , Statesville, N. C. 28677 J. O. Tally, Jr. , Esq. , P. O. Drawer 1660 Dr. W. C. Bell Fayetteville, N. C. State Planning Task Force P. O. Box 1351 Mr. Dayne H. Brown, Director, Raleigh, N. C. 27602 State Raciation Protection Program North Carolina State Board of Health Mr. J. Bonner Manly, Director Raleigh, N. C. 27602 State Development Bea rd Hampton Office Building Honorable Reese A. Hubbard Columbia, S. C. 29202 County Supervisor of Oconee County Walhalla, S. C. 29621 Al;;ie A. Wells, Esq. , Chairman M r. Josepn B. Knotts, Jr. , Atomic Safety and Licensing Board Pa ne '. Counsel for AEC Regulatory itaff U. S. Atom.c Exrgy Commission U. S. Atomic Energy Commission Washing:en, D. C. 20545 Washington, D. C. 20545
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Y[Y.C, NT.rNra leT, NiC'r.c lcn anr. Eoss o A:tceneys Or A,,piicar.t 3
1 ! AGREEMENT 'i'!:RMiN ATING CAROL.iNAS-VIRGINIAS POWMR POOi, AGREEMENT t TilIS .\GilEEMENT, made this 9th day of July .1970, by and h.. .
. Carnlac l'cwc.r 6. Ly;ht Comp .ny, Du'.c Powe r Company. Soc.th C;.colma I: lect ric & Gus Company and V!: p..ia E' ectr:c and Power Company.
he ren...it er refe rre<l to at. Part ies: I
- W l T N E S S K T11
i WitMl;l: Ah, the l'a rties executv<l the Ca rchna s-Virginius. Power l 1%,1 Ag cen.< ot (hereinafter called the C.AllVA Pool Agreement) on July 1 i j 1961, and have operated pursuant to its terms, as revised and amended, i since May 1.19G7. to the present; and WHEREAS. cach of the Parties has become a member of the Southeastern Elcetric Reliability Council which was formed on January 14 1970, and j WiiMREAS. the Parties hereto have executed the Virginia-Carolinas Heliability Agre.*nient, a sub-group within the Southeastern Electric Heliability Council; and i 4 WHEREAS. the Virginia-Carolinas Reliability Group and the I Southeastern Electric Reliability Council will provide a vehicle for coordina-tion and planning for reliability of electric service on a broader base than now provided in the CARVA Pool Agreement; and 1 WIIEREAS, each of the Parties hereto is now and has for many years been interconnected with the Party or Parties whose electric system i
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. adjoins it, pursuant to interconnection agreements on file with the Federal .
I Power Commission; and j WHEREAS, future sales and exchanges of capacity, energy and spinning reserve, emergency assistance and coordination of scheculed maintenance can be made under interconnection agreements between the Parties more simply and expeditiously than under the present CARVA Fool Agreement; and . WHEREAS,the annual fixed capital charges provided in the CARVA P>ol Agreement and its Appendices have become obsolete due to the rising cost of capital; the prtcing formula in that Agreement is excessively com-plicated and provides insufficient means of adjustment to reflect current economic conditions; - NOW THEREFORE the Parties hereto, in consideration of their agreements each with the other do hereby mutually agree as follows:
- 1. The Carolinas-Virginias Power Pool Agreement dated July 1, 9
1961, as subsequently amended and revised, together with all appendices thereto, is hereby terminated, effective April 30, 1970, the last day of its current fiscal year. 2 Each Party will continue to make annual payments in support of previously authorized Pool Transmission Facilities in the amounts and for the periods specified in Appendix A attached hereto and incorporated into this contract by reference. 1 3 Each Party hereby reaffirms its rights and obligations under the following contracta: 2-y
(1) The contract between Carolma Power & laght Company and TVA, executed January 22, 1970; (2) The two contracts between the Southern Company and Duke Power Corr.pany, both dated August 1,1969. (3) The contract between Carolina Power & Light Company , and the other Parties hereto with respect to Asheville Unit No. 2, which te rminates May 1,1984; (4) The contract between South Carolina Electric & Gas Company and the South Carolina Public Service Authority which terminates April 30, 1974; (5) The contract between Virginia Electric and Power Company and Allegheny Power System for the purchase of 100 megawatts from May 15, 1972, to September 15, 1972;
- 4. For a period of three years from May 1,1970, the parties agree to adhere to the principle of equalized reserve in the allocation of reserve responsibility among the four companies, in the manner set forth in Para-graph 6 below. The 300 megawatts of capacity which Virginia Electric and Power Company is purchasing from American Electric Power Company for the period May 1,1971, to April 30, 1974, is hereby recognized as Vepco's capacity, to the extent it is actually available to Vepco.
5 Each of the parties agrees to file with the Federal Power Com-mission service schedules for (1) Limited Term Power; (2) Short Term Power; and (3) Spinning Reserve, in substantially the form set forth in Appendices B, C & D (attached hereto and incorporated into this contract by ,
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{ l . reference) for use by and between such of the pt.rtias whose electric systems , are adjoining, over existing interconnections or such additional interconnec-j tions as may oe established between ary of the parties. Each party undertakes
; inat it wn1 use its best effcrts to citain Faderal Pcwer Commissten acceptance for filing of these Service Schecules as rata schedulas si the fihng party. Each i
party agrees that it will not withdraw or cancel any of these three service 1 l
- l. r j schedules prior to April 30, 1973. All parties undertake to use their est 5 I
l efforts to obtain Federal Power Commission acceptanca for filing as a rate i schedule of Carolina Power & Li;nt Company, the contract between that ; a i
. Company and the other parties hereto with respect to Asheville Unit No. 2.
4 l
- 6. For a pertod of three years beginning May 1,1970, tne parties j
i hereto agree to buy or sell Limited Term Power ir. such amounts and for
- such periods that each of the four campanies will carry the same percentage t
I reserve (herein called Equalized Reserve) based on that Company's estimated i Adjusted System Load, estimated each year for the threa 12-month periods beginning May 1,1970; May 1,1971; aan May 1, '.572. Tha saic 12-month I 4 . periods shall be c; lied Annual Al'.ccat.cn Periods. The tota'. amount of reserve 4 ) to be divided amt ng the companies will be the excess of the sum of the companies' Adjusted System Capabilities over the sum of the companier ' .3djusted System i , I .oa ds. Adjusted System Capability" of t. C:mpany is the sum of the net generating capabtitty insta' led cn its system anc mace avanacle for inclusion hereunder, plus firm capabnity (other than ;m:.wc Tarm ?cwen prehased
- from others where.the raserva ~ ras;castbihg _ tht.: cf ; .a ,;urchise r,' t.nd
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O minus firm sales to others where tne reserve responsibility is.that of the purchaser.
" Adjusted System Load" of a company is its peak net territorial 5 loac for a clock-hour, adjusted in three ways:
, (a) By accing firm power sales to other compantes (other ; i than Limiteo Term Power) when the reserve responsi-4 bility ts that of the seller; (b) By subtracting firm power purchases from other com-pantes (other than Limited Term Power) when the reserve :esponsibility is that of the seller; and (c) By subtracting Interruptible Power Sales. Prior to the beginning of each Annual Allocation Period, each Company will supply the others the estimate of its peak Adjusted System Load for the said alloc ation period. This estimate will be used throughout the period for calculating Equalized Reserve. Equalized Reserve for each Company will be calculated, and the amounts of Limited Term purchases or sales resulting therefrom will become effective on the first cay of the Annual Allocation Period. New allocations of Equalized Reserve will be made, and new amounts of Limited Term Power sales cetermined each time the Adjusted System Capability of one or more companies is changed. After the last such change in an Annual Allocation Period, the then effective allocation will remam in effec: ur.til the er.c of such perioc. IN WITNESS WHEREOF the Parties nereco r.:.ve caused this 3 -[
. - - - s
. Agreement t a be executed by tneir duly authorized officers, the day and yea r first above written.
ATTEST: CAROLINA POWER & LIGHT COMPANY By Sec retary ATTEST: DUKE POWER COMPANY By Secretary ATTEST: SOUTH CAROLINA ELECTRIC
& GAS COMPANY Sec reta ry ATTEST: VIRGINIA ELECTRIC AND POWER COMPANY Sec reta ry l
l 4 4 < e up
f.P?2NDIX A page 1 , TEMi'M*.TIO!; D.4TES FOR CARVA PCGL TRANSMISSION FACILITTES Portion Pool Owned Participation In-Service Facility Campany (5) (4) Date Termination D acky Mount-Battleboro 230 kv CPEL 65% 100% 1967 & 1968 April 30, 197 Vapco 357, 1001 O s:on to Everetts 230 kv Added Length Vepco 1007. 1007. 1967 ' April 30, 197 Wa cree-Robinson 115 kv OCD Duke 1007. 1001 1967 April 30, 197 Vtcaree-Robinson 115/100 kv Transf. CP6L 1007. 100% 1968 April 30, 19? Ma 7.tver 138/100 kV Transf. Duke 1007, 100% 1967 April 30, 197
- svidson River 115/100 kv Ttansf. Duke 1007. 1007. 1967 April 30, 197
..ncry 115/100 kv Tr.snsf. Duke 1007. 1007. 1967 April 30, 197 ?c.xboro-Eno 230 kv 2nd Cira.it nuke 42% 100% 1968 April 30, 197 CPsL 58% 100%
Asheville-lforseshoe Tie Duke 837. 100% 1968 April 30, 197 CP6L 177. 1001 Fr r r-!!auport-Neube rry 230 kv nuke 457. 1007. 1971 April 30,197: SCZEC 551 100% Canadys-Sunter 230 kv scrLG 407. 1007. 1967 6 1970 April 30, 197 CPst 607. 1007.
',- te ree-Sutater 230 kv SCE1G 18% 1007. 1970 April 30, 197' CPLL 8 27. 1007.
ti *erson-Roxboro 132 kv CP&L 1007. 1007. 1969 ..iril 20, 197*
'; t' . -V i rgi n i a S t a te 1.i ne -Cow. ins
- ! $00 kv -Duha 10G% (2) 1971 Apri1 30, 197:
s Ford-?!cupart 500 kV Duke 100% 100% 1972 hrti 30. 197
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,APIENDlX A Page 2, TElul1 NATION DATES FOR CAI;VA POOL TRANSMISSION FACII.ITIES .
Portion Pool 0.m ing owned Participation In-Service Facility (6) . Cotepany (5) (4) Date Termination D Surty-carson 500 kv Vepco 100% 507. 1972 April 30, 19P Carson-trake 500 kv Vepco 507. 1007. 1972 April 30, 197: CP&L 50% 1007. J R ich.nond -Hake 500 kv CP&L 100% 07. (3) r " Newport-Richmond 500 kv CP6L 457. 1007. 1972 April 30, 197 Duke - 557, 100% Footnotes: (1) South Caroliua Electric 6 Cas Cocpany termiaates pcyments on April 30, 1976, and owning companies assume SCEsc payment responsibilities through April 30, 1978. (2) Poul participation will be 507. from May 1, 1971 to April 30, 1973 and 357. frcin May 1, 1973 to April 30, l')7 6.
',3 ) C;.tolina Pvt .a & Light Ce2.pany agrees that it will construct this segment of the 500 kv line, wit hout -
any sharing of cost by the othcr companies. The line will be constructed and placed in service at such time .:s r.trolina Powe r & Light Company needs the facility in its own system and in any event not later than 19 tu . , (4) The annua. t i o .i capit al charges and the operating and maintenance expenses for Peol Transmission l'ac i li tics sh a ll b. distr.buted .nong the companics in the ratio of each Company's est itaated peak net t e r rit.o r i a l le.:d, plea f o r:a sales to non-racmbe r companit.s, to the sum of such estimated peak net territoriet l o..d s , plus firm sales to non-member coaipanies, of all the companies.
-(5) 11ased on e:.t in.ated cost.
(6) Each i ten includes all necessary line and substation f acilities whkL ha, e been previously agreed upon by ;he C.nVA E:wcutive Cotanittee and listed in Notices of Obligation and Minutes of CARVA Executive C..etaitt(c L etings.
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, APPENDIX B
. SERVICE SCHEDULE LIMITED TERM POWER AND ENERGY Sec tic l> -a tto_r1 1.1 This Service Schecule, a part of and "nder an agreement dated
, between and
, shall become effective September 1, 1970, and shall continue in effect for an initial period ending April 30,1973, and thereafter until terminated as provided for in Section 1. 2 below.
1, 2 Either party upon at least three years' prior written notice to i the other r. arty may terminate this . schedule at the expiration of said initial period or thereafter, j Section 2 - Power and Mnercy Delive ry 2.1 Either party by giving the other party notice may reserve electric power (herein called Limited Term Power) for yearly periods, or for shorter periods where the availability of Limited ferm Power depends upon the in-service dates of new generating equipment or by mutual agree-ment, in such amounts and at such times as the other party may have and is willing to make availabic as Limited Term Power.
- 2. 2 11 the party receiving the request for Limited Term Power does not have it av.iitable from its own resources, it may, if requested. arrange '
to purchase Limited Term Power from a third party for resale to the party making the. request, under the terms specified in Sect.on 3.
- 2. 3 To reserve Limited Term Power,'the party desiring such power ,
1
e S nit ti .S[Jm ily i n .t S fint iC C io ;ne OUlc r ;s r'.y ..;, J.a!..ae : os r.;;GW;.;t., e ral the pe rtoo tor wnich :t ue.stres to c.me rve suc r. pow e r. Tae party roce:ving sucn notice shall signtiy the amount anc perioc c: time it :s willing to make
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constitute 0:ncing agreements aetwean :ne part;es uncar ;ne terms o ;.tais service schedule.
- 2. 4 During the period tna: Limitec Tarm i:awer has been contractec for as provtued in Section 2. 3 above, the party ahien agreed to supply such power shall deliver electric energy (herein callac .m;;ad Tarm Energy) to the other party upon cau anc ta amounts '.:p to . a curaae r c:. ,m. ow a tt s c o n-tractec for. However, in :he event ci braaxcown or other e .ergency condi-tions on tne system of the su , ply.ag party resu'tLing n- icss of generating capacity in excess of ,3.,.-ow of the ra;ac capac;;y of .:s largest Jacerating unit, the supplying party may recuce the raie ci e ai very :: such enerpy under that .
portion ot .t tmiteg.1 e rm .,c' ice r ce:r. ; mac.a aw.1c.a :: om it s awr. gene ration sources in the rat:o ;nat tne ctal amcunt c.' .;t.;..;a .so Ic;n aars :o tha rated capacity of its largest ;enaratin ; unit. T .e cel vary cl ene rgy under that portinn of Limiteu Term ?cwar ce;n; mace at ar.ac.2 from its own genera-
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1:cn sources may be c;scentinuac rhar :ha .:.c esc ;ence ..;c.g c;. ice ;he newest of such lar;;est ; nits i: ; .2 re are er.c cr. c c c. m c; ice c.t. :.1.s :c) or. ( 4 I the system of the st.ppiyinif pa rty .6 Out c. sc r /.ca .u. : ::.Acu.a c maintenaCOe. 1 At a port 10ia C t w.s. . u . . t e u.. . e. . . . -: .s.. , . . , .m.. . , . . . . ...
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l l s;m:ta r u, those outuned acove, then the suppiying party may nterrupt or , i recuce its deliveries to the receiving company by i xe amounts
- 2. 5 Subject to the provisions of Section 2 4, the supplying party will dei;ver L.=; tac Te r r ?ov/ar c accoraance w; . schecules des;gnatec cy the rece:ving party.
2 6 The losses c.ssoctatec w;th the ; cans =13s:c,n of capacity and energy under this agreement, either on :he system of the supplying party, or on the system or a tatra party wn:ch may be supplying Limited Term Power to the supplying party hereunder for resale to the receiving party, will be borne 'oy the receiving party Compensation for such losses will be accompitshed by seneduling coincidental delivery of loss compensation Section 3 - Rates and Charges 31 For capacity purchased from a thirc party by the supplying party for resale to the receiving party hereunder. the receivir.g party will pay the supplying party a rate per kilowatt equal :o the rate per kilowatt paid to the third party by the supplying party. For capac:ty mace ava:iaola fecm the ystem of the supplying party, the parchasing party will pay tne supplying party a rate per xilowatt equal to the Annual Demanc Charge Ra:e calculated for the system of the supplying party in accordance with the formula set forth in Appendix A to this .a greement. The Demanc Charge Ra:e wiii ce calculated as of December 31, }969, anc Cacernber 51 of eacc ca.encar yea r thereafter when lamited Te rm ?cwe r is heir.c se,1;. 'Zhe ici .c.. .ure.ac.: Charge Rate shali in t t feet: .e cu rint 19 70, .nc incraai:e; ; .e u c.t.::d C.'.ar;fe Hute for i each cat. c.ca r yea r ,n2; becor.e c;fect.ve ;a cf . ac.;.;ry . sch;ec;;o recaice- - 3
J iation in 1970 and subsequent years upon tne occurrence of any of the follow-
- ing incidents (such recalculation to be mace as of the date of each incident, except that initial billing may be on an estimated basis subject to adjustment when I
- nal accounting cecomes available):
(a) A new generating unit is placec in service or an ? , existing unit is retired on the system of the supply:ng party; (b) A new transmission facility of sufficient sice as to 3 affect the Annual Demar.d Charge rate is placed in service on i the system of the supplying party; 4 (ci A change occurs in the status of a transmission i i facility on the system of the supplying party which would affect the Annual Demand Charge rate; or ] (d) A new issue of bonds or preferred stock is made, or j an outstanding issue of bonds or preferred stock is retired
- on the system of the supplying party.
t r
, It is tntended tnat changes in (a) above involving major units will be
- made effective as of the first day of commercial operation of the unit involved.
