ML18018B566
| ML18018B566 | |
| Person / Time | |
|---|---|
| Site: | Harris  |
| Issue date: | 02/16/1984 |
| From: | Mcduffie M CAROLINA POWER & LIGHT CO. |
| To: | Toalston A Office of Nuclear Reactor Regulation |
| References | |
| RTR-REGGD-09.003, RTR-REGGD-9.003 NLS-84-049, NLS-84-49, NUDOCS 8402220196 | |
| Download: ML18018B566 (94) | |
Text
REGULATORY . ORMATION DISTRIBUTION SY 'M (RIDS)
ACCESSION NBR;8402?2019b DOO,DATE: 84/02/1e NOTARIZED: NO < DOCKET 0 FACIL:50-400 BYNAME Shearon Harris Nuclear Power Plantg Unit ig 'Carolina 050o0400
'AUTH AUTHOR AFFILIATION MCDUFFIE<M,A, Carolina Power 8 Light Co, RECIP,NAME REC1PIENT AFFILIATION TOALSTONgA.L, Division of Engineering
SUBJECT:
.Forwards addi info requested for antitrust review in connection w/OL app/ication. Info prepared per Req Guide 9+3>
Response to Reg Guide- 9,3 also filed on behalf of North Carolina Eastern Municipal Power Agency, DISTRIBUTION CODE! Z998S 'COPIES RECEIVED;LTR ENCL SIZE$ gg 7ITLEt Antitrust Info Ae Reg Guide 9,3 NOTES:
RECIPIENT COPIES RECIPIENT COPIES ID CODE'/NAME LTTR ENCL ID CODE/NAME LTTR ENCL NRR LB3 BC 1 0 NRR LB3 LA 1 0 BUCKLEYgB 01 1 0 INTERNAL: ELD Qb 1 1 NRR/DE/AEAB 07 1 1 Q4 1 1 EXTERNAL! LPDR 03 1 1 NRC PDR 02 1 1 NS I'C 05 1 1 NTIS 1 TOTAL NUMBER OF COPIES REQUIRED: LTTR 10 ENCL 7
dh ~ R I a
,qq III r y r dt dq "'I y ~q(
4 ir i 4
II II d)f
>r
~ ~
I Ii y y 4 yd fr d~ d 4 4'4 fC ~ ll+ 4 d 4 ydrhilA)r ill i'rlJ If
( 'i Il ' I~ ' Ii f g li'dllr(r( i "(qd) f ) Id yq 'I ir'lh d$ /(, h(h ~
) f I" 4
' I g '4 ( '~y ( pyr( t d( qq
~
g(ri)ldhh
~
' (41'Fhh( I II("),0 <dr~) (4(h '>I(K gd',gg'g$ ir f (I', ~
4 da j II Ii rr q Il I l Li trqqq i Ih Ngg i I d
Ll
0 CMP, Carolina Power & Light Company SERIAL: NLS-84-049 FZB 16 1984 Mr. Argil L. Toalston, Chief Antitrust & Economic Analysis Branch Division of Engineering U.S. Nuclear Regulatory Commission Washington, DC 20555 SHEARON HARRIS NUCLEAR POWER PLANT UNIT NO. 1 DOCKET NO. 50-400 ANTITRUST REVIEW OPERATING LICENSE STAGE
REFERENCE:
- 1) January 19, 1983 Letter/A. L. Toalston to J. A. Jones
- 2) September 3, 1981 Letter/J. A. Jones to H. R. Denton
Dear Mr. Toalston:
Carolina Power & Light Company (CP&L) hereby submits one (1) original and twenty (20) copies of the additional information requested (Reference 1) for the antitrust review in connection with the operating license application for the Shearon Harris Nuclear Power Plant. This information was prepared in accordance with Regulatory Guide 9.3.
Along with CP&L's response to Regulatory Guide 9.3 (Attachment I), CP&L also files on behalf of North Carolina Eastern Municipal Power Agency its response to Regulatory Guide 9.3 (Attachment II).
This submittal completes CP&L's input of information for the antitrust review and supplements the information previously transmitted (Reference 2).