Changes involving inte.nal combustion turoine generators or small steam or i hydro units of 25,000 KW or less may, at the option of the owning party be- [ made effective as of the first of the month next following the date of commercial-
- operation or the date of retirement, for purposes of calculating Annual Demand Charge rates hereunder. Payment for capactty shall begtn with the initial date l
l of tne per:od of delivery ar.d shall cor.tir.ue :.ntil the terminal cate of such l-l_ perioc of cetive ry, wit . cut any ac;ustment for perions wher. the de'.;very of i energy :s_ tnterrupted :..,-proviceu . . See::on 2. 4 a bove. N _
- 3. 2 When energy delivered hereuncer is generated on the system of the supplying party, the receiving party will pay for such energy at a rate per kilowatt-hour calculated as follows:
(a) For tne 12-month period ending Aprii 30,1971, anc for periods subsequent to April 30, 1973, the calculated 4 average procuction cost (including operating and maintenance costs) of the energy produced by all plants on the system of the ( supplying party for the month in which the delivery is being billed, plus 10% of such average cost. (b) For the periods from May 1,1971, through April 30, j 1973, two rates as follows: (i) the calculated average production cost (including operation and maintenance costs) of the energy produced by those I-C turbine generators scheduled for 1971 installation which have been installed and made available for use hereunder on the system of the supplying party, plus 10ct
- hereof, and (ii) the calculated average production cost (including operating and maintenance costs) of the energy produced by all other units on the system of the supplying party, lus 10% for the month in which tt.e delivery is being billed. The amount of energy to be billed under (i) above will be the amount of energy generated on 4
the I-C turbine generators in (i) as a result of the delivery of Limited Term Energy hereunder. The amount of energy to be
~ billed under Di) above will be the excess, d any, of total Limited Term i:'nergy cehvered curtag the month over the amount
i
- ' billed in (i) above. Billing each month _will be on an estimated basts, subject to adjustment when all production
- costs for the billing month are available. If a party is selling 1 im;ted Term ?cwer to more than one company at the same time, the amount of energy to be bnlac uncer (1) wd'. be pro-rated between the purchasers of such energy in the ratio of the i
j amounts of Limited Term Energy deliverec to each during the i time in which the proration is being mace, ,. When energy delivered hereunder is purchasec from a l thted pa rty by the supplying party for resale to the receiving 4 party, the receiving party will pay the supplying party at a j rate equal to the er st of such energy per kilowatt-hour plus 10% i i
- 3. 3 Where applicable, taxes will be added to billings under Sections 3. I and 3. 2, including but not limited to:
Support of South Carolina Public Service Commission 1 l Sales Tax or Energy Gross Receipts Taxes Sales Tax or Use Tax on Fuel .l South Carolina Generation Tax
- Any. new or additional applicable taxes imposed after the date of this Service Schedule shall be incluceo in billings hereunder.
a 4
.,b
$ .I
.w
,. - . . -. _ .- ._ 3 . ._.% . c, a
APPENDIX A GENERAL EXPLANATION OF DETERMINATION OF CAPACITY CHARGES AND ENERGY CHARGES-LIMT.TED TERM POWER SERVICE SCHEDULE The selling company w;1i :nvoice the buying company fcr capacity anc energy used on or before the tenth day of the month, payable by the twentteth day of the month, for capacity anc energy usec in the preceding month. Cost wilt be estimatec if not known and adjusted at a later date. The charges will be calculated as follows: 3 A. Capacity (Ptxed) Cha rge Calculation:
- 1. The monthly demand charge is the sum of one-twelfth of the annual production capacity charge and the annual transmission capactty charge.
- 2. The annual capacity charges will be calculateo always as of the previous year end and recomputed aring year whenever either a generating unit is placed in service or retired, or transmission facility of sufficient size as to affect the annual demand charge rate, is placed in service or retired, or whenever there is a new issue or retirement of long-term debt or capital stock. The annual capactty charges will be recomputed the first of the subsequent month of such incident, except in the case of a generating unit above 25,000 KW which shall require recomputation as of the date of such incident. At the time of any recomput e.on, the annual capacity charge rate shall be adjusted to
, reflect all additions and rettrements of bulk transmission facilities, since the last previous computation.
- 3. The method of computing the annual procuction capacity charge per KW is to divide the sum of the pr oduction annual fixed chard *S. if'ciuding return on investment, depreciation, income taxes, property and other taxes related to plant investment, and insurance, by the sum of all production plant capability, stated in KW, under the most adverse operating concitions (Major plants-FPC Form 1, pages 432 and 433, line 10, and small plants per company.
, records).
- 4. The same procedure is used for computing the annual transmission capacity-charge except that transmission O & M expense is included as a fixed charge and all transmissica amounts are adjusted to eliminate (1) costs not associated with bulk transmission and (2) ransmission investment currently being shared by former CARVA Poel members under termination agreement. Long-term
, firm purchase of KW capacity will be adcec to prcduction capability determined uncer A. 3 above, to arrive at transmisston charge per KW.
- 5. The annual _ fixed cha rges are computed or ceterminec as f allows:
5.1 Iteturn on Investme .t This item of annuni tixec char;a .3 compt.tec ny muluplytn., the total functionat (Proc. & Trans. ) investment by taa :atett' amaeccec weighten ' composite cost of. capital.
e A. 5. (cont) 5.1.1. Investment Investment consists of book plant balances in ar.c ounts 101-106 less accumulated depreciation (accounts 108-110; plus net nuclear fuel investment in plant account 120 and allocated por-tions of normal working capital, consisting of: (a) Minimum bank balances in account 131. (b) 30 Day producucn fuel supply in account 151. (c) Other materials in acccunts 154 and 153. (c) 1/8 of all operating expenses for one year. except , purchased power (accounts 500-557 less 555) for production and accounts 560-573 for transmission with both functions also betng allocated a portion of A & G expense accounts 920-932). (e) Federal income tax offset, consisting of an agreed percentage of the annual Federal provision in account 409, is deducted from other working capital item. 5.1. 2. Composite Cost of Capital Three costs of capital are computed: for long-term debt, preferred stock and common equity; and are weighted on basts of capitalization ratios, and summed to arrive at composite cost of capital. For bonds and preferred stock, weighted annual net cost to company is computed through mos t recent tesue or retirement. For common equity, the sum of net earnings for common (excluding extraordinary items) for last three calendar years is divided by the sum of the daily weighted average common equity outstanding for the same three year period.
- 5. 2 Depreciation - FPC Account 403 Depreciation will be calculated using depreciable plant balances (including a portion ,af general plant), and annual depreciation rates.
When a production plant or transmission facility is added or retired, depreciation will be recomputed to account for the change.
- 5. 3 Income Taxes The income tax fixed annual charge is computed rather than allocating actual book amounts. The computation begins with the return on investment amount (Para. 5. I above), deducts the tax deductible interest portion and, using the current composite Federal-State tax rate and m. king .idjustments for differences between book and tax depreem t um, computes what the income tax would he, assuming the ret u rn on n.vi :' ment previously computed.
i4 l*ropert v and Other Taxes iteiated to Plant investment- PPC Account 408 Taxes directly assignable to producuon pisnt nec iaentified anc re.mainmg plant taxes are allcaated on casts of gross book p. ant (accounts 101-106) , with the general piant a!!ccatec portton further allocatec to remaining functions on same basis. 2
.. . . . - ~~ ~ - .
4 A. b (Coi.t tnuinD
- 5. 5 b rance - Fl*C Account 324 Total insu ra nce; expense is sesigned utrectly where possible with the balance allocated on casis of plant anvestment.
- 5. 6. Tra nsmtssion O i. M Expense l This item is used only in computtng the transmtssion capacity charge i and consists of the last annual transmission O & M expense (accounts l 350,-573) .ncrenad by a percentage for A & G expense and payroll
- taxes anc reouced by :he porticn applicable to non-bul'c transmtssion plant.
- 6. Tne resulting procuctton and transmission capactty rates c KW a e
! multiplied by contracted KW to calculate the capacity charges for the_ month. B. Energy Charge Calculation 2
- 1. The monthly energy charge is based on the actual production cost per '
net KWH of the selling company for the month in which the energy is sold.
- 2. The following costs will be used to calculate the energy charge rate;
- a. FPC accounts 500-557 excluding purchased power (account 555).
a
- b. An allocated portton of Administrative & General expense hxcluding
!, insurance) and payroll taxes. 1 } 3. The KWH net generation will be the net generation for all production plants ! with exceptions noted in the contract. l
- 4. The n:onthly production cost, as stated in 2 above, will be divided by the i KWH net generation as stated in 3 above. To the results will be added the 10% specified in the agreement.
i
! 5. The resulting rate per KWH, as calculated in 4 above. wnl be multiplied , ! by the KWHrs of energy delivered by the selling company to calculate the l total energy charge for the monta. l
. ) C. Acolicable Taxes / ; Applicable taxes not provided for elsewhere, in the capacity charge calculation or the energy charge calculation, will be included in *he bill by the selling company, i 4
.3-
LIMITED TERM PCWER SERVICE SCHEDULE tIL Company ENERGY CHARGE r- - -- - - ,_ _. --_ .
, _ __ _ _ _---.. - - - - - v.,.---
Line N .~gtmw _----- ! lF?C I 6 Reference I a I Month of
-l i (i)
I r i Starm l I i I l 1 Operation (500-507, excluding fuel) ') .417,11ne '12 ! i i ! : 1 2 Maintenance (510-514) i 'p.417,line :19 , i
- : i :
; Nuclear j f
3 : Op< ration ( 517 - 5 25.e xc lud i ng fuel)
' g'.417,11ne32 l 4 ' i
, Maintenance (528-532) ; p.417,11ne[39 l ;
I s
! i ! '
tivdraulic ! ' l i i 5 ; operation (535-540) l' p.417,line'i49 i t i - o ; Maintenance (541-545) ' . i p.418,11nep j l 6 i 4
'Other Power I ! ! l j i 4 1 i t I
?
Operation (546-550 Excludi.ng fuel) ! p.418,11ne '14 i i ! 3 Maintenance (551-554) 'p.418,line 20 I l
. l l i .
l
! I i
- Otner Power Supply Expense (Excludide, i t .
Purchased ?ove r) l I ' i g i i 4 l Sys ten control and load d{sp. i p.418,11ne 24 i i
} ;g~ " T Other expenses '
4 p.418,11na 25 t !. I I l .
! l 11 jTotal U.ines i thru 10) ,
i I l .
- i 12 !
'.A d d 7, Line 11(See Sch.IIIa) '
i i I 4
' i I !
_ i Fuel ! - I ;
, I I :
13 Steam ; i
.- i,
- 14 '
Nuclear , , 15 Other ! 4 16 . Total (Lines 11 thru 15) i
. n .
Wri Net Gene.arion p .431, lin, ) *
- i?
Produellan Cost per Net iG."t( : ( l i ne 16 + ; 7 ) av Md 102 (1101 of line ;o) b 4 w.. - n* n % 49 49 .h QQ ,_
r 1' I
- f. LIMITED TERM POWER SERVICE SCilEDULE 1:.u I' Company l Calculat ion of Allocat ion Percent for A 6 G Expense,
! Payroll Taxes, etc. I Calendar Year } = u. z:=:.o ur_c . - um rz: .u=r au m-cu renrr .2,.r - m r .rr = ecs.sg mm 2 : emm. v rmru s rn ) 1.ine FPC F arm I I
. _ Eh& .m.._ - __. _ ._ .. ... . .. m _. m . , 1._m m JLefe renC _. _mm- -..m.,-..
p..! I.L- - ~ _ . ~ 1 Adm. and Cen. Expense e Page 419 Line 53 l 2 I.ess Insurance Page 419 Line 42 l i I(
)'
i 3 Add All' Fed. 6 State Payro 1 Taxes Page 352 l 4 Tot al A t. G and t' h taxco _ _ _ 3, __ , . _ _ _ _ i 5 Total 0 6 H Expense Page 419 Line 54 l I Less: i e Fuels Excludeds , t 6 Steam - Ac[t. 501 ,l Page 41), Line 5 ( ) i , 7 Nuclear - Act t. 518 l Page 41 r, Line 24 ( ) 8 Other - Acc t. 547 Pagc 413, Line 10 ( ) > 9 A & C Expense (Line I above) ! j( ) 10 Purchased Power Page 418 Line 23 ( ) I i Balance 0 6 M (Line 5 les.s 6 - 10) 11 12 Allocation Percent (Line 4s Line 11) , 1 . _ _ - . . ~ ..__. .. __ _ . . __ _ . _ - I
- ___._..l__... .._. . _ _,. .. . _ _ . _. . . . . . . . . . _ - - - - -
I i
A Ll!41TED TERM POWER SERVICE SCelEDill.E_ _ . - - _ _. COMPANY Return on Investment as of ~
'"""~~'*'*
J. i ne
~ ~ ~ ' -
~ ~~ ' ~ - 'P r oJ u'cTi <in~ ~~' ' ". - - ~ - "~7" ""- - ' Triilisin! 61 b'n '~
Refere:nce i Amount i R ference Amaunt _..<,..,.s-3p * . x--. .- . . . . . . ,
,,..-q,....,,--n . . = . . , . -. . - , ...a . . . . . . . . .
Sch. I.ine Col. (1) Sch. Line Col. (2) j f Gross Plant in Service: l 1 Electric A-1 6 5 A-3 7 2 2 Electric-Noc. fuel-net A-7 4 5 . 3, Lest: Accom depr. A-1 17 5 . ( _ _ A-3 15 2 ( ) 4 Net plant in service Materials and Supplies: 5 Non - Fue1 A-4 21 1 A-4 23 2 h Fuel A-5 30 2 Workiny,Capj;al_: / I;iniwur.. tenh lealance A-6 3 2 A-6 5 3 tl 1/8 Open. expense A-6 15 2 A-6 17 3 9 Fed. Inc. tax offset A-6 20 2 ( A-6 22 3 ( ) O Total I nveti t men t -_ I . C.o..m. pos i t c con t o f cay. A-8 4 . 5 -_ 1. . A_8 4 - 5 - --
~4 - - - - .
l T Return on I nves t inent (11 times 10) _ ____ _ e o
LIMITF.D TFRM POWER SERVICI: S C H t:Dil t.f. .41 Company _ Cost of Plant and Accumulated Depreciation ' As of pt-1.ine
. r .r .: c c s : w.:r. .r nrn::: r : na -m a.c -1 z.a. m J.0I filSiLu_..u a ...m :.un a .ar2 **Dr Ed } :-P) d 1 L < : - e r u. m .ow.:uc . . ...;2 .r FPC as of :Lubsequent Revised 1 Allocation Total 7. of Total Jh! . . . .. .lM3c;httigit... , _ , l'gigf _ ge;f... d2))J A.v ? ). !. . (l1 M 2)1 441. 4:al.. 5. m b-m._,_.,
(1) 'ImisacLJnug llalance J5 c .(4) Cost of Plant (Acets. 101-1 06) (2) (3) - (5) i ( t, ) I Production: Steam 403 l g l ; l . 2 Nuclear 401 ' 3 l Hydro l 401 l 4 1nterna1 Com! 1 402 .5 '6 Total Production 402 . 1 7- Transmission 402 . .8 Distribution 403 . (Sch. A-24
- 9. ' . _ . .G. e. n.. e r. s.12 . C. o_m. . e I. .n t. a_ ..n. g . . . - _ . . _ _ _
= _ _ _ . _ -.(.-._.. . 4 _,. ..__-0-- ....
!O TOTAL,(6 - 9) '
._ .20- _1na.. n0.__7 ACCtft;ulf.Tt:0 DI-:PRECIATION
.(ACCT 8- 103,,,101,_1IJ0),
1 Productlon: Steem 408 2 Nuclear 408 3 Ilydro-Convent ional 408 % llydro-Pomp. S Lor. 408 5 Internal Comte. 408 Total. Production 408 - Transmission 408 - > Distribution 408 . General, Connon, etc. (Sch.A-2) ( ) -
. _ . TOfAI. .(ll 20) . ..._ _.. . _ _ . - _ _ _
d.. .
- -.gg ;; .. 3.g i
e
A-2 LIMITED TERM POWER SERVICE SCHEDULE Company General, Common, Intangible Plant Allocation 88 of
? age !
t j dil Description Reference }l Total ?roduction transmission Other (. . . _ __ (1) (2) (3) (4) Plant l FPC 1
' General Plant 'P.403 i 2 Co non plant (elec. portion? f r ,
- P.3518 l 1
i i 3 Intanetble olant (elec. portion) IP.401 ! I t ' i 4 , Total (Ins. 1-3) ! l 5
,A1 locate on basis of Line 19 below Dooreciation Reserve FPC 1 !
6 General P 408 l ! ! 7 ! Common P.351B ! i
- 3 Total (Ins. 6-7) -
9 l Allocate on basis of l Line 19 belev i l } i Non-Decreciable or Clearing
' Account Deoreciable Plant FPC 1 10 Auto and trucks P.403 ii Other Gen.Non-Depr. P.403 12 fCarrnonNon-Depr. 'P351B l i) !Other, if any 1 l la .
I Total (Ins. 10-13) [ 15 ! Allocate on basis of j j i
! Line 19 below l l 1 ; j _ __ : *! *i i !
I ! l i ! 4 - ! 1 i . Allocation 3 asia-Electric O&M i PPC 1 i I
; Salaries Other Than AAC l '?355 i En.25 i 1
l Ln. 19 { . Ln. 20 I'; 25-(19&20Yi
- 15. Total 0 & M S_alaries ! I 17 , Less A & G (FFC 1, P355, in.24) l Cr- ~) - +
18 5alance ' i, - i ! . , le 7. of Total - La lo ; 100.007 : . 7.! . 7.! . 7;
+ L'se- on Schedule B , Col. 2 Lines 7 .ind 10. ' I - '
A-1 LIMITED TERM POWER SERVICE SCHEDULE Company Transmission Plant As of _ _ , _ , - .. Line Description l (1) (2) jPlant Investment l
. : Balance (Sch. Al, in.1, Col.5)
}, ,' f, 2
,La.ssNon-selkTransmissionj?lant ( 7.)
3 i , 3 3ulk Transmission (Ln.1 ILn. 2) i i i '
- Plant currently beikg shared bh for:ner CA}VA l>
Pool members under termir.ationagredment l (attach listing as A-3-al
,' Former' members ' applicable 5
percent 7 9 - Less former members ' portion (Ln.4 x !.n,5) 7 ; Gross bulk Transmission Plc nt (Ln.3-Ln.6) 1 l 8 l 3ulk Transmission 7. (Ln.7 + Ln .1 ) (XX .>7.) 7. i b i e i i
; Depreciation Reserve i
9 . Balance from Sch. Apl, Ln. 18, Col.5
!0 f
Less Non-bulk Transmission Reserve ( 7. ) I 1 i 3ulk Transmission (Ln.9 - I!n.10) j I i 12 [AccumulatedReserveapplic4ble to investment on Ln.4 above (Sch. A-3-t) 13 !Former members' applicable percent 7. I 14 l Less -Former members portien ' (Ln.12 x. Ln.13) i i 15 IBulk Depreciation Reserve fin, 11 - Ln. 14) I
}
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< i s s
- - ' I ,3
! ! l !
i t I
LIMITED TERT 1 POWER SERVICE SCllEDULE A - f. Company Materials and Supplies (Excluding Fuel) Date n . .m a c uwmoet.aucomxc.wr
- Ti n.:e . s. 1. nne.u .rw._u:wumcim seference o; mur-u r v. u.a-u - _- - w.a.eu-c., u c .e u--
linrehouse Location or - .u .eu awas w = No. Class of Material illocation Production Transmissi( n Other l'o t a l (1) (2) (3) (4) I ! i 2 3 4 . 5 6 7 8. 10 11 12 13 14 15 16 Total Account 154 FPC P207 I7 11erchandi se - Acct . 155 FPC P207 18 Total (16 a 17) . 19 % of Total - 1.ine 18 7. *4 7. 100.00*/ 20 Stores Expense (163) (Line 19)
'21 Total (18 + 20) 22 "4 11olk Transmission (A-3) 7.
23 1:uik Transiilssion
. j . _ . . _ . . . _ _ . . . . . _ . . ..___. . . . . . _ _ _ _ . . _ - _ . _ ___ _ _ _ . . _ . _ . _ _ _ _ _ _ . _ . . . _. . . _ . . . _ . . . . . .. . _
l e I l
LIMITED TERM POWER SERVICE SCHEDULE A_3 Company Fuel S tock As of I** . ._ . -- Line ! Description l Suopiv Amount lSteamPlants - Name: (1) (2) i 2 , 3 ! l e, 1 a , 9 10 l 11 ; Total - Tons Coal 12 ' Average System Price ($ on)* 13 Amount - Coal (Ln.11 x Ln. 12) I
. Normal Oil l
!upply S (Bbis)
I 14 l L5 l 16 e 17 Total Bbis. Oil - Steam Plants I le Average System Price ($/Bbk) * ! k 19 Amount - Oil - Steam Plsnes (17 x 18) Other Production: (Use St rage Capac.ty) 20 ! l 21 ! I 22 l 23 ! l 24 ! 25 l i _ 26 ! i 27 ; Total - 3 bis. Oil - Othe'r Prod. I { ! ! l 23 , Average System Price ($!B 1)* ! I
. , I 29 Amount - 011 - Oth.Produ;ction (27x A3) { >
, . I -
i 33 Tota l Fue l S tock (Lns . 13 t 19 + 29) 4 t I I 4
*llse year-end average for ' calendar year studies jor previous month's ayerage wheni revised for addition of new generattng unit. ! : i l l l ! i I
A-6 LIMITED TERM POWER SERVICE SCHEDULE
, Company Working Capleal n -
ra 3.-.- Year .
._ _ __ _ . _ _ _ . _ ___..,_m... -
_-_m _ Ltne Descriotion l l l Total hroductionbransmissicn Otter i !
--_y.__ -
i I (1) (2) (3) l (4 ) i 1 Minimum Sank dalances: , j {, 2 Allocat
- on % (A1, Col .o) ,' 100.007. g . . 7. . 4
' ]
3 Allocated a:.ounts (Ln.2 x' Total) 3 i 4 Bulk Trans.*/. (A3, Ln. 3) l l !
- I i 5 t Bulk Trans. Amount (Ln.3 xi Ln.4) l t '
{
-1/8 Annual Goerating Expense f I I 6 i Production-FPC 1, page 418, Ln.27) ?
Transmission,FPC 1. P . 418 En.471 l l ' d a Distribution,FPC 1, P.419 Ln.18 ' [ i { i . 9 Customer Accounts, FPC 1, . 419,Ln.25) ' f i 10 , Sales FPC 1 1 419, Ln.35 ! I L1 l A6C FPC 1, P.419, Ln.53 t
! Allocated on basis of A2, Ln.18 12 j Total O&M,FPC 1, P. 41 9, Ln.54 l l I 13 l Less purchased pcwer, P.418, Ln.23 )( ) l i i i(
14 i s. Totals (Ln.12'- Ln.13) i
- i i 15 1/6 of Line 14 totals I ! l !
[6 Bulk Trans .7. (A3, Ln.8) I f i, e i7 i Bulk Trans. Amount i f
.l
;i l
i l l l 1
} !
Federal Income Tax Of fset: i '6 l i Provision for Current Fed . i ; Electric Income Tax ! i l (FPC 1, p. 114 , Ln . 12) I ! ! l
- / !
l Percent Offset * *4} I j 1 l .1 Offset Amount ( Ln.16 x LnL 17) i i r 9 i .
, , i Allocat ton 7 (A1, Col.6) 4100.007 -
L' 7, f
. . . ; l l 0. .
. Allocated Amounts (Ln.19 x Total) l - l ' I
\
l
- 1 3uik Trans.7. (A-3, Ln.S) ' ! j f 74 !
- 2 Bulk Trana. Amount (Ln.20 x Ln.21) l I '
l
- ! l ,l-6 i i t i i
- Of feet 7. will vary as agreed upon, i I
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F LIMITED TEkN P(NER SERVICE SCilEDULE A-i Company Cornpos i t e Cos t of Capttal As of n a uw r.->.s_c um-mnarva.ox:-naca 2m.xaw~ ~ -v - rnuuum.1 wa ..~ ,
.w w m u a.a u , w.u 1.a u..:..gz ys.a s.,m 4ms 3.N.o. - DescriEtion Ca gi t. a l ization C
-~ _ _ Cost -of Capit al -
m_ _ .ost- ---- _m._r . as of Arnoun t 1 Total Re fe rence 1 (2) x (4) l (1) (2) (3) (4) (5) 1 Long-Term Debt . A-8-1 Line 20, Col. 7 . . 1 ,2 Preferred Stock . A-8-2 Line 11, Col. 7 . . .3 Cotn.wn Er;u i t y . A-8-2 Line 16, Col. 7 . . 4 T(YrAI. 100.00 1 -
. 1 *
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. _ _ . . . . _ . . . - _ _ . . . . . _ . _ . _ , . _ _ _ _ _ . . . _ _ , _ _ . . _ _ _ . . . . . _ . - _ _ . . . . . . _ - _ . . . . . - ~ _ _ _ - .. -
h
LIMITED TERM POWER SERVICE SCllEDUI.E A-S-l Company Cost of Debt Capital as of smun._w w.- m - s=.- - ,m_- m --_ Dehn_Disti _,_.. m _ m.,., _ . m , , I. i ne . Prioci & Exp. or Net ,,,.,. ,___ _ ,,, Coupon Net _ Cost _ ,mf _Outstandin; Annua 1 w pp,s -... S ri _.- ,e, a,e s ---- -- ..- - _ Issueba1- - - . -.P r_ e m ,_- N e t . Pr oc e e. d.. s . . - Ra e . to Company _'a s of - Cost ! First and Refunding Mortgagre Honds: X . XXX7, 1 2 _ _1_ .. . _ _ . _ . _. ___ _ 4 5 6 7 8 9 10 11 12 11. 14 15 16 Sinking Fund Debentures: 17 . . _ _ _ 18 J 19 Total 1,ong-Term Debt l 1 i yo Weighted Average Cos : (I.i ne 19, Col. 7/1.ine 19, Col. 6 - to 3 decimals) 9 i
... ._. . . . . . . - . _ _ . . . . _ - . . _ . . _ _ _ _ . . _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ . _ _ . . _ _. . _ _ _ _ . . _ _ . . . . . . . . . _ _ _ _ _ . _ - . _ _ _ . _ . . . ._.i_
e
. . ~ . - . . . - - _ _ . - . - . . - .- - - .
I.lMITED TEft$1 PWER SERVICE SCitEDUIE A-5-2 Company Embedded Cost of Preferred and Three Year Average Conanon Equity . .:.= :--xym - u -, < m e s. n n, e--r- . . m~ :sm - , , - = ::ww.. a-an ~1 a.a w. n a-~ ,-u.~e- ma=- e- s v " + " c " = ~ I.i ne - m -~~-M u Emisedded Cost of Principal Ex g,c o. e Net Dividend Net Cost Ou t s t a n.li nq l Annual
. ..N g ,. ,, ,.,, Prt f erred Serles Issued ,, j3Li s p i.i,g_. j'ipyct3,$, 1
_ lQtf _ (3 h gT3ny. y;i., qfy _ ,,,,_ . mC1M.L __ (_ (1). _(2),_ _(,4 (6) .) Pteference Stock: X.XXX7 I 2 3 .- . . . . . . . - - - . - - - - . _ __ _ _ _ _ Preferred Stock: 4 5 6
. . 7. . . . . . ...... . . .. -
L 8 9
. - . _ -- __ _ _ . _ - . . . .- a 10 Yot el Ps efca s ed Serico ,
.l.
I-
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1I 1.'c 1 g1,1 ei Av a et'.( Cost i I.ine 10,00 7 /1.f ine 10 Col. 6,to P/. decimais > . */
- - e.u a su..
..g P'110 ec Yor.4 r / ve 8 6rc Cowiion I gulty Cost
.i... .<
5 13.11Y_4V3IMS. Gye2it Eculty
][er_ r Ite ret ence A. .ou n t Earnine,c,*
- 12 19_ , A-8-3 13 19 4-8-3 - . . . . . . - . - . . . - . . - - . . -.--.... - .. . - . . . - 14 19,_ A-8-3 IS To rAl.s 16 t!c igter e,I Ave s .3;e Cos t .(l.i ng 15, Col ,4 /l ii g* lL Cn!; 2,J o_ 3 ._d s c itna lu ).. _ _ _ . . . . _ . .. . ..
, . . , 7* -- --
- A ra gr Pre f er red Divi. lends an.I ExcInsi.ve of Extr,ordinarv I l eins
LIMITED TERM PCMER SERVICE SCHEDUII A-6-) Company Daily Weighted Average Co:cton Equity 1 I bi"*
! ! l Reference 19 19 19 l
1 Coc:non Equity - End of yeaq , por:. 1,p.111 i
' Con:non Equity - 3eginning of year 2 i 7or:n 1,p.111 l 3 ,
1 l Increase (Decrease) ! i i i ii ! 4 Less public sale net proceeds ' ' ' } 5 { Public sale date i -
' .' I 6 )Normalchange (In. 3 - In.44) 1 e { !
i . 7 i 1 fOne-halfofnormalchange i i d507. In. 6) I I d j Daily pro-rata share of lige 4 for j no. o f days outstanding d /365 x!Ln. 4) 9
; Average Daily Con non Equity (Ins. 2 t- 7 + 3) I ! I 1
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14 LIMITED TEIGi POWER SERVICE SCllEDUI.E __. Cotupany Annualized Depreciation Expenses as of
- ~. .z . r = : . : , . n - c = . = .; r: z_ n ;=. e =c. m = re r_ x n =, -% =. - , = ~ . _ _ w.m= r, c r ;. /,.--, =. .-,.- .. n.x. m.., .. . .. . e ,
tine Description Plant Less Depre- Weir,hted Annualized ~n .
,. . . . . a. ,. - .=. .. . _ . - , , . . . , , , _ , , v,......- . . ~ .
.-.n. .,o, , , , . . , - . . . . n a.~. . - . . , , . . .
Original Non-Depre- ciable Composite Depreciati >n . Cost ciable Amount Annual Expense Balance Amounts Rate (Form 1 (A1, col.3) * (1) - (2) P. 429 (3) x (4) Froduction Plant: (1) (2) (3) (4) (5) 1 Steam 2 Nuclear 3 Ilyd ro - 4 Ilyd ro - 5 Otlier Prod. - 6 Other Prod. - 7 Gener a l , Comu.on , e tc . Allocated to Prod. (Ente: Col.1 froo A2, In.5, col.2) __ . . 8 To t e 1 Prod , _ (S.u..m ,_.C..o. I . d. ) _ _ ..,,0_._ . . --_ .
. . - 0 . . .m .x.,.m..m,, . g _a, m_ m u _am, Transmission Plant:
9 Plcut Cost (A-1, Col .3 , Ln. 7) 10 General, Cou non, etc . Allocat ed to Trans. (Enter Col .1 f rom A2, Ln 5, col.3) _ _ , _ _ _ _ . _ , , 'l l Total Trano. (Sum. C il.5) - _ _ _ m._.. (L _ __ _ _ _ . 0_- _ __ .. -_pm -
.. .. . J _-m ,m _ .., m ____
B2 Itulk Treins .7. (Sch. A-3) ....k 33 lioll: Trans. Ainouat [Ln. 11 x 1. i. 12) sec.: .- u rot line, 7 an,I 10, tir . non-dc pr. ironi Sch. 12 Line 14 . e i
a: LIMITED TERM POWER SERVICE SCHEDULE i l Company Income Taxes me --- __ Year Line l Production i Ttansmis s ion l Nn. I f (1) (2) 1
, Return on investment (Sch. A) 2 Less: Interes t on Long Tern Debt
__ _ Sch.A,( line 10 times Sch.A-8, linet 1, Col.5) I 3 Balance for equity earningo i 4 I Combined Federal & State income tax factor (1) "4 l l 5 Total income taxes, before Sch. M adjestments (4 kimes 3) I l 6 Gross taxable income (line 3 plus lino 5) Add or (Deduct) l l U 7 Difference between book and tax depreciation (Sch. C-1) 8 Difference between book and tax nue:, ear fuel amortization
,9 Adjusted taxable income fot Federal & State income tax 10 Composite Federal & State j ncome tax race (b) .
11 Income taxes (10 times 9) (1) Calculation of tax fac.cor: f I 100.000% Tax factor = (b) = 100 - ib) Less: State rate
- ()
I Federal ( *x (t) ) , i , .
! Add: State rate i !
CompositeFederal&Stdterate (b)
! i !
!* Federal Tax Race. I i l [
l i i > {
LlHITED TElef POWER SERVICE SCREDULE C-1 COMPANY Calculation of Difference Between Book and Tax Depreciation ne ennemrtc : s.u-r.cr.e cmr .:r_-r,: _:r gg.w_qg-gg - - u cxxwm wn::cm.2 r m sm, r -m arm a..v.nv .u.na 1 i ne- .. v . .n-.
..- Des,. c r iqu on Depreciat.ioii Plant Tax Base lieprecial 1e Tax
~ , . , - - . . - . - - - , nu - - - -
Tax Difference Isch.D. Col.4) Col.3) udjustment Tax Base Rate 1,preciationi (2) - (3.) (4) x (5) (1) - (6) Product. ion Plant (1) (2) (3) (4) (5) (6) (7) 1 S t ear. 2 Nuclesr 3 Ilydro 4 Ilydro 5 Other Prod. 6 Ottier Prod. 7 Genes a 1. Coasaon, etc. Allocated to Paod. 8 Total Prod.(Sum. Col.9) Trainnuiscion Plant: _ . - ~. . mm. m 9 Plcut Cost 10 Cer.ci el , Com.aan, etc. Allocated to Trans. _ ~ . 11 Tot al Trans . (Suro. Co .5) 12 I;ull. Trans.41ss ion *l. (Sch. A-3)
- _i 13 Iulk Trrnr.Ldssion Amount ( .n.11 x Ln.(2)
>da.. ew we w g.y.em.t we.atm.we p W ogeh-A.% 9 M# M @.Wh 6 h wm .
.. #. ..m .. _e
..m. _, ao= * -
*"*** hap.N aW W N* -
. LIMITED TERM PCWER SERVICE SCliEDULE Company PROPERTY TAXES YEAR Linel Description f '
Production T ansmission (1) (2) i I i ; Local Property Taxes (Sc h . D-1) l l l ' i I i i 1 2 IS,C. Franchise Tax (Sch. 3-2) l ! I 3 Other, if any (explain) I 4 Total (Ln. 1 + 2) - 1 5 Transmission Bulk Pcreent (A-3, Ln.8)
'l 6 lBulkTransmissionAmount ($n, 4 x 5)
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t>- s LIMITED TERM PCWER SEAVICE SCliEDULE Cocupany Local Property Taxes
. : w r ,-- - . _m_m - _ _ _ _
! I I i
i i l I (u 1 Previous Year Taxes Assessed ( Fo nn 1, page 352) ! 3
;LessAmountApplicableto} reduction nits l (S c h. D-1-a , Ln. 19) l 3 l
3
! Balance Taxes Applicable ed' all other g(?lan'; ! I Cross Plant Beeinnine of ? devious Years ,
i ! 4 Electric (FPC 1, P. 403, Ln. 88) I 5 Add Comon (FPC 1, P. 3: 1) l 6
', Deduct Production (FPC 1, P.402, Ld.42) (
7 Balance non-prod. ( I s.4+5- 6) A
. E f fec t ive prev. year non-W od, rate (Ln.3 + Ln.7 .XX'CCC{
Current Year Taxes: ' i Production Plant: i 9 j Previous year taxes (Ln , 2 above) J i Add (deduct) Estimated Taxes for I - I, 1 Production Plant addit:.ons and re ;irement last year (C-1-a, Ln. 2.7) l l 11 Add General - Conunon al .ocation (Sch. A1, col.4, Ln. 6 x Line 8 above) 12 i Total Production, current year i I fTransmissi. Plant: 13 t Plant in service beginnL,nd of curr/ int year (A1, col .1, Ia. 7) 14 Add General - Ccemon al",ocation _ (Al, col.4, Ln.7) t 15 Total (Ln. 13 + L,4) i k i i 16 iTransmission Taxes Current Year I (Ln.15 x Ln. M rate) i, { i - l 1 l l .- = ... - l- .f l I
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l l LIMITED TERM PCMER SERVICE SCiiEDITLE D.1.a t Company l PRODUCTION PLuiT LOCAL PROPERTY TAXES YEAR 1.i n e Plant Name f Type l County l l al l Race l Tax Plant j (Mills per
' ' S-Steam $1)
N-Nuc
! Plants Taxes M-Hydro g .(3) X (45
?revious Year 0-Other ! (1) !
(2) ! (3) (4) 1 i l ! ! I i 2 j l 3 1 l 5 > l 7 ' l l s i i 9 . 10 l ' 1 I 11 I l 12 .I 13 , f 1 14 ' l
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15 ;
)
' 1 16 17 {. ,
13 l l 19 i Total previous calendar year taxes (Sbm.1- 18) :i l l ! l l
! Annualized Tax on Units Added or Recit.,.a:
l 20 l l 21 l 22 l, 23 i 24 ; t 25 ! t l I t l 26 3 I1 I I I 27 ;
. Total annual taxes on plan,t changes ($um. 20-26's , ! l
; ,- 1
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LIMITED TEF.M POWER SERVICE SCHEDULE D-2 South Carolina Franchise Tax (True Value) Year .:= m --
- - - - - - ~ ~ - - - - ~ - - - - -- - - ~~
f l l l i Total Franchise-Electric pepartment-{er Company Records I Assessment - Production Plants in S .C. l t
; Assessmen:
Stean , j$ l
. , i . I i 1 '
! l l i
l i Hydro l l
\ <
l l i i i Internal Combustion Turbiites l I i ! 2 Total Assessment !S + 42x100=S , 3 l Tax G S.003-Applicable to! YearEndPfoduction h l 4, Annualized Tax on Units added or retkred: l Total Assessment 2 + 42x100x$.'003-$ ,i l i : 5 Taxes Applicable to Total Production in South L.:rolina (3+4) 3 t ! , e Taxes Applicable to All Opher Utility Plant inj3.C.(Line 1,- 3) ,$ I l 7i Summary - .kilocation
! Taxes Applicable to: Amount o'f Gen .Pl c . i Total l
{ TA-1, col.o) i ' { i 1*roduction (Line 5) $ 7 li
! Tr a ns mi r.s ion (1) ;
( l . I Distribution (1) I f i e i l 1 e General (1) l , :( ) ' i
}-__ __- - .-
(1); AllocationbasedonPlantfInvestment;(A-1, Col.,1): j ; {
?lant Inves . I l Allbcation ,
i (A-1, Col.1) I, of Total' ofTcx'2s(1.ir.e6h f; Transmission , ! Distribution : I ! I General Plant , I f j
.t . e a
LIMITED TERM POWER SERVICE SCHEDULE Company ANNUAL INSURANCE YEAR _ _ , - _ . , - - - m .- m._. f.ine bescription l (1) l (2) (3) I' I 1 Tota;InsurancePreviousYbar(Accc.9h4,FPC1,P419) I Acet. f 924 i i 2 , Add (deduct) amount necessary to annualize i I for addition or retirement of generating unit i. 3 ; Total Insurance Curr nt Year i i l f Allocation of Ln.3 total (kxplain l Allocation Basis Below if hot l Directly Assignable): Production a*ransmission Other Tots: 4 ; Fire and extended coverage 5
- Moller and machinery o Nuclear liability
; Other:
I I 6 l \ f 9 ; l l 10 f l 11 ' ' 12 l l 13 i 14 l l f ) 15 Total - Per Ln.3 ! 16 Hulk Transmission Percent I % 17 i Bulk Transmission Amount i l Explanation of Allocation Bases: Line No. Expl nation
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LIMITED TERM PbWER SERVICE SCREDULE Company Transmission Operating and Maintenance Expense Year Line j J g. ! _ _ Amount l 1 19_ Expense (Form 1, p. 418, line 47) I. l
!2 I Add 7. f o r A & G , pa yroll taxe's , e t c .
I _ . _ _ , __. (Schedul'e III a) l '
! l 3 ; Total g e i 7. applicable to b . ilk power ,
(A-3, col. 7 7.) ! i i 1 5 Transmission expense appli :abletobufkpower __ I i I I l I I I ! l I i i
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LIMITED TERM PtN*ER SERVICE SCHEDUU c Company Net Continuous Plant Capability As of Page of
. . .. . . ..,_...__,_,._.__..._..._,_.,.m.,_,,,,m,,_.. ...
1,ine P.eference Nuclear i Steam Other Prod. Hydro Total No. Plant Ra;ne ,,_ l . ( Q_ , , ,,
.(2) , l. ,,, O j ,,[_ g _ ,,, ., _, Q]_ , ,,,
(6) , 1 Re ference .FPC Fom 1 P432 -L10 432 -L10 h432 - L 5 .P433 - L10 s . 2 t i ! 3 l 1 I f ;
, t :, 1 5
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! 10 I il Total Production Capability, ' 62 Long-term firm purchase: Frcm
;3 .. .. .. ..
y , , 4 Total Trans. W(L31 + L33) i --
~~ - _.
i A l> P E Ni>lX C SEitVICE SCHEDULE SJ10RT TEltM POWEll AND ENEltGY SECTION 1 - UtiltATION 1.1 Th:A service schedule, a nart ci and under :.n agreemer.t dated
._ _he : twe e t! _
_and _ . . . _ . . - . _ _ _ _ . . . . . . . SI"'ll necorne ef fec.u ve Septe nher 1, 1970. and shall continue in effect to the expir: tion of an initial period ending April 30,1973, and thereafter until terminated as provided ;or in Section 1. 2 below.
- 1. 2 Either party upon at least three years prior written notice may terminate this schedule at the expiration of said initial period or thereafter.
SECTION 2 - SERVICES TO BE RENDERED 2,1 may arrange to reserve from _. , and' may arrange to reserve from , for one or more calendar weeks or for the balance of any calendar week, electric power ("Short Term Power"). whenever, in the sole judgment of the party requested to reserve the aame, such power is available. 4 2.11 Prior to each reservation of Short Term Power,
'the number of' kilowatts to be reserved and the l
period of the reservatica .shai' be determined by ! the parties. Such determinetton shall be confirmed in writing, if during such pe. !od condition.s a rise
~
.that could not have acca reasonably foreseen at the
, time of the reservatior. and cause the reserva-tion to be burdensome to the supplying party, such party may be written notice to the reserving party, or oral notice later confirmed in writing, recuce the r.umcer of :Cowatts to be reserved by i
such amount anc for surh time as it shall specify in such notice. 2.12 During eacn period that Short Term Power has been reserved, the party that has agreed to supply
- such power shall upon call provide operating capacity ("Short Term Ooerating Cacacity") of up to and including the number of kilowatts then reserved and deliver electric energy ("Short Term Enerty") to the reserving party at an average rate curing each hour of up to and including such number.
i SECTION 3 - COMPENSATION 3.1 The reserving party shall pay the supplying party 3.11 Demand Charge 35c_ for each week times the number of kilowatts reserved for that week or 7c per day or part thereof l that Short Term Power is reserved times the number i of kilowatts reserved for that day. If the supplying
. party reduces the numoer of kilowatts of capacity in accordance with Saction 3.11, the supplying party 2.
will adjust the cemand charge to the receiving party at the rate of 70 per kilowatt per day. 3.12 110% of the calculated average production cost of the highest cost generating units being used to procuce the energy required to make the delivery. 1 3.13 In the event either party obtains Short Term t Power from a third party for re-transmittal to a receiving ps.rty under this Schedule, the demand , charge to the receiving party will be that charged by the third party. The energy charge will be the rate per KWH paid to the third party plus 10% the reof. 3.14 1 The losses associated with the transmission of capacity and energy under this agreement. either on the system of the supplying party, or on the system of a third party which may be supplying Short Term Power to the supplying party hereunder for resale to the receiving party, will be borne by the' receiving party. . Compensation for such losses will be accomplished by scheculing coincidental
- delivery of loss compensation.
t
A l'I'!:Ni n e la SEllVICE SCHEDULE SPINNING RESERVE W SECTION 1 - DURATION
- 1. 1 This service sch. dule, a part of and under an agreement dated i
hetween and
, shall becomo effectiv( Septemlier 1, 1970, and shall continue in effect to the expiration of an initial period I
ending April 30, 1973, and thereafter until terminate.d as provided for in Section 1. 2 below.
- 1. 2 Either party upon at : cast three years prior written notice may 3 terminate this schedule at the expiration of said initial period or thereafter.
i SECTION 2 - DEFINITION Spinning Heserve is defined as the sum of (i) the unloaded generating i capacity resources of a Company which are connected and ready to supply power upon demand, (ii) generating capacity which can be started and made available within 10 minutes, and (iii) generating capacity which can be made available within 10 minutes by appropriate interruptible or other contracts. Generating capacity which is a part of Spinning Reserve must be available indefinitely. Hydro capacity will be included only to the extent it can deliver its capacity until a steam unit can be started to replace it and only.if such a steam unit is available. Standing Combustion Turbines will be i classified au spinning reserve i ., ~ tile ame.unt ci generation which can be ' produced in 10 minutes. 1
During the first 24 hours following the loss of generating capacity, the capacity lost shall be considered a part of the owning company's Sptoning Reserve Commitment. Similarly, emergency assistance bing rendered a third party system for a pers d of 24 houra following the beginning of a period of delivery shall be considerec as part of a company's total Spinning Reserve Commitment. SECTION 3 - SERVICES TO BE RENDERED 3.1 It is recognized that service reliability will be improved when the reserves of two systems are available to backstand the loss of large generating units and also that significant operating savings will result from two systems each sharing in the spinning reserve of the other. Each of the parties will, therefore, maintain spinning reserve capacity each day in the amount of the sum of (1) 8 percent of the largest unit in operation on the respective systems and (2) 4 percent of the estimated annual peak load, except as may be amended by the Operating Committee, such total in each system to be known as each system's Spinning Reserve Commitment. Following the emergency loss of generating capacity on a system, that system will first utilize its own Spinning Reserve Commitment to replace the capacity lost ex :ept as may otherwise be agreed upon and may then call upon the other system to make available the additional capacity required to I replace the capacity lost, up to the amount of its Spinning Reserve Commit-ment and capacity available from third party systems, provided that the supplying system is not suffering an emergency of its own or is not supplying. emergency assistance to a third party system. 2
1 i 4, j _ .5. .: In the event of extreme emergenetc.s, eaen . system w.1. ..u ke available to the other total available reserve capacity on its system and will attempt to obtain capacity and/or energy from third party systems as l ] .
- required.
1
- 3. 3 From time to nme it may be =cre econom; cal for either system to purchase capacity to supply a portion of i:s Spinn:ng Reserve Commit-4 ment rather than supply it from its own resources; then in the amounts and 1
j for the period agreed upon the other system will make available such capacity. , SECTION 4- RATES AND CHARGES 4.1 Should a company request delivery of all or part of the Spinning Reserve Commitment in Section 3.1 and 3. 2 the amount of energy delivered will be charged as follows: When energy delivered hereunder (during the first 24 hours following i
- an emergency) is generated on the system of the supplying party, the receiving party will pay for such energy at a rate per KWH equal to the calculated average productic ' cost of the highest cost generating units being used to produce the energy required to make the delivery plus 10 percent or at the option of supplying party make return in. kind. Should the party suffering the outage require assistance for more than 24 hours, then after the 24-hour period it will purchase available capacity necessary to carry its load and, to the extent that it is available, capacity to restore its Spinning Reserve to normal, for the perioc of the emergency, or for one week, ..whichever period is shorter, 2: :he rate specifice in Paragraph 4. 3 below. Should the period of the cmergency ex:end beyond :he ini:ial 24.
r 9
, -e, -
hours and the succeemng seven days anti the party suffering the emergency continue to require assistance, it may purchase available power for the remainder of the emergency under provision of Service Schedule "Short Term Power and Energy". *
- 4. 2 For the capacity in 3.1 anc 3. 2, purchased from a third party system for celivery to the system suffering an emergency, the receiving company will compensate the delivering company for the cost of the third party capaci:v. Compensation for energy associa.ed with such capacity wtil be cost plus 10 percent.
- 4. 3 Compensation for capacity made available under Section 3. 3 will be at a rate of $0. 03 per KW day. If it is necessary for the supplying company to start a unit in order to supply this capacity, then at the option of the supplying company the receiving company will be required to purchase energy in the amount of the minimum output of the unit started for this purpose, at a rate equal to the calculated cost of producing this energy, including starting and incremental maintenance costs plus 10 percert.
- 4. 4 The' transmission losses associated witn the transmission of capacity and energy under this agreement, either on the system of the supplying party or on the system of a third party which may be_ supplying Spinning Reserve Power to the supplying party hereunder for resale to the receiving party, will be borne by the receiving party. Compensation for losses will be accomplished by scheduling ccincicental celivery of loss compensation.
- 4. 5 Where applicable, taxes will be added to tne bnlings under .
4.
- 4.1, 4. 2, and 4. 3 including but not limited to:
Support 'of South Carolina Public Service Commission South Carolina Gross Receipts Tax South Carolina Generation Tax North Carolina Gross Receipts Tax Any new or additional applicable taxes enacted after the date of this Service Schedule shall be included in billings under this Service Schedule, f 4 I I
)
l 4 J
- _ .% - , __ , ~ _ , . , ,-. 7 , o . . . - . , , - -
SUMMARY
- ENGINEEPING AND LEGAL REPORTS i:2
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PROPOSED - k NORTH CAROLINA f.'UNICIPAL AND COOPERATIVE STATEWIDE POWER SUPPLY PLAN .
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Alton G. MurchLaon Auguat 9, 1969 - r:l"et riCi*. ien of ? orth Carolina F ay e t. '. e v il : c , !! . C. FOli IV.M801 ATF ,,QELEASE SOUT'P.7. - P l:: E. h - y . y.; r J . Jarner Ha.;nal, of Statenville, was re-e]ected president of :lectriCities of Jorth Caroli.n2 at the annual meeting of the organi::aticr. . ere Feldsy and immediately called for all-out support of action to implement a $1 billion statewide t;er,uration and transmission project to provide the long-range power needs of Tarheel cities and rural cooperatives. Members of the acscciation approved a resolution that would certify the mammoth venture as both " desirable ar.d feasible," recommending the matter be submitted to the governing boards of I member cities to proceed with the next phane. This would require authorization of detailed engineering, ler,a1 and financial plans for actual construction of the proj ect. The stetewide power project would serve electric distribution systems in approximately 70 Tarheel urban communities and 36 rural cooperatives representing a present population in excess of two million people. i The long-range savings for the_ ten year period 1975-1985 are 1 l . l estimated to be as much as $100 million. For the fifteen year period 1975-1990, comparable estimated savings may exceed $250 millien. Action on thia nonumental undertaking, formally labeled EPIC, l short for Electric Power in Carolina /Cition and Cooperatives, followed the presentation of engineering and legal reports on the Joint Power Study, which 21ectricities and the North Carolina Electric Membarship Corporation ordered a year ago. (mcre)
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Similar conr. irk Pr t' ion will b'; r,1 ven to the proj.:c t ny t he IJ': iMC at i t '. meeting in Raleigh next wuck. First Of Its Kind According to 'ayor Bagnal, EPIC is the "first joins power supnly system ever put to[, ether for c.n entirc stat- " Reports 'subniit ted 'b'y the organicat ion ' local counsel and consulting engineers found the combined laa is of the municipals and co-ops, proj ected through 1990, large enough to take full advantage of the upper limits of present scale and technology in the pouer industry. Robert W. Bathen, representing R. W. Beck & Associates of i ' Orlando, Florida, made the presentation for the engince ring studies. I The legal phases of the project were presented by J. O. Tally, Jr., of Tally, Tally & Lewis of Fayetteville, general counsel for ElectriCities. They were joined in the presentations 1,y T. Foley Treadway, of Southern En61 ncering Comoany of Georgia, and William T. Crisp, of Crisp, Twiggs & Wells of Raleigh, consultants for NC EMC. , i
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Make Up Of EPIC 1
"The proj ect ," said Mayor Bagnal, " includes a statewide network i l
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e Proj e c t. Cost Estimated cost of the cor pleted yc em 1 :, in excess of 31 billion . The cost to construct, or tne capital cost of all generation and transmissicn facilities, will not require exp'nditures by any or all of the cities or cc -opa One hundred per c;it of auch cost will be provided by two sources:
- 1. Revenue bcnds, issued in respectiv and prope clonate amounts, simultaneously, by the cities; and
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"Mu f fic i e n t. fl.:xil :ty ha. b'en incorporated int.o the p]: inn i ng to it.. :r, rate all exi:: ting generation and transmission owned by potenttal partieit. ant.:," caj d "ayor 13ar:nal .
A'.onc the way, approvals and licensing procedures by thc varioua Federal ar.d State reculatcry bourda will need to be obtained. Other Feotures Other features of EPIC provide that... All generation and transmission will be operated by a statewide non-profit corparution whose officials will be democratically and proportiunately designated by citics and co-ops. ; I
--Distribution will be operated individually and retail distribution rates will continue to be set by the respective cities and co-ops. '
--The wholesalo rates wh'ich all cities and co-ops pay for buli<
power, af ter beinr; structured by good and uniform utility business practices for 1 carl factors and the like, wil't be uniform. Other Business Other business of the meeting given over primarily to the prec '.tation and discussion of EPIC included the adoption of an operating budget for Electricities for the next fiscal year and the naming of several comnittees. Elected along with President Bagnal was Mayor Simon Sitterson, Jr., of Kinstan, vice president. David Taylor, city ::anager of Tarboro, who wac re-elected secretary-treasurer, and R- A. Muonch, Jr., cf Fayctteville, immediate pant president, round ou' *ne cfficers. M;cnch it alsc chair ~.an of tan Power Sappiv Committet whic- ha' c oO:'d ina', t'd t hi c movt':"000 since l';; begi:inf nt".
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F.a.v o r o f 3 h e ! b.'.' . and L. C. ' 'il l i m- ; , J1rcetcr of public utJ11rir e o r lii r,h Poi n t . t Mayor Willia" L o n t,2 , 0.# Lincolnton, and Mayor 2. B. Pi t t:r.an , of '.iilcon, are se:'ving .he rarnining year of their terms. 9 e
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I t, k I N. . .,e.e- n
TR AN.tih11TT A L, SilhlNIAltY , CONC LUSIONS AND R ECOhth1ENDATIONS
; f ; _ _.Ed fo r " . . . furthe r joint action to construct and operate such system. "
~
. North Ca rc lina
- !L .. F:!cct ric hier.J2e rship Corporation The power supply plan that has evolved from our studies is of such magnitude that it has been appropriately 5c .t:: -' r , , sed No rth Ca rolina hiunicipal sugge sted it be given the ac ronym, "E. P. I. C. ", stand-
- Coope rative St.itewide Powe r ing for Electric Power in Carolina Cities and Coopera-3 ::- 21v Plan - E l'iC.
tive s . The overall plan will, therefore, be refer red to a s EPIC throughout this Repo rt for simplicity. PROJECTED LOADS
- a the Memo rani: am of Ag reement .
- a ., a t 1, 19i. .; between the two The projected combined loads of the hiunicipals in a whic h this Report is .tddres sed, Elect riCities and Cooperatives in NC EhiC a re la rge
..- .. !. ul and .iancial :,tudie s have enough to take full advantage of the uppe r limit s of pre sent
. ;>u : _.u, d ove . :ic past year in un scale and technology in the powe r industry. The coinbined projected loads through 1990 are summarized as follows:
.c r: : n t: t he r e..sibilitf and de si rability Annual Peak Load Annual Energy
- - tetior :nd ope .stion of a n elect ric gen- (htW) (N1Wil) ti s ai:. 3. cm for 1:te purpose of n .t i a 'ou ,, o r t o t hei r re:,1ec tive 1968 1,290 6,2.10,000 tuly :ahli t he s ::,uch
. . si F ty, undert; ke further joint 1970 1,520 7,330,000
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1930 3,410 / 16,510,000
. 1 , a. . : ult: of :- enginee r-ii, ; '
t,c e n c.. :.duc t e.i a nd 1990 7,220 35,120,000 ir .. u.t opi ans this ha s hee i a year ~
~ . . b ' t !: ha- iroduced cufficient re- - - - -
Of the above totals, the municipal sy stem of lectri-nr a rt. w the .. . ult u of ou r Cities represents approximately two-thirds and the
,;c n :d 2 . ir.g recommendation s Cooperative system s one-third. A s shown on the cove r I-l u
t' map the potential participants are spread across the located in the Eastern Region, in the We:, tern Region and length and breadth of North Carolina. The total com- the Central Region, 500 kv transmission lines would . bined load divides roughly 40% in the Western (Piedmont) traverse the State connecting these plants to major load
.R egion, 20S*,. in the Central Region (vicinity of Fayette- ,
ville) and 40"e in the Ea ste rn Region. centers and to a large pumped-storage hydroelectric plantj in the western part of the state having an ultimate in- ! stalled capacity of 2,000 mw. This project. , the Green At present, all of the potential participants' whole- River Pumped Storage Project, for which a preliminary sale power is supplied from the three major private permit application has already been filed with the Federal ' utilities in the State, Duke Power Company (Duke),
- Power Commission on behalf of the municipals and co-4 Carolina Power and Light Co.'(CP&L) and Virginia operatives of North Carolina, would, at ultimate develop-Electric and Power Company (VEPCO). Relatively ment, be equal in size to the largest such project now bein
- rircr amounu :.re . supplied from self-owned gener- planned anywhere in the United States.
ation on some municipal systems and the Southeastern Power - Administration (SEPA);; G ene ration ~ ' MAJOR PROJECT FEATUR ES Over the period 1975 - 1991, the generating plant con-struction program'shown on Table I has been developed Through the study of numerous generation - as being the most economical. i transmission alterna tivea, the engineers have jointly
- co:1cluded that the r:out ecm.omical power supply plan The tabulated installed capacity is on the basis of inter.
is one that would int lude a stat'ewide network of 500 kv connected operation and normal pool reserves. If isolatec
' (!>l!V) and 2 30 kv tra nsmis sion lines interconnecting major operation is required, additional reserve capacity in the pa rticip..nt ic2d cer.te r s with fou r majo r ' gene ra ting plants, form of gas-turbines would be required, but the base load ..1 shown or the cove r nmp. (230 kv not shown). Ifope- generation plan would not change. - fully, the EPlc sy s:..m would be inte rconnec ted with the dectrical systems of the CARVA pool menL rs (Duke, T ran smi s sion Cl% L, VEPCO ami S .uth Carolina Electric and Ga s
- Compa ny). The planned 500 kv and 230 kv backbone transmission system shown on the center fold out map of this Report,
'i'he four major y.w r.iting plants would comprise would be under-lain with an extensive network of 115 kv, 'ti. rec combined nucle.i r - conventional fossil fired 69 kv and 41 kv transmission lines to deliver power from p!" t complexes ultimately I aving two 800 - 1,000 mw the major 500 kv and 230 kv substations to the individual er.? ca r uniu and o:.c 500 mw fossil fired ur.it at pa rticipant's delivery points. The total planned con struc-
[ e.ich comp!cx. A typica l a rrangement simila r to ~ tion of transmission for the period 1975-1990 is as shown
; tra t propowd at er.ch of these complexes is shown on Tabic 2
- on the Lb..ek af the f: ont-. cove r of the Report. ,
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' I'able 1 Table 2 G ene ration Project l'estures_ . Transmission Project Fez:tures
- f ta
- icn IMe riution Date, Ca pa city Initial 1990 i} i: err. Plant Complex: Steam Peaking Initial ~ 500 MW 500 kv 250 miles 600 mi'es Nuclea r . Initial 800
- Nuclea r - 1989 l',000 230 kv 900 2,100 Tc:als through 1991 2,300 MW 115, 69 & 44 kv ;
- "e ste rn Plant Complex: llase Load r Existing 900 900 ;
St ea m Initial 500 MW
~ Nuclea r : Initial 800 , New 1,700 4,500 Nuclea r : 1987 1.000 ' i Tands throudh 1991' .
2., 300 MW Existing Generation and Transmission l.;ptra! Plant Con 3 plex: Steam Peaking 1981 500 MW Sufficient flexibility has been incorporated into 3 Nuclear . 1983 1,000 the planning to integrate all existing generatio:t and Nuclea r ; 1991 1,000 transmission owned by potential pa rticipant:, into T 1:: throu,;;h 1991 ' 2,500 MW the overall power supply plan and adequate compen-i sation made for ownership or use. .' lans for the
.. . . en River Project: , lhimped.Stge. 1977 250 MW economical integration of existing SEPA allotments
- Unmped Stge. 1980 250 wauld also be incorporated into final plans.
4 Pun. ped Sige. 1984 250 j Pumped Stge. 1986 '250 COORDINATION WITH OTilER SYSTEMS
. .nped Stge.,1988 250 ,
. Pumped Stge. 1990 250 The planning for the EPIC plan ha s contemplated Teni s through 1990 1,500 MW two alternative s: a) inte rconnection ope ration with other utility's system within and without Nor:h U Gas Turbines Initial 125 MW Ca roli na , primarily members of the CARVA Pcol, 3:!e: Ga s Turbines 1982 250 and b) isolated operation, that is, not relying cn ar.y Ga s Tu rbines .1986 __500 other systems for power exchanges and interconnec:cd -
- 14. :.1:. t!.roui :990 875 M w reliability or re se rve s.
G: - Tote ' + Erou -h 1991 9. -17 5 M p/
= ,
I-3 e
inte rconnected ope ration with MEMBElt PA11TICIPATION AND H ENEl-Tri j
. . fi r st We t :a t .ve ,
" A RV A Po.;l a ra: athe r s, would be in the public All of the municipally ow ned electric sy stems and all l
,t a s u. !! a s the individual ceonomic inte rest 3 of of the cooperative systems in North Carolina a re po- It P
"/ 4 Poal n ic : s a::d t'.e potential pa rticipant a tential members and beneficiarie s of the EPIC plan. '
. "'I C . W
.e rconnected operation would avoid is conternplated that all of the coope rative s will pa rti-the ec e a 3a ry 5.:Jic. : ion of ce rtain t ransmi ssion facili- cipate through their present power supply agent, act-a nd exc. mive In stalled tene rating re serve s. In North Ca rolir.a Electric Membership Corporation, Municipal pa rticipa-u ring tF ma a nd cost e stimates for inter- ing through its boa rd of director s.
- e c t s d c.: c .- u i n n, only th minimal advantage s have tion is conternplated to be c$ sentially on an individual ,
c- Inc. .
.r.c e a full evaluation will have to be system ba sis, with authoriz; tion made to handle adminiC c r: er ec cti -cu ssions and final neg otiations stration of project development to a municipal - NCEM
-t'.e C A!1V A Poc! membe rs and others.
The joint board. Operation of the project would be through incers ard :aa rn ey a svould expect to ente r se riousl y a statewide non-profit corporation whose goveridng mei .N. ast lar.s a u coon as .mtho rized, boa rd(s) and officials would be democratically and pro- ! po rtionately de signated by the pa rticipating citie s and l cr to be discussed is the orderly coope rative s . .
. nii. tr ! - . <. i e r o f ' .
f roro the planning re sponsibility of it is tir sup :'i r . to that of MPIC. This ha s been Under the proposed EPIC powe r supply plan, cc es c .n the planning to date. For ne:the r nece ssa ry nor de ,irable that each pa rticipating
' plated that only that po rtion se r ved directly from the rea a,a, .. . c s..;.
system and coope rative be The W d - rs e ru i na, a rea sonable a nnual load EPIC tra nsmission system, at lea st initially. .re
- . i ti . c u sting .uppli.: r s .y stem will be t ra ns - alte rnative to se rving directly those loads that r?d; -'. et r!v yea rs of project development, initially beyond an economicc.1 transmis3 ion distance i -' ,_ I c. g. , from the backbone system is to no otiate wheeling sy stem a rran;;ements or to continue to pdrcha se for tho se
& 3ir anni L eficial an inte rconn. cted opera- f rom pre sent supplie r s. Al so, during the ea rly, yea r s of mbe rs of the elect ric utility oub' h. .H project development when gene rating plant aif ditions a re
.4 i: (. Jina, oun: powe r aupply beity; pha sed in with those of the pre sent supplie rs, ri c e x s .. .
.1 ex. mination a nd .tudy of c e rtain major loads may co:itinue to be se rved .. they
.t :iv of i solated op .t ution, s a re now.
0 :p . .:t ui red , if 1.. rced upon th.. pate ntial - u ..
- , van;d nonethele s s still p roduce Postace Stamp Rate Concent r to: ;-: - < o r.y. t ed powe r supply co st s than c . 3: sc. purcha e ra te s and charge s. The postage stainp rati: co , cept agreed to in !>rinciple in the Memorandum of Agre ment ha s been an intet,ral I-4
. . __ ._ - _ . . _ . . _ _ .- . _ _ _ _ . _- . . _ . _ . . . _ , _ - ~ _
~
9a rtlof the planr.i:g for MPIC. Under this concept, delivery voltage versus the average postage stamp ca st,
. id 'y applied in othei successfully forme.1 and ,
plus the cost of transformation to the present delivery . . t
; e-, ting gene z-ation and transmission sy stems, all voltage.
'pa r tic ipa nt s, <!.ethe r di rectly connected to the , y g. m o r lne,t. . would pay a unifo rm rate at standard _ _ _. For the ten-year period 1975 - 1985, the total saving s ds. live ry vol: age. ' Such rate would apply irre spective estimated as a re sult of implementing the EPIC plan ex-S: 4 .e'.e r th e participa nt l's served .directly, o r ceed $60,000,000 to $100,000,000. th es. ugh morc e'e cnoraical al .o rnate means.' . A s ! pl:.r ned, stand.;rd delivery valtage would be at the For the fifteen-year period 1975 - 1990, c ompa rable ' .t ransmission valtage side of delivery substations e stimated savings exceed $230,000,000 to $300,000,000.
- stopping poVm.down frem the EPIC system to the
-py.r ricip. tnt 9 system. ny setting the postage stamp PROJECT COST AND FINANCING
- ru . at the t ran s
- nir.sion volt age level, the c riteria Mr r establistun;; a new dJivery point will be up to the The magnitude of the EPIC plan can perhaps best be ir. divi A :1 pa r:icipant systein and an equitable sharing comprehended in terms of investment .ost s using present
-of cost s will he a s su red. Consistent with the concept day cost levels. 'Through initial project development to of ec.uitable cost sharing, it is contemplated that the 1980, the total estimated investment in gene ration and transmission facilities' including all direct construction
,po n ge starnp rate will be a load factor incentive rate, having both' dema nd and energy component s. - costs, land, construction overheads, interest during cor,-
~
struction, engineering, contingencies, training and start-up, working capital, reserve funds and legal and fiscal
'~
' .Powe r Co st Savir.u ,
costs would be approximately $550,000,000 for genera-No c.ttempt has b a as yet to develop an tion _and $200,000,000 for transmission, or a total of actual postage st.wp ra w tisce this ca n be dete rmined
$750,000,000.
or.lyfa s project ficancing %r> ope ration are finally de-t e rmi ned , lic,.v. v e r , annual cost , have been estimated Ily 1990 such inve stment cost, ba sed on present price
- on the postay mmp concept. ' Although not repre- levels would be approximately $1f.100,000,000 for genera ;
' 3 en'.a t i ve in a. f ear of the rate that will be developed, tion and $350,000,000 for transmission, oi- a total of 9 i: . e cost s wi!! fluct uate f rom year to yea r a s new $1/T50,000,000. !iac ilities a re installed, total annual cost compa risons - ov.; - los enau b periods off..r an adequate e:.timate Initial Projcet Costs and Financing
- ..i ase... e c .cr co..t . The se' cost:, can be compa red
, nst pr e 3ent purcha se pot e r cout:, a s a :aca sure In conside ring initial project cost s and financing, costs
- o .' kug-rang project benefit s in terms of powei- have been escalated to 1975 price levels. S;nte initial [
i c.. * : sa vi ng :. . project development will take place during the period 1975 - 1980, the total financing requirement ba sed on
..r+ , u -1. dial avino, have be.o. e ,ti - 197L price level., has been eatimated at initial dev. !op-
.Jmo .,: 4 at now r o si, a t ., re :.e nt ment to be a pp cmima tely Si,3 5,000,0t. i, inere .ie by a np roxima telv 3336. 000 000 to W1 000 000im I M.0 e
r .ms .2 . .,u, s.-.----.,.am.- =. .,..ma - m.. a mu,s--..._4-- mr 4ma .-m 2.4_mma_A--u..u. a._m. _ . . _ - _ . - . . wm . . ~ . + - . +
. ,s. a._.4 % .m a. ,m a from the first bond proceeds.
J.s disc med nior.r fully elsewhere in thi's Report, - , fi r :o:a1 J . c ;cing requirement would be met one - ENVIRONMENTAL CONSIDER ATIONS .
- 1.undred per' c ant from the following source.s:
- ~~ The planning and construction of a statewide: project
- 1) ~ Elec:. t: - :levenue 13onds, issued in respective
~
~~ ~ ~
of the scope contemplated in the EPIC plan must care-ahd nroportionate amounts by the Cities, and ' fully consider the effect on the State's environment. - Thii consideration should be, and is, particularly significant.-
' 2)-' R EA nd ma rket loans by the Coo'peratives. when the potential owners are themselves public entities and membership corporations. > .W gene rd cbligation bonds would be is sued by the " Citic s . The refore, in the very earliest plan developr,;nt, the ,
engineers have recognized that protection of the State's Ti;e. long -term debt obligations will be secured by coastal estuaries and rivers from any harmful thermal , 'e c.~.t rA c t s .,i:' the Ci:ics to take and pay for power effect s of power. plant cooling must be a ssured. Since th.
...,ce r h pe ric t :. years from the System and by similar major load centers of potential EPIC participants are not
[ ur Mi.i r a w . :riste arrangements with respect to ~ located on the coa,st, as is true in the northea stern U.S. , the Coop.- c_ .% s. studies were made of once through cooling at' plant sites ! i on the coast with long transmission lines to load centers ' The 'p ri: c! pal a nd inte re.>t costs and.all othe r cost s versus plants near the load centers using essentially mak 4 ~o f ope rm tn :.n<: mainnining the generation, trans- up water from streams and the auxilic.ry cooling using
- n. nion anc general plant facilities required for the cooling towers or cooling ponds. It appears that it will .
EiMC phin 1 :.ve haea eatiniated is a reasonable range be at lea st a s economical to provide for such auxiliary and mix oi ;w ncing em ts and price levels in esti- cooling at load center plants rather than natural cooling .
- i. ting the :ong- erm project savings. at coastal locations. i
.The re:: re, niject to fin'd determination of fea si- Air pollution is also a major environmental concern '
- nh ty unset cn cetailed engineering work, contractual to all areas of the country. Only three '500 mw units are nmmittm * . . nd requi red legal and agency approvals, planned.to burn fossil fuels and two of the se a re peaking the bonds ac.c oth"r obligations should be readily Even the type units that will. operate only intermittently.
ma rke table. third fossil fired unit will be relegated to essentially In any ;
- peaking service in' the later years of the-project.
!Kv,..-lop .cnt cost , durin t the planning (not con- . event,. even these plants should be, and would be, equipp
- m : ion) .a < t.. the pairc. of succes sful financing with the latest particle emission and noxious ga s reduc- !
Ji a va c : ;,rc, ject, conce rning enginee ring, exe- tion devices.
; H i u ,- le : . cthe r e:.p. nses, will require advance s Ci !c s ar.d Coope rative s, icr two or i hich wi 1 be refundable to them The effect on environment associated with the Green
- t' .. . .
4 1 fi . I P
f
- 1) . Approval by the Fede ral Power Conunission of the -
Itiv.ir Pump 6d Storage Project is also a prime con- Prelimmary Permit Application to study in detail the anp Green River Pumped Storage Hydroelectric Project, ibts'
nS, CONT R ACTS,J N EGOTI ATIONS AND 8)
Approving opinion of recognized bond counsel REPORTS underlying legal determinations.
- During the prcjch i.lanning :.nd davelopment stagc, In orde r to secure such approvals, your aticrr.c'/s w psior to ir.itial financing, aufficient engineering and have to prepare legal documents and presentwill them IQal war!: cIll be required in connection with securing re spective responsible bodies while your c:.gineers at lea st the 11owing permits, licenses, certificates
., 3I e .3 } ~< r .[
I-7 ____________-_____._____-_____._____.--___m m.-_ -____ - -__ __ -
- _ _ _ - _ _ _ - _ _ _ _ _. -
v' l; t
~
L .gto prepare necessa ry detailed engineering reports 3) Reports to F. P.C. on~the study of the Green Rive: rd present expert te stimony. Pumped Storage Project. l-E:< tensive cont ract negotiations and prepa ration wo'rk -1) Extensive, comprehensive reports to A. E.C. on
.:,.-alving bot e nginee ring and legal talent will'be~rc~- ~ the proposed nuclear generation plants.
Iuired 'in con:wction with: '
- 5) Final Feasibility Report t ipport initial financ-
- 1) Arrangenwnts for pa rticipation in EPIC by the 'ing.
C: tie s and- Cocpe ratives.
- CONCLUSIONS
- 2) !.ong-term povsr e :l.plyTparticipation contracts 2nd rate devcicyment. The results of the studies, investigations and analyse conducted to date and summarized in Part II, Engineer-3)- Possib:e re-negotiation of power contracts with ing Report, and Part III, Legal Report, form the basis ed i sting supplic rs and SEPA. for the following conclusions:
- 4) Interconnections and pooling agreements with 1) The combined loads of the members of ElectriCiti and NCEMC are of sufficient magn'itude to take full ad-c the r s .
. vantage of the upper limits of scale and present technolo
- 5) Arran sements for compessation to participant . in developing an economical statewide power supply plan u.cr.crs of exi. sting gene ration and transmission. to supply their own bulk power requirements beginning it i i [ the pe riod 1975 - 1980.
,6) l'uel procurement contrac'ts.
- 2) The construction and operation of the statewide po
- 7) Equipment contracts for long delivery items of supply plan described in this Engineering and Legal Rep.
- tjor. facilitie s made contingent on succe ssful financ- appears to be engineeringly, legally and financially feas'
. :.g . ,
- 3) The successful accomplishment of the proposed E Si;:. ficar.t :.+:ditional engineering and legal reports plan could bring hundreds of millions of dollars of savin,
!~: .t win be required inchide: - to the partiHpating systems over the long-range future l ' through achieving lower bulk power supply costs than
- . t )- Prelimina ry de siy,n and detailed project cost ;from their present suppliers or any other presently knot l . ~. .
- % : e s . potential alternative.
( l'
- 2) Exten sive site and routing investigations and re- 4) With continued joint support of the potential partic
. pa nt s, the proposed project can be carried through the I-8 l
I
~
final planning and licensing stages to successful
~- -
fina nc'ing. - - i ~~ R EC'dMM E D iiONS s Accordingly, it is recommended that:
. J ,
, 1).l This Engineering and Legal Report be ap-I prove.d and that the proposed EPIC plan described
,, [ .
herein be adopted as the' preliminary long-range
~
f. poweE supply plan of the _ Citie s and Cooperatives l of the State of North Carolina.
, 2); Such organizational, budget and other ar-rangements be recommended to the Cities and Coope rative s for adoption a s required to unde rtake -
. and implement the further planning and develop-ment'of the project and the pursuit of the neces-i sary and appropriate legal, engineering, fiscal and o'her procedures to accomplish them.
t Respectfully submitted, i
'S/ R. W. Beck and A ssociate s S/ Southern Engineering Engineers for ElectriCities Company of Georgia
. Engineers for NCEMC
'? S/ Tally, Tally & Lewis Attorneys for ElectriCities S/ Crisp, Twiggs & Wells General Counsel for NCEMC 5
I , 9
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O Q. W c: O Z ti. C4 Z
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I'
II
SUMMARY
ENGINEERING REPORT kk: F 1~.9CTION AND ACKNOWLEDGEMENTS
~ ~
so much more eloquently than engineers are capable of and we are grateful of the opportunity to have worked with
'I h e aynote of the pa st yea r's l engineering activity two of the nation's outstanding law firms, Tally, Tally i:
- - c.cy+..::ing :he plan and concept of the proposed Lewis and Crisp, Twiggs and Wells, in bringing this truly
.hl! i.;w.ide powe r oupply pre, gram ha s been team- EPIC project to its present state of developr .nt.
-c; r i . 'hnce avthorization last August by the Executive 0 ,rr ~ i: : . of E!ectriCities to R. W. Beck and In this Summary Engineering Report, we will try to
.s.soci :=. 5 and by the . Board of Directors of NCEMC avoid duplication of significant facts pointed out in Part 6 5:;.:-' : Engineering Company of Georgia, these I - Transmittal, Summary, Conclusions and Recom-vce J.r.. , pur s.unt to :he Memorandum of Under- mendations. On the other hand, the respective member-r.dl:4 Setween engineers which was incorporated ship has the right to, know that the statements included in
.o:.? .:.~.orandum of Agreement between organi- Part I are based on extensive engineering study and
'n:icn z , .1ve wo rked, studied and planned the system analysis, so it is appropriate to summarize the more M .: - C. i nately evolv;ed, in close harmony .1d . impo: tant of these in this part of the' Report in some-m: .l. m coope ra: ion. what more detail than set out in Part I. T hi . Girit of teamwork ha s extended well beyond As pointed out in the Legal Report, much of the under-
.. ._. .nc ring a.q.eet s alone; it ha s been embodied lying studies, analyses and results thereof are profes-
- . . C. 4 : re:uianship between engineers and sionally confidential. Such confidential information ha s, .
..r0s :.nd in turn between these consultants and however, been made available to the Executive Co:umi: tee
..nr3 and the gove rnir.g groups of the two organiza- of ElectriCitie s and the Boa rd of NCEMC. Further, it lor.::, z.:.i appointed officir.ls through whom the studies is contemplated that, as necessary to reach important
.ve be.:r coordina:ed. -
decisions regarding carrying the proposed project fore-ward, such confidential information as it affects each I'. t $
---I mee:ings of ElectriCities and of NCEMC City and Cooperative will be made availabic to it on an dl:..cz. : tl.e first oppo rtunity for the entire membe r-
- individual ba sis.
. , n . . .mine the results of this teamwork and to a continua: ion of such efforts can bring LOAD PROJECTIONS
, r. '. .- :fs:cm :he f ruits of the seeds planted this nr In making the load projections summarized in Part I, e:: tensive data received from individual systems on forms
. ily joi . .>. ic.c very appropriate acknowledge-designed by the engineers were utilized to develcp grow.h
>r- s s %ve expressed in theit- report rates, diversity of load, typical monthly tnd annual lo .d 9
Spes and load dura tion curves utilized in the at 11. 4% pe r year. Using projections of municipal
- c. Ora:icn and transmission expansion study. system loads combined with REA approved estimates, or
.Diverai:V reasonable assumptions with respect thereto, io: the
._ Cooperatives, combined projections from 1968 to 1975
. ,_ _ f used in this report average 8. 5% annual g rowth rate. Fo Our laint studies revealed that substantial diversity the period 1975-1990 an even more conservative projec-exi sts between the time of annual peak demand of the y Ci:les and Cooperatives. The Cities as a whole have tion was used resulting in a growth rate of S.0% per year annual average.
e.:m ner peak, while the Coaperatives as a whole have a win:e r peak. . The. sea sonal. diversity between the two is about 6,3% of peak load. The electric utility industry is a decrea sing cost busi-- nes s where g rowth and scale mean ever lower costs. Y. M, subsantial diversity ' exists between the time The refore, these conservative growth rates assure that ti d w n. 7. . pen h 1oad on the individual municipal and
~
estimated cost of power and, therefore, the estimated sa-c~ >pe rr.tive systems, ings are conservatively stated and should be substantially bettered on the actual system. The c.er.efits of sea sonal, monthly and daily Total Load and Design Loads
< v e n i .'f batwna peak loads is one .of the factors *
' in; c e n: u + L wn powe r service more economi-c.a! :Sn .i. idely spre..d i solated 'sy stems. Only The total projected loads of the Cities and Cooperative throu.z i. a zel:-owned generation transmission plan have not been used in designing the initial generation and t ch i s E PIC vill the Cities and Coope rative s be transmission system for two reasons:
. e. nu re : @ ne benefits of such diversity are
- .c rutag direc:ty to their systems. 1) The Engineers have assumed that the period 1975 -
1980 would be a developmental period in which the system G ra":h R ..:c s would take shape and during which period there would be an orderly transfer of load from the Companies' power G r e;- ' rz. m u se3! in proji cting future peak kw supply systems to that of EPIC, and
/ . .r: .n-
.I h L nave been conservatively 2) Not all of the municipal and coopera tive load is e .:: .a :e . '.c es.rdi m: to recent surveys; g rowth
*ta u - Ji r d;na ., Georgia and Florida' have initially within economical transmission distance of the
- m. ..; be- c im la , con; pound inc rea se since backbone system. The refo re, continued purcha se from
! . .;. . publi . . O data also shows t'nt the present suppliers by EPIC on behalf of these sf stems
'i" O c. . c :-
- nd i.:q ht Co. had the fourth highest appears more econo:r.ical in the early yea rs. A n alte rna-r a . :i. U. S. f>r 1968 - 24.31%. For the tive of wheeling power to such loads over the exis:ing
- . 5 - i M. 9, ' C P : ! . 's d va rag e c row th ra te wa s company transmission system would have to be evaluated
. . :: . a .c , u n.,d , De.e Powe r Cc.mpany on the basis of discussion and negotiations with the Compa ni e s.
, . - :ve . , 10. 0% pe r yea r a n,: VEPCO e
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.- .;c id. mt.nicipal and coope rative load is not the major. .
.t tr:sf :he three companies'.overall load, it is a sig- Utilizing the design load projections and load characte
- nifichn
- 'part of t!; air North .Ca rolina load and doe s repre- istics and cost estimate s of va rious types of. generation, - .
mt: 2.pproximately one to two years growth to the indi- studies were made of the optimum mix and size of base . eib.: Conipanv 5 ove rall load. In 1967, the -following - 2 load, intermittent base load - long-term peaking, .short , ruiau ;f combined municipal - cooperative load to term peaking and reserye capacity which would produceL Cc:r.pany load existed: the most economical generation expansion plan. Duke' C P8th 'VEPCO - Ove rall Ba se load gene ration is supplie'd by units that' operate
, essentially at full load around the clock, month in and - ,
hrio. cf Combined . month out, except for periodic maintenance or unschedul-Lud :c' Company ,
./ outages and are therefore operated at what is called a-Cc5ILoad- t 8. 04% 18.'1% 4 3.5% - 8.85% high plant factor (average load vs. capacity). ' On an
; annual load duration curve, which is a plot of the per ~
- niti e of Combined . centage of time during the year that the. system experien-
- .w.-:c Company , certain loads equal to some percentage of the annual pea!
.!:rth Ca rclina ~
, load, base load units occupy the bpttom part of the ' area ,
. ' L sa d 11.97% 21.35% 40.97% 16.71% under the curve. Since such units produce more kilowatt - hours per unit of installed capacity than generation Ti.'c'later .igdre is .notewo rthy since it shows that a scheduled elsewhere on the load duration curve, it is - ; , ni:icant pr rtion of-the facilitied being planned by the essential that they have the lowest possible fuel cost and Cr- p:.r.ie s in No: th Carolina a re to se rve' the muni- be large, efficient units. Therefore, large nuclear plant rc: m. t -l coop r. .ive load s. I'o r tiii s rea son, if the and large conventional coal or oil fired plants are con-C : e a .d CI ::cratives da decide to. build their own sidered for this type of service. The magnitude.of the
. .wrarian e n!- t ransmi ..sion system, ce rtain lines now combined loads of the Cities and Cooperatives permitted u.cir ; planned by theLCompanies, particularly 500 kv consideration of units in the size range of the upper limi-
- a
- 7 M0 kv,- -5hould be built and ' owned by the EPIC of today's technology, 500 - 1,000 mw individual unit s.
pa rtidpants :o ser.ve : heir own load s. A balance of capital costs versus energy costs may wi'
. : . .; 9a p a.. '.e opp. nite page shows the projected dictate that in the earlier years of lesser load, a mix of I-:#., : pe;.k Icr. - .d de'sigmpea k load of the combined. ~
large nuclear plants and smaller base load fossil fired n .dicipal - acp:-ative systems for the period 1975 . plants is the most economical with the fossil fired plants
- l %0. ,
moving up the load duration curve in later years as larger plants, particularly nuclear plants are brought on ; ! line. As will be discussed more fully later, thi s wa s the case.in planning the EPIC System. 4
~
e II e-- - - - - , , - - , - - - - - - - , , - 6 9 e O $ 9- Sw
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r* . Tho se plants w hich occupy the middle to upper supplying the load. A s can be seen there, all the energy cr. >e of the lod duration curve are characterized under the curve below 65% of the ]!cak load is cupplied wl ,:newhat higher fuel or energy costs and lower by nuclear. In addition, not shown is the ndditional :raclear paital costs. Specially designed'" steam-peaking pumping energy used in conjunction with pumped storage. Ma nts" and pumpcd storage hydroelectric plants,where - Due to losses it takes approximately 3 kwh of pumping evelopable,usually are selected for this type of service.
~
cnergy to produce 2 kwh from the gene rators at the pumped he combination of adequate pumped storage capability storage project. r.d la rge nuclear units is currently being recognized s the most economical method of meeting large future Also shown on the load duration curve is the energy sad r ' nire me nt s . By using off peak nuclear energy supplied from the pumped storage and conventional br pumpina,, these plants can be maintained at their base load and peaking fossil fired units. As can be nest efficient high plant factors, while the energy stored seen, the pumped storage provides about 20% of the load n the upper reuervoir of the pumped storage project an be released during peak daytime periods. The on peak, a ratio found practical with respect to the pro-Jr >t neneration e:spansion schemes were limite'd in the ject studied and the storage capacities available.
- noent and size of nuclear plants'since originally a Description of Proposed Generation Plan emped storage'projec~t of only 600 mw was developed.
urthe r study, however, revealed an alternativ~e upper The initial project development has been fitted to 1975 cservoir site that will permit development up to design loads. These loads would justify the installation
,000 mw.
The results we re a substantial reduction of the following generation: a overall project costs. .. y 1) One 800 mw nuclear unit and one 500 mw fossil The very upper limits of the load duration curve, pd generating rc serv'es not counted on to carry load, fired unit at a plant site in the Eastern Region of the State. n best be supplied from steam peaking units a'nd gas - rhine s. An .uh quare mix of this type of generation s b0en included in the overall generation expansion '
- 2) A 500 mw fossil fired base load unit at a plant site in the Western (Piedmont) Regi9fi of the State.
agram to meet the requirements for interconnected e ra ti on. Ilowever, in evaluating the cost of isolated
- 3) Gas - Turbine capacity to provide needed reserves e ration sufficien additional reserve capacity in the located at stri tugic locations in the State.
rm of gas turbines has been priced out toineasure is additional but hopefully unnecessary cost. A s a practical matter, the engineers recognize that the Load Duration Curve ' lead time required to organize EPIC plus the normal lead time on large units, particula rly nuclea r, may not pc rmit
. :e graph on il opposite page shows the annual development of all or any of this generation as carly as 1975. Nonetheless cost estimates based on such assump- .J hration es.. ce for 19')0 and the type of generation tion are valid since ample allowance ha s been made for e scala tion.
TT .t
DESIGtJ LOAD vs INSTALLED GENERATION
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GREEN' RIVER PUMPED-STORAGE PROJECT racmeo , PROJECT- LOCATION MAP s s saa= au.u==am.o - R//r BI'CK AND ASSOCIATES ' caApinc SCALE MILES l c .
9 te se im estigt.tions that' the combination of the Foster Pulliam reservoir area. A t th e wo r s t , i t 'vo ulci L.v. to 2wc-r reservcir and an upper reservoir to be developed 1 be transported from the Foster reservoir area. Thelo-in the Pulliam Creek drainage' area on the north side cation of the quarry for the rock fill will nced special of tr.e river app. cared to offer the best potential for a a t te ntion. It may be arranged to form an intake canal large pumped: s:orage development. The location of which would shorten the pre ssure shafts. Similar ar-this projed is shown on the relief map reproduced on ~ rangements were adopted for the layouts at Salina and Bhc opposite page. Muddy Run. For intakes located in the natural reservoir the ratio between length of pressure shaft and head At ;':is pair.t it was decided that a field investigation would be about 5. 3 at Pulliam. ' This ' comp re s wi th
- of the proposed project would be necessary in orde r to ratios of 8. 75 at Taum Sauk and 3. I at h!uddy Run. It confirrp the ten:ative conclusions reached during the is clear that savings from shortened shafts refer not of fice - tudie s. Air. Adolf Meyer, . a. nationally recog- ;
only to the shafts themselves. Because of regulation nited .mpert on hydroelectric power development and considerations, they,also influence the velocity in the ' icemer chiaf civil design engineer of the Tennessee conduits and the WR of the units. Talley J.uthcrity, wa s retained to assist in an on-site s evalua: ion of this project in cooperatiorfwith the hydro- "In the Pulliam reservoir area we could see no indi- ' electric design group of R. W. Beck and A ssociates. cations which would make us suspect water loss. Iiow-Excerpts. from Mr. Mbyer's report 'of his investigation - ever, as the tightness of the reservoir is a ba sic con-follow: dition for the success of the project, I'd like to recomme that it be given further study. A competent geologist whc Fo ste r Q.ovy. r Dam 3nd Reservoir) is familiar with the prevailing rock fo. mations of the
' area and who knows about the experienc s gained in the
'From tha general condition of the site, it appears construction of the many reservoirs in tha neighborhood, there is a gead probability that it is well. suited for should be asked to inspect the reservoir sae. lie i economical conaruction of a fill dam with impervious core probably would be in a position to give a conclusive and with compacted rock shoulde rs. Materials for the an swer regarding tightne ss. His opinion about the rock Leo're appear to be available in the reservoir area im-
~
conditions surrounding the shaft between the upper 4 mediately up t re;.m f rt.m the site. " - reservoir and the power house shoulil also be sought and should be valuable in the absence of ar.f underground ex-
. '_P.C"dlSi C.D'.ek NW": r_91tm and Re se rvci r) ,
ploration at this time. '
'For the').4A foot hi;;h stracture required at this "It is further recommended that the two dam sites be ! cith, it a pp. .e a very probab!c that economy again would explored to establish the probable safe contact between i:.vor' 4 fil! . m, with .m Impervious core between core and tight foundation and between rock fill and I
_ pa c:e d : 6 fills. It is questionnble whether core foundation surface of at least equal strength character-meria'. all /. 4 effis le et 1..tndling could be found in the istics to the rock fill. The geologist should be consulted II-6
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abour ha to gut Ois information in the most economi- 'cil :. a rne r. " Gross head would be 880 feet niinimum and 1,040 feet me.ximum. These high heads will allow the use of smaller, more economical pump-turbine units than would b2 the Fclicv.ing the .:cid inve stigation,' a prelimin .ry project layou: v.m prepa red. 'Ba sed on the. re sults of case at lower heads and, together with other factors, will 9.e se sradies, i; was recomme:uled that application be help to produce a very economical installation, particu-rc. uie : : the FPC !ar a Preliminary Permit in oider to larly in the later stages of development. pecpei.. under a?._ rore detailed studies of. this pro-pc: c.nc protect Go Cities and Cooperatives ri; hts to Lower Reservoir: The lower r eservoir for the pro-Wady and develap :he project. Accordingly, an appli- posed project will be the Foster dam and reservoir referre kuion for Prelirmn ry Permit for the Green River to in the 1964 FPC River Basin Planning Status Report Nmped S(arap: Project was filed on July IS with the for the Santee River Basin. The reservoir will be formed Federal Ooccer Cc muission on behalf of Statesville by a rock-fill dam with an impervious core approximately nd o:her Nor:b C:.rolina municipal corporations own- 165 feet high, located at approximately river mile 29 on tlie Green Rive r. Construction materials for both the r.g and operat:r alectric distribution systems and the
~ ~;rth Carolina FJactric Membership Corporation. The core and the compacted rock-fill shoulders of the dam are .:plicants have been notified of receipt _of the ap' plica- available in close proximity to the site. A radial-gated spillway will be formed by excavating a channel through iar .bu. nc furtha communication has been received as the ridge forming the right abutment, with a low-level out-i this time. T h.s is ' normal procedure for an application let provided for minimum releases.
,I this type and :: may be some time before final action s caken by the C :mmi.seion. ' Total storage capacity of the Foster Reservoir is esti-Project he:ption mated at about 65,000 acre feet, with the 25,000 acre feet required for operation of the project at its proposed The general project plan of this project is shbwn on ultimate development of 2,000 mw being available between te map appearin; on the opposite page, elevations, 1,060 and 1,100. A good part of the land which will be covered by this reservoir is already cleared. It i s c or:c c -- ted that this project would be developed Powe rhou se: The powerhouse will be located on the c.itially in .1977 .. 250 mw generating capacity, followed Re adai:ica - 0 .hw in 1980 'and stage-wise expan- north side of the lower reservoir at the b; se of Long Ridge. 2 ' . c.v .c.c rements to approximately 1, 500 mw This powerhouse will be of the semi-outdoor type constructe b 199 3. - i;h c';i: nie development at about 2,000 mw. of reinforced concrete. A gantry crane will be provided O n. :.n d s .. rvoi r s nd the forebay channel would on the roof of the structure for removal and maintenance s e.an .r. .:. e i.O.u lly to full capacity. of the pump-generator units. It is contemplated that the generator-motors will have a rated capacity of approxi-raately 250 mw each. Generator voltage will be 13. S kv. H -7
y 4 i [ WEEKLY LOAD 2 CURVE 1
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d An excavWd tailcace approximately 600 feet long construction of the dam from the excavated rock from the will be provic.ed ta convey flows to and frem the lower forebay channel. Material for the impervious core would' re;ervoir and to prc, vide. adequate submergence on the be imported from the lower reservoir area at the worst, 3 pump turbine runners. Trashracks will be provided with a good part of it probably coming from the proposed
.ta prevent. trash arid debris from entering the pump- upper reservoir area.
turbine unit s. I Clearing of the reservoir area will be somewhat more Power Tunnels: " Sepa rate power tunnels, each of a problem than for the lower reservoir, but.should-appraximately 2,300 feet in length, will be provided to not present unusual difficulty. A s noted in Mr. Meye r's , serve-cach pair of prmp-turbine units. The tunnels report, the principal geological formation in the area Aill be bifurc' ted a near the powerhouse to' serve both (mica gneiss) appears to be quite' favorable for construc. units ami wil: ac lined with st.iel and concrete at the tion of dams and power tunnels, as well as tight enough d..w : a ream end s and possibly., concrete at the upstream to prevent leakage from the reservoir. e .b. . h is wr.templated that these tunnels uill be jconstructed to match the stage; development of the Operation and Transmission
- genarating units.
It is contemplated that this station will be remotely I'or ebg Cha nnel:_ The uppe r ends of: the power operated under normal conditions. Transmission voltage
- tunnel s will :erminate in a forebay channel a'pproxi- from the project will be 230 kv, and 500 kv. In the mas.ly 2,800 feet loni which will be excavated through .i ni ti a 1 stages, at 1eact onc 1inc wi'lI be 500 hhe rim of tb. upper r. ,ervoir'in order to co'nvey flows construction operated initially at 230 kv. It is planned
- ty, and from the powe r tunnels; The excavation from that this installation will be operated at design capacity this channal will be utilized in the construction' of the for approximately ten hours daily for five days each week j dams for ho:S the upper and lower reserr > irs.
with a considerable portion of the pumping for re-filling of the upper re servoir coming on weekend s when avail- ~ . . T!;is forebay channel will' serve to great y decrease ability of pumping ene rgy is greatest and cost is lowe st. ithe length 'of the powe r 't onnci s, such that the ratio it is estima ted that approximate 1/1. 5 billion kwh of }of :unnel length to ope ra ting head will be approximately electrical energy will be produced by this-installation
- three to one a
- ave:ag.. condition s. This is a very in 1990, when it will be developed to 1,500 mw generat- !
- i.wa rable 8: u:, tion.a'nd uhould allow for considerable ing capacity.
jecono ny and ca w in the operation of the project. On the opposite page is shown a typical weekly load
- Qpe r Re se rvoi r: 7 he upper reservoir will be located curve in the later years of project development showing ,in : :e Pallifr.i Creek Drainage A rea. A dam ap!,roxi- the nuclea r power generation carrying the prima ry ba se ;n itely 3C0 w. m ma yimum height will be re qui red. It load requirements of the system supplements d during
- i . cas. er..p! / iat G
- . dam will also be const ructed
' this peak week with some base load fossil fired genera -
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nh y it. seen ring roc! .or the under the-weekly load curve from the Green River 4
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.: ~
and u c. .:end 1e> ods a re shown c ross-hatched and indica w the piu aped ene rgy supplied by primarily- - nucle:.r and a small amount of ba se load fossil fired ' ~ _ generanon. :his weekly load curve illustrates how valu bL :.eecluate purr-ped storage capacity is to the ove rai! E'PIC plan. Were it not available, more ex-pen si . a ba se load nuclea r and fo s sil fired and peak-ir.g capacity would have to be provided but would not be op.-r.ted du ring the off-peak nighttime and week-end hour s. , a e B b e IT - 9 e
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@ j
. . @ E.M.C. SYSTEM .
h
- NUCLEAR GENERATION d PUMPED STORAGE GENERATION 8
@ CONVENTIONAL FOSSIL GENERATION
- 500 KV TRANSMISSION LINE R 500 KV LINE TO BE RELOCATED IN INTERCONNECTED SYSTEM E 500 KV LINE TO BE ELIM:NATED IN .
INTERCONNECTED SYSTEM 23O KV TRANSMISSlON LINE
~~R ~
230 KV LINE TO BE RELOCATED IN ' INTFRCONNECTFD SYSTEM'
JIt ANSN!!SSION solid lines which are anticipated to be built by EPIC in any case are nonetheless de signated with an "R" indicat-Cac#ral ing that these could be relocated somewhat as necessary under a coordinated plan with the CARVA pool members. Selection of vol:aae: rhe following voltages were Underlying 115 kv, 69 kv and 44 kv lines and substations, aclec:ed iar uae in the design of the EPIC system: ~ ' although carefully planned on working maps, are nct shown - { M hv, 2 30 kr, 115 kv, 69 kv and 44 kv. The selec- on this backbone . system map.
- an of each of the tra.nsmission voltages from which
- he bulk of delivery would be made at i15 kv, 69 kv Delivery of power and energy: Inve stments have been and N4 ':v, was primarily on the basis of exis:ing included in this study for the transmission facilities neces-x:,1: ages and, therefore, existing transmission facili-sary for delivery of ,ower and energy from generation
- s in the s:a: . This breaks down generally into sources to the high side of distribution substations. It is
- rec areas, 115 kv in the eastern a rea, 69 kv in the assumed that participating utilities would provide their
- c. ntral a rea ad. 44 kv in the western a rea. The selec- own distribution substation facilitie s.
u a ui 500 hv and 230 kv were made on the' basis of the q- n:Ities of pc ..ce r to be delive red to 'diffe rent a rea s Economics of 500 kv:The trend in the design of generati d c,: the size ci .:e generating stations from which units and stations is toward much larger capacities in pvccr will be muved. 500 kv and.230 kv a're also ap- order to take advantage of economic,s of scale and to more p rently the vcsjes that have he'en selecte'd by other fully utilize the limited number of good generating sites. companie s in the r.rea and will'thus afford much greater The benefits from these larger generating units, plus opportunitie s fo r inte rconnections. , other possible benefits such as coordinated pooling of reserve capacity and economy interchange are all de-
. Bwkbone sv2: .a. - The backbone transmission pendent upon the ability of the transmission system to syst.:m in this design is 500 kv. This 500 kv system transport large blocks of power, sometimes for long dis-can :ects four gdne rating site locations and ha s six ta nc e s. A 500 kv line for instance can ca rry approximatel laccious for step down to the 230 kv system by the end 1,500 to 2,000 mw depending upon the line design, wire cl de studf pe riod. The 230 kv system then delivers size and line length. The establishment of a 500 kv net-po xe: to major !aad c<.nters over the state into lower work offers to this System the potential of participating vultage t ransnus:; ion systems for further delivery to in the economics of scale. Also, since this is the level distribution suhtations of participating utilities. of EIIV transmission voltage already adopted by the CARVA pool members, broade r opportunitie s will exist Thi s cackbc . af 500 kv and 230 kv facilities is shown for joint planning and power pooling than if other voltages
,1 th.. ce nic + ""-out : nap pi mding this sec tion. Note had been selected.
' 4 4me c,f tL lines are #ow n dotted, indicating those ui; .. s ". P ic h mi,,i.: he clin.in.ned under interconnected Inte rconnected or Isolated Ogeration: The tra nsmi s-
,. . ion vi:'. f- CA RVA W..! since the pac! me:nbers sion system of this study has been designed and laid out
-( : '- -
.,r :rm : DO kv c z,sentialh long so that if necessary it can be constructed and operated as
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, o r h wu zt p p o y c ga ,ih i e o o nn at P t rt a o nihg s ap rd t l n n noeo t
t t ua pS h nrd o s e, i e e ird Cu t osh h y a a f or ogi r 'a s t naieh . ct t h e gc ya i s t t i s r a d n c eg d u g t pm n r e pw r a er reiar nn t ns c t e ul l n io et i n o e yrf l e e a y ei nS pw hf rpn t i e n et rn e ne i g d t d u a c vbUo i a s um i x n n r ed nbh d h he an d e at t r f Ce o e
. f i s oe ai t bioh ol o t i V
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t gPeit b t_ at a st i h pd e a r innd - nmng'e e N ho nt a ee m c f p ,s i ap y nE d nS t h t s e gi t h t e i sd a i i n ns o o s or1 rl ob s a e r a n i t i yl e 3 ndl g al s mumh d o a n mt i a c n es ud e i e t l t r e i l a g a ih vee n a o ed s oome oys l rb oi i l pn e o a o otrh ehl dnd o n l o e npiumpt i r e rt ei l poh l a wbl d a n cl o s e yu od Cnn t i t t ps ot r r o c u go nana s a e r a l
, g e eyl e s y - at a r osinop a eivfo si y t I l
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,i t
hi ei c h r h r aa y a nt i c e m o e un r oa ut ah l u TmtnploJcnt i < t usd r T Wepntiih s t e a h Tt s e n nf eh rela p a e ht f o e n r e e e : ai r r o umdl cil l I et d g oc r a t mRs ._ i pin oori uxon pc ouS ec o t y s mfnn nuEo t i i nr f s e - e m s i
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- t. i c s e i m
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s n t i wid % s i oa g ed t f r ul r ui e-g a. 06 5 0 n i A n i h. k et e F R v t r ni e o ao er cc y 0 : u T1 ja.j t i e e. ?. o . o gc n s ei wy 9 ar l v.a l t r n noiprd v e - h ye y + r n r i T a. ieiact. o e l ei g l.i .- t p k . : p p omb t
;y r o re o v o ca t nf h, l l ea M.
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- c. '
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ommoieg? a e r i7 u. ',a 0 h ib s i h 'i e D r s t s et t t e s i
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id
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- d f e p - H t
ii l i r o u s9 D i
.o h:ilize the e; d re in:ercoranected backbone and under- units that are backed off.
".2 t ransmu ion sy stem fo.- the transfe r of power and
- v ergy from generating plants to load centers on an equit- 3) Exchange of emergency and scheduied maintenanc.
.able sharing of construction responsibility and use of . energy.
othe rs surplus transmis sion capacity and transfer by -
- ~ . displacement a rc, or' should be, the rule rathe3. than the
- 4) Sharing of installed capacity reserves. .
exception.
- 5) Sharing of spinning reserves.
The ~ EPIC plan could contribute materially to the fumre powe r supply need s of tlns area. If implemented, 6) Joint development of generating plant sites. its participants can economicall'y afford to bear a fair W.: aig:d iican: pcrtion of the investment in new trans- 'T) Conduction of joint stability studies, load flow
.m
. ... n and ger.eration facilities required to ; supply their studies and generation expansion studies.
1.,ds and provide substantial benefits to other
;y a tcm s. . Benefits of Coordination Elsewhere i. d.is Report important a rea s 'of potential The benefits of coordination between electric utility coo rdination N.w already been discussed. regarding systems are multi-fold and include:
pha sing in of EPIC gene ration to reduce to minimal ,
' significance id'.ng of mvestment en existing power supply 1) Economic benefits resulting from the mutual shar.
system s; clir: aation or relocation of certain EHV and ing of costs and savings resulting from the areas of co-high voltage transmission lines; and mutual reduction ordination discussed above. of gene rating re serve s.
~
- 2) Increa sed reliability of service through the inter-4 A full level of coordination with other systems which connection of transmission facilities and sharing of would produm :urther substantial mutual benefits might reserves.
include:
- 3) Environmental benefits re sulting fr n coordinated 1)' Excha
- v of short-term surplus capacity between
' planning to make the best possible use of limited power system s front new la rge ' units and f rom system surplus plant sites, transmission rights of way and recreational s reserves. opportunitie s at planned facilities.
- 2) Exet . ci ecom my energy between systems on Other Public and Coopera tive Sy stems an hcu r by b er ..:. sis where units on the interconnected sy L t m a re ::M ,duled Dir.the mo t economical dispatch on No attempt has been made in this Report to evaluate i: remcmm . m st c riteria, with a split of saving s be-n . a :.v..il .m u:.its vh..duled for. genera ti.:n versus other the obviously beneficial effects of coordinated planning and operations with other public and cooperr.tive systems e IT 17
_ _. . _ _ _ __ _._. _ _ . ~ _ . . PROJECT AND TOTAL INVESTMENT COST (Based on 1969 Price Levels)
- Initial 1980 '
1985 1990
$(000) $(000) $(000) S(000)
(r ec t Prc., ject Cqt_ finch =e s Engin.eering, Inte re st During Construction, C aming encie s, Training and S: art-up Costs and Price Escalt.: ion) - G ene r:.i>n Nucicar 140,464
; 277,017 443,653 776,925 Conventional Fossil 115,584 115,584 164,462 Pumped Storage 164,462 Gas Turbine 52,080 70,360 107,240 12,602 12,602 37,806 88,214 Sub-Total : 268,650 457,283 716,281'
, 1,136,841 T ra ns mi s sion '
151,745 _194,392 271,068 321,097 Direct Project Cost ' i 420,395 651,675 987,349 1,457,938
+ ,
N j he? Investment Costs , Generadon , ; ' Initial Nuclea e Fuel Core 26,640 53,280 W arY.ng Capital
- 84, 780 147,780
. 3,161 5,465 8,550 13,687 Rese rve Funds ' '
18,941 32,508 50,956 81,581 Fiscal and. Legal and Project' Administration 2,472 4,273 6,653 10,517 Sub-To tal 51,214 95,526 150,939 253,565i Tra nsmis sion Working Capital 1,000 1,000 1,000 1,000 R e s a rve Funds 8,900 12,000 16,300 22,200 Fiscal and Legal and Project Administration 2,300 3,000 3,790 Sub-Total ' 5,000 12,200 16,000 21,090 28,200
- a1 I- vestment Cost Cen r - - 319,864 Tran- >i o n 552,809 867,220 1,390,406 163,945 210,392 292,158 349,297 m
483,809 763,201 1,159,378 1,739,703 e
. s'
. n;.c ru.g
.V. . - i' Cauh.na. .\ s ca s be readily en- Total Inve stment Cost tc 1990 vi: . a d fro.. ar. en .una:ior of the backbone n . . d o. - ._,m'.s-:u- n.a p* logic.:1 ca :..!ida tes T.ible 3 show:. the total investment cost for the initial
.t . >
con ... .:ior. vo sd d .. th . S,ou t h C:. ah.na . project and the cumulative tmais to 1980, 19S5 and 1990 r e ,..uc e se rvi c. A u t ha r n.y anu Central E.lectr c 1> owe r In order to indicate the magnitude of inv .stment in dii-ferent types of facilities, a brcakdoun of direct project uupe ra ter . d,outa Carolina a nd municipal v, stems . in Socu.. C a : m. .u. + and Vi rginia, particularly the _ _ _ . costs has been made between nuclea r, fos sil fired
- D..n vim e , V. ii sys:em. pmnped storage and gas turbine gene ration and t ra n s-mi s sion. These direct project costs include ali engineer.
sn c '.m ,
.. .o.
a ha , , ace n nos sible of coo rt.inatt an ,. . ing and inte re t during construction, plus ample allow-v.1'. n.. -ia s ed l.a nue- Diste u rog ra m o f nutlt.t- sta te . a nce Jor contingencie s, t raining and sta rt -up co :,t e ,. . ' c i a mount s, th e re fo r e, repre sent the estimated plant invest., e, ten: aince ent;ineerina" st udie s of t,r:. L,entral
* ..t
. ec. ve not yet b<en cornpleted and reported ...cm cost s that would appea r on the books o:. L,i. .,,, excep.
- or the initial nuclea r fuel cot e loau,.
4
. e. u e r s t'n t ' tvc joimly developed the
.. ?PIC ola a ho ve, howeve r, contributed In addit. ion to actual plant inve stment, tt will be neces]
'. si-8 ;t.t
.o r u se by Ya n',.ee-Di>:ie enginee r s in their sary to provide for intttal nuclea r fuel core, wo rki ng t atR
- te ;.
capital; it scal, legal and adninu st rative o r ga niza: ion
. 'M O ; :. T (:
.. A .X. a lO N A N CI N G costs and project constructior administ ration. The 1mou computed for total investme it als'o include; an a mount to
_n . .; V e , . . ;, t .he .,rojec t co st a and e stiinates of establish a bond reserve funu equal to at lea s: one yea r's principal and interest payments. Iloweve r, in actual t ,. . . nninec cs ;oe,a:. with construction cost
; vu:. s, v ., a. c ."u .> unof t,. .
financin"e and operations, it may be decided to build up
. p e c e c t . . t tu r e s b e"r u.au m'-
4
- ...a .c. - i :
- oje c t . n..i . 5c ub.r. . . t h s- co st a. tac.'
tit - such re se rve fund s f rom current net pou e r t evenue s ten . :eded :. - each a t- the succeet.:ng 7 yea rs to 1990 rather than fundin"o them f rom hond issues and loans. In e :imati: ,.
. .ual c o s t s, tixed charge rate s were
, Zicd :o n . * : :vestmcet cost and annual cperation A s shown on Table 3, gene ration repre sent s approxi-
. . . nte: :.cc cost were estiuated and added to mately 2/3 and transmission 1/3 of the initial project in-
- i: cd e ' t rge ve s tment. 13y 1990, however, transmis sion re pre sents only 2 5% of the total inve stment. This is due to the large
'i'he calc ~.h tion of inve stment co st ha s bee r. pre- initi 1 investment in constructing the bachhone trans:nis-pa ed n i: .
"t c o a levels in o rde r to u.de
. sion system, primarily the 500 kv facilities.
rea: , 1
-ale . . ri , s :o p. e s. .: powerc.,ts. '. l a o . ve > a '
com : .he .nitia: p roject devel(.p- General plant investment is not shown in T ble 3 incel, me.:t , nd a; ,,:s is IMO have been esca!ated to this cost ha s been handled in the annual cost estimate s, e: unated !- - .. ice L v. Is .a order ta evaluate Als n t shown are additional investment cost s t!.at would, Oc rman - ' . .nc;.ng that will be recuired be associated with maintaining higher capacity reserve ' levels if the 1 Plc system is not interconnected wi:h other
~
% - ; o: s'
. . 1 prcject.
major electric utilities in the area. e
PROJECT AND TOTAL INVESTMENT COST (Based on 1975 Price Levels) . Additions Initial to 1980. 1980
$(000) $(000) $(000) !
Lc r e et Project Cost
! clude r Enginee ring, Inte re st During Construction, .
-O:ntinp nc is ti, ~2 raining and Start-up and Price Escalation)
G e ne .-a rion _ l-
':uclear 172,636 167,828 340,464 Conventional Fossil 142,058 0 142,058 Fr .i.eJ .:...aage ,
,, 0 62,S85 62,885 Gas Turbine _ -- 15,489 0 15,489
ub -To t al ,7 330,183 230,713- 560,896}
T rn us mi s sion , , 180,577 50,749 231,326 Di rect Project' Cost . 510,760 281,462 792,222
'C9.e r Inn:stnwat Cost s Y *
' G ere r tion.
I .::ial' Nuc1ca r Fbel Core f 29,027 ?.9,027 58,054 Ylorhing Capital. , 3,844 2,802 6,646 R e:.e rve I'und s -
, 23,040 16,515 39,555 Tiscal and Legal'and Project A'd ministration 3,037 2,223 _5,260lg Sub-Total ,
58,948 50,567 109,515 T rc u s mi o.sn ' i Vlorkint; Capital ' 1,190 0 1,190 R e se rve - l'und s 10,591 3,689 14,230
.Fi ., cal 4 n.! : ogal and Project Administration- ----- - 2,737 - 833 3,510 Sub Total 14,518 4,522 19,040-
.. a:':e r Inve stment Co sts- -
73,466 55,089 128,555'
. . ,-i' Inve . ar'C at .
w- . ti v 389,131 281.,280 670,~11 T. ni:, on 195,095 55,271 250,366,I
'Cotal 584,226 336,551 920,777~
_ - . - - . . _. ,. - - - - _ . _ h
- -~ . -- _ - , _ _ - - - _ - -. - - _. _. - .- . _ - -
initial Praject Cos:s and Financing and the investment in fossil fired s: cam anit: em ~ drcp to about 1531. Pumped storage cost = wil. == a..'y - Tab 4 sets fo rth the e stimated initial project represent iess than ICL of the investment al hau:.;h re- [os s plus additicas to' 1950, the end of the develop- presenting almost IS% of the capacity, since as the nc:nal period, .and the total investment for which funds ~ 7 project approaches ultimate development, unit installed r.u st be secured :h rough long-term financing during--- - costs per kw reduce substantially fro'm initial unit costs. hc.pericd to 1950 As shown on Table 3 the total initial direct project Th cifc-ets of rising construction costs a re well generation cost is $330,000,000 and transmission cost
, n.w n .o every ci:inen, ..ad price escalation in the is $ 180,000,000 for a total of $510,000,000. By 1950 tos: o? constructum major project features must be the comparable direct project cost of generation is retimated in evaluating the initial funding reouirements. $ ~51,0; ,000 n.1 of transmission is $231,000,000 for a total of $792,000,000.
Nucle.:.r powe r plaiit costs appear to be in a cur rent
- ste ci particri . sly rapidly rising costs. This factor To these direct project costs, the additional other a s tec n carciull- considered in evaluating. nuclear investment costs total $73,000,000 and $129,000,000 t r zus ccrventiw:.1 base load fossil fired generation respectively for the initial and 1980 project developmen:.
n :%- sv a rall e jan.sion plan. If this trend cont'inues Note that the initial nuclear fuel core represents about furitl linal project development,'some shift may have one-half of this additional investmenf and that capitalized t, be :o.de by replacing nuclear units in the western reserve funds represent the c . cat bulk of the rest of other
~; of N state whe re fossil fuel is lowest, with inve stment costs. Note that no bond discount ha s been onver.tional gene ration. Iloweve r, on the ba sis of included in the capital investment totals since it is
.;ceted 1975 price levels that can be ' estimated to- understood tnat the North Carolina Local Government Ly, t .c nuclea r units in combination with pumped
~
Commission is not likely to approve any bond issue sold torage hold a dafinite aconomic edge over supplying a t le s s than pa r.
.c load ircm :.11 fossil fired generation or a combina-lon of fa ssil fired plant s and pumped storage. ' Flexibility in arrangag principal payments on debt service and building up all or a portion of the re se rve Looking at Table 4, the nuclear p! Int investment funds from revenue will be important factors in the de-e .rc 2cr.:s onl; h li the t.nal initial project inve st- termination of the rates finally set to recover power i ; 2nc r:-ion. Additions of nuclear units and costs from participating systems.
m~,ed .5:orage in the p riul to 1980 alter the ratios
.:ch th:.: by IW the ir.. e st ment cost in gene ra tion is Financing E nuc! car, 2 5% fossil fired steam plants, 10%
- .ged s: crap- and le s u than 55 'ga s tu rbine s. Since It is anticipated that tne overall financing of the EPIC r.l. c. .cw 5.. ? we fc.; sil fired steam unit is planned project investment will be essentially 100% debt financ-v;c:.i. : c intta.1 deve.!ai, ment, the percentage inve st- ing representing a mix of municipal electric revenue
. . . c. n le a . i!! ri r. :o appec4ximatuly 70'", by 1990 bonds, long-te rm loans from the Federal Rural Electrificat; TT . .
7
Administra ian and private long-term debt financing. construct and operate the proposed CPIC prafeet is ob-The fixed charge rate s used in calculating annual co::,ts viou s. Such organizational requirement >, howeve r, woul. represent a range of interest rates and mix of funds proceed in definite phases: that appears reasonable based on average historical costs of money in recent years" . Phase I - From date of decision to proceed with final planning of the project to the approximate date of financ-Annual Cests ing. All of the year by year annual cost of power from Phase II - From date of financing and start of construc alternative power supply plans studied have been pre- tion to date of commercial operation.
. pared in work paper form in the cifices of the two engi-neering firms. Thsse work papers are considered pro- Phase III - Actual operation of the initial project and fessionaly ccafidential. The results set forth in these ,
work papers, and subsequent studies that would'be con- continued construction of new facilities to meet future - growth. ducted should be of interest only to the Executive Commit-tee of ElectriCities, the 130ard of NCEMC and individual During Phase I, the actual organization for EPIC need potential pa r:icipants. It is not likely that specific not be large since the bulk of the activity will be admini-figures will be rnade known publicly except in the stering the work being performed by the attorneys and Official Statement used in support of initial financing. engineers and their special consultants in preparing The membership of the orgfnizations can be final project plans, cost estimates, and securing admini-j strative and legal approvals when and as required to - a ssured, hovcover, .that adequate allowance has been Proceed to Phase II. included in the annual costs on which estimated savings 3 have been based to completely pay for all Phase I - Planning and Financing
- costs to own, .oparate, maintain, renew and replace ;
the plant; pay annual principal and interest payments During this phase, the organization might consist
- when due; establish and main:ain adequate reserve primarily of a joint executive committee of the two i funds; establish and maintain working capital; establish organizations and sufficient executive and administrative
- and maintain an organization of capable people to staff to carry the project through to Phase II. Of
. handle the administration and general expense of course, much of the groundwork required for Phase II . , planning, constructing and operating the generating will have to be laid and an organization built up in
- plar.ts, transmission lines and substations; and to sufficient time to move into this phase on a timely iconstruct, operate and maintain general plant and ba si s.
equipment needed to Fause and dispatch the organiza- - ! tion's personnel and equip:nent. Pha se II - Construction ORG A NIZ A T '.ON During this phase, in addition to administering multi-million dollar construction contracts, assisted by the Thu need m r e.taui si.ing an o rganization la plan, engineers, the EPIC organization will have to undert .ke,
L-> J - --,-.-e- -,_ A -,-s- -L E-- --4--a- ---m - 4 4- q---+--w+* -~- . .s aA 4.-- +--O 4 or contract :., have undertaken, the training of its securing certain permits, licenses, certificates and ope rating organizaticn in sufficient time for start-up ' approvals. Also broad descriptions were given in Pa r and shaked .u n ai the physical plant prior to' com- I of ce rtain engineering reports, preparation of expert marcial operation. _ These costs have already been testimony and contract negotiations that will have to be anticipated ..nd included in the estimated direct project .-- --accomplished during this phase of planning and develop
- costs. Somenme during this phase is when it is ex- ment to the point of financing.
- p. c:ed that the non-profit operating organization dis-
~
cussed in *he Legal Report will take shape. A somewhat more detailed description of the engine ing work involved in successfully completing this phase Pha se III - Operation of project development follows. During Phase III, the EPN organization will become Detailed Generation. Transmission and Substation a full fledged operating utility bus.iness responsible Facilitie s for day to day ope rations, long-range planning, con-
- struction and financing of additional facilities. Need- The following detailed studies will have to be includ Icss ta say it would be a rather large and irnportant in the work undertaken during this phase prior to secu org a ni zation.
ing approvals, successful financing, and proceeding wi final design:
- Throughout all of the phases of organizational de- ;
velopment, CPIC should be able to attract capable Site studies. Studies of each generating plant site
' ' people sinec the cha!! cage and opportunities to be on -
will have to be made a s to:
.:he ground ficor of such a brand new, far-sighted project wotdd appeal to experienced utility operators 1) Foundation inve stigations, including geologi-and management personnc1 throughout the United cal reports, core drillings and determination of
- S= te s. It .:a.. been the engineer s expe rience that foundation design loads at the nuclear-conventional some of the nation's top utility executives have been plant site s, and tunnel construction, dam de sign, spill so attracted to other new projects such as the Ilanford way and powerhouse design at the pumped storage site Nuclea r El. c*ric Generating Plant, the Basin Electric Power Cooperativ'e power plant and Missouri Basin 2) Cooling water studies to determine the avail-Systems Group. '
ability of water and the most economical method of providing auxiliary cooling. REQUIREMENTS TO COMPIETE PilASE I - PLANNING AND FINANCING ~3) Fuel and transportation costs at alte rnate sites prior to making final site selections. Ther._ .s already ',een discussed in Pa rt I of this L p.,r; :ha: c 6 1de. :> !e en;ineering, legal and ad-
-1) Environmental studies for nuclear plant sites
- nim ei ratis wark will be required in connection with including hydrological, meteorological, seismological, t
TI 16 8
- - . ._ - - = _ _ _ _ _ . _ . _ . _ - _ -. - . _ . -.. -.
g e.;.c;iral, populatien density, land use, radiological. projected year by year cash flo,w pro form a;.c r .:ing re sult s. This report to establish final sc.ubility and
- 5) Rec reation: ! and fish.and wildlife studies at be used in support of financing.
P.u purnped storage' project site. _ _ ,
.._ _ - Final Rate Design Study
- 6) Mapping as reqsired at all plant sites.
Based upon'the final estimated cost of power from a Transmis sim. Route Studies. Studie s of alternative year by year cash flow operating re sults analysis, de-
- -:um:g s and co s: of transmission line rights of way,
~
velop the final rate or rates designed to be applied to pr;p ration af 1.c,d ow ne rship maps, preliminary plans EPIC members for wholesale power purchases. sni profile drc.uings of rinal selected routes. The other engineering work associated with contract Q trisci Sf s:em Sudies. . Transmission load flow negotiations, expert testimony before courts and com-
.and stability ::a..: die s with r.nd without joint participa- missions cannot be specifically detailed at this time an ':sr. by othe r utilitie s. . Lcss of load probability studies further than ha s already been spelled out in Part I.
L:. iud on force : outage rates of units, maintenance '
- . n.udule s, lead forecaMing latitude, etc. , for de- CONCLUSIONS AND RECOMMENDATIONS ar nining required gene r:, ting re serves. Compilation anc analysis of studies of individual systems. prepared The conclusions and recommendations of the engi-
~
by that system's engi ae rs to determine delivery neers are presented concurrently with the abbreviated points and delivery voltage for the EPIC system. conclusions and recommendations of the attorneys in Part I of this Report. Part III spells out the legal con-P relimi .a ry Des-g and Outlir.e Specifications. To clusions and recommendations in more detail, he prepa red s:. :11 major project features as the ba sis for .inal project planning and detailed cost estimates. It is sufficient for this Summary Engineering Repor' state separately that:
. Final Cart Es:imates and Construction Schedule. .
h.se wauld h:.ve to be prepared for all proj'ect 1) The proposed EPIC project has unquestioned features in crder to plan for financing and construc-
- engineering feasbility.
tica e' the prcject.
- 2) The economic fea sibility appea rs to be a ssured, Final l'en =it litd:ec.y subject to completion of the further work d escribed in this Re~ port,. and subject further to adequate pa rticipa-Ba sed on :.re:imin :.cy de sign =, tentative construc- tion by the municipally owned systems in the State act-
- P,n :m :tre.." s, :: :al co.1 c anmate s of construction ing jointly with the Cooperatives through NCEMC.
"' ope r:.n c .. :. r . cc. . . c u u.1 a r rang ement s, plus II-17 I
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- 3) Upon a final finding of feasibility, the proposed '
1
> EPIC project can be successfully financed and operated . '
at lower costs than any otle r alternative power supply
.available to the Cities and Cooperatives.
l - lL Respec tfully. submitted,
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S/ R. W. Beck and Associates S/ Southern Engineering Company Enginee rs for ElecriCities ' of Georgia
; Engineers for.NCEMC i .
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G
III LEG AL REPORT .
, TO ELECTRICITIES OF NORTII CAROLINA
-- A'N D- .
NORTH CAROLINA-ELECTRIC MEMBERSHIP CGRPORATION PREFACE j, to cause, untiring, helpful, who have worked with us. I: n?.y c,;- t:nusual to begin the preface to a work Next, many individual Mayors, Councilmen, Board Mem be p:. . :. _. f, . ecch, or boa:i) with instam .; tate- municipal and Co-op managers and others have, fully ar.
- c..eni ca . .e uhimate conclu sion. But - here it seems ably, given time, understanding, and a ssistance.
r c enh appron.iste but essential. The conclusion is
- .:.:, depil/, we can, and, practically, . we must all State, regiona' and national officials of publicly owned ph.n ar.d inild and v ork together. electric systems, of the American o ublic Powe r A ssoci.
cf NRECA, and of some State and Federal agencies and L .c : , ;r.eant ou r elec tric citie s araong them- missions have rendered valuabic support and informatio ! 61vc: and our s. lect ric cooperatives among them-E d ve :. and both group:, togethe r. And, for our lawyers' part, we thank especially the able
. senior (and junior) men of the engineering firms you hav i . rce. n r .t in aH that you'r engineering, legal and other retained - R. W. Beck and Associates and Southern Engi c.: -:s h;.ve done, and implicit in every. line of ing Company of Georgia - whose engineering report forn .' . ;; ; report, is this mutuality of inte rest and the other part of this volume.
u n k r :a r.ing. , To all these - any many more - our gratitude. AC F NC?/ t.F DG EM EN TS SOURCES AND MATE' RIALS i: fd.'.o .. :. s r.:.t a ra ll y t ha t we , . a s legal counsel, wish
- ' . s ._ : c: in this sumn.a ry of our report to acknowledge In our research and analysis of the problems inhering in
. .. r c i :.al a nd prole . .ional debts to all who have this endeavor, we have (in addition to learning from the
- !
- : - 2 ir .hu: study, which has been, nece s sa rily, persons above gratefully remembered) tried to search oi
. ir : cyc ..nd c.< ten..ive. We remember p rate- take account of, analyze and expe rimentally apply eve ry
. !1y, .iy at, the re spective ;overning g roups of State and Federal Statute, court case, regula tion, com-F* * ::ii C;t:u :. of North Ca rolina and North Carolina mission decision and policy, and to consult all the major
-" professional and scholarly writing, within this extensive
- Whe rsbin Co ry.ra tion. Thi, - Ex ec u t ive C'~~ . . c,i ti , :ir i m.d the !!o:. rd c: Dirce'cirs of field of law.
i
- f. a v,r . -
b . .. r..e in.ly :he .rincipal s f..r whom ve corked; they h.sve been individuals, committed Naturally and properly much of these underlying data is e
- _ _ - - - - _ - _ - - _ _ - ~ . - _ _ - -- - - _ - - - - - . . .-. -. -.
p rofie .c hl:7 .c.nfidential. E.lually (and, in addition, there is but one, true legal issue. It is a s bri ad a s the ,
- b yL 26 ;r. ..
- .k.v) we have had, ecnstantly, down technological and practical field ir. th'e compt.nion report.
Ire:N . m.
.: 6 e c t, th raugh our working paper s, It is this:
O. rough ir:e r:. and detailed written and oral reports to . ycu, ar.J up t , :h: s moment, to distil and summarize. Legally, can all those reported and recommended plar plants, facilities and means be accomplished? T1.e en 3 product is this legal report, which must be and is,
- in =hort ar.d la rguly non technical language, but, we hope, ANSWER TO LEGAL ISSUE er. coir.pa ssing of all considerations.
Yes. Tl!E TACTS STATEMENT OF LEGAL CONTEXT - At th.. f.reshc'd of every brief, opinion, important ' c ra .ra c t a nd :ca ,e , and simila r documents, lawyers state, As we indicated it,would be inappropriate, in this type of iFpre:r.ises ar.d summa ries, the.large facts which impel report, to include legal citations, or to run to detail, or . a n.1 dciine t!. .: endeavor or matter in concern. We do so even to advocate. Our function, he re, is to report legal h f f'- conclusions, based on our study. Iloweve r,- it is appro-priate and essential, that we 1) describe the legal hous-A s the reprt en:npanion to this shows, . ur Engineers ing for these projects, and 2) with our ultimate reasons. are rerealing to you a plan for providing, th rough se- support our conclusions on the validity of that housing.
. cure aaure;3 cud economical mea'ns, adequate electric pi.wer tu cur Cities and Co-ops with which they, at re- B riefly: % !!, raay 1,c:te r serve our people. The heart of that
. p!a r. :s . tecl slojically ra tional gene rating and trans- Generating plants and some associated facilities will 1
" i s siar. ph:r. c;c s tenuive in time 'with the boundaries of
. owned, mainly, by the electric cities. The ownership w:
' n!! ci No:-: C:.rclina a s it thu s can be coextent.ive with he in tne legal form of undivided tenants-in-common wit! ~ the needs ci a!! the people of North Carolina who wish right of partition. The respective piares of ownership to-pos ses s and . ave consumer-owned power. This
. will be proportionate to respective base year (s) bulk pow
- v. ill requi re ; r. tt pl.,nt s a nd line s and multi-millions use s of the respective municipal (and othe r) entitie s, of do!h r = . i ra s will entail gene ration, t ra n smi s sion, dist ribu: ion, pechably regional inte rconnection:. and Tra nsmi s sio n, and certain associated facilities, will ran d:c. ::, ar.d the coordination and operation of he owned, mainly, by the cooperatives. Such ownership a!' of tho se. will probably be held by NCEMC but may also be either or both of 1) individual Co-op owned or 2) undivided
' 1 J.G A I ISS'li: tenants-in-common without right of partition. a ca tego ries, g reat and . mall,
/. : ti. r.:. - .w,v-i..d Distribution, with its associated facilities, will contir l, ,. c if.c le;..I ;ue stion s, prcSlems and conce rns, individually to be owned by the individual Cities and Co-c
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i I As to operation: period of years from the system. All ger.eration and transmission will be operated by The loans of the Co-ops will be secured the same wa One state-wide non-profit corporation whose governing and/or by other ways appropriate to Co-ops. hea rd(s) and officials will be d emoc ratically and pro- _ portionately designated by the participating Cities and The principal and interest costs of repaying all such Co-ops. loans have, by our engineers, been factored into all the calculations for building and operating this system. Distribution will continue to be operated individually by the respective Cities and Co-ops and retail distri- Upon this basis, if feasibility continues indicated, ot bution rates uill continue to be set by them. national financial advisors have told us all such bonds v be readily marketable. The. rate s which all Cities and Co-ops (both those
- served by direct connection and'those otherwise pro- De.velopment costs, in the planning (not construction' v'ded) pay for 'culk power, after being structured by stages of so vast a project, concerning engineering, e.s good and uniform unlity business practices for load cutive, legal and other expenses, will require advances fe.etors and the like,- will be uniform for all Cities and of money by cities and co-ops, for two or three years, C o -ap s . of which will be refundable to them from the first bond
- proceeds.
As to cost: ' i That is the legal housing. The cost to construct, or in accounting terms, the opital cost of all generation and transmission facilities, Now, to see how we can begin to build that legal housin; will not require the expenditure'of a single dollar by let us clear away some legal underbrush. 2.ny 'or all of the Citie s or Co-ops. One hundred per cent of such cost wi;l be provided by two sources: The following are indisputable facts and principles of le life in North Carolina.
- 1) Revenue bonds, issued in respective and pro-partionate amounts, sinndtaneotisly, by the Cities; As to every City:
- . nd It can own and operate its own generation, transmist RFA ar.d market loans by the cooperatives. and distribution.
No general abligation bonds will be issued by the The generation can be by any and all means of hydro Citie s. - fossil fuel, nuclear, gas or oil fired or, indeed, any meant .
'I h e r e ve:s . ~.:ds of thi: C:tiet, will be se, ured by cd. racts of : .e Citie s to take and pay for power over a For these purposes it can cond. mn and own land and i
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