Should you have any questions, please contact Mr. Pedro Salas (919) 836-8015.
Yours very truly, M. A. McDuffie Senior Vice President Nuclear Generation PS/ccc (9425PSA)
Attachment:
CP&L Response to RG 9.3 NCEMPA Response to RG 9.3 Resale Rate Schedules CP&L System Map CC: Mr. B. C. Buckley (NRC)
Mr. G. F- Maxwell (NRC-SHNPP)
Mr. J. P. O'Reilly (NRC-RII) 8402220196 840216 (
PDR ADOCK 05000400 PDR 411 Fayettevllle Street o P. O. Box 1551 o Raleigh, N. C. 27602
ATTACHMENT I CAROLINA POWER 6 LIGHT COMPANY RESPONSE TO REGULATORY GUIDE 9.3
4 0
Anticipated excess or shortage in generating capacity resources not expected at the construction permit stage. Reasons for the excess or shortage along with data on how the excess will be allocated, distributed, or otherwise utilized or how the shortage will be obtained.
Response: Since issuance of the construction permit, CP&L has reduced its forecasts of future load growth and has cancelled plans to construct certain generating units and delayed the projected in-service dates for other future units. Currently, the Company does not anticipate any material excess or shortage in generating capacity resources. CP&L continuously studies conditions which affect the electric energy usage and demand requirements of its customers and periodically revises its energy and load forecasts to refle'ct changing conditions. The construction schedule for new generating units is also periodically revised to accommodate the forecasted load growth.'hanged customer usage patterns, changing economic conditions, and implementation of an intensified Conservation and Load Management Program have resulted in a reduction in the forecasted growth in peak demand. This
. lower projected load growth has ca'used the Company to alter its construction schedule to match future resources
'with the forecasted load. Changes in the construction schedule have affected the Harris Plant.
At the time the Construction Permit was issued, Harris Unit Nos. 1, 2, 3, and 4 were scheduled for commercial operation in 1984, 1986, 1990, and 1988, respectively. In December 1981, plans to construct Harris Unit Nos. 3 and 4 were cancelled, in part as a result of the adoption of an intensified Conservation and Load Management Program. The goal of the Conservation and Load Management Program is to reduce the forecasted 1995 peak demand by 1750 MW below what it would otherwise be. Since issuance of the construction permit, revised load forecasts resulted in several postponements of the projected in-service dates for Harris Unit Nos. 1 and 2. Currently,. Harris Unit No. 1 is scheduled for commercial operation in 1986.
CP&L's Board of Directors approved the cancellation of Unit 2 on December 21, 1983. Several factors contributed to the cancellation decision, including cost.escalations due to inflation and changes in regulatory requirements coupled with uncertainty regarding future regulatory changes, the success of CP&L's CLM program, and the Company's ability to advance construction of Mayo Unit No. 2, a planned coal-fired unit.
New power pools or coordinating groups or changes in structure, activities, policies, practices, or membership of power pools or coordinating groups in which the license was, is, or will be a participant.
Response: CP&L received the construction permit for the Harris Plant from the NRC in January 1978. At that time, the Company was a member of the Virginia-Carolinas subregion (VACAR) of the Southeastern Electric Reliability Council (SERG) which is one of the nine councils'f the North American Electric Reliability Council (NERC). There are seven utilities which make up VACAR, including CP&L, Duke Power Company, South Carolina Electric & Gas Company, South Carolina Public Service Authority, Southeastern Power Administration, Virginia Electric & Power Company, and Yadkin, Inc.
The Company is still a member of VACAR and SERG. There have been no significant changes in the objectives of these organizations since the Company was granted the Harris Plant construction permit.
Changes in transmission with respect to (1) the nuclear plant, (2) interconnections, or (3) connections to wholesale customers.
Response (1): In the final Environmental Report (ER) submitted to the NRC, the Company states that all references to 500 kV transmission facilities shown in the plant's initial documents should be deleted. This deletion can be found in Volume 3, page 10.9-1 of that document. Subsequent to the cancellation of Unit No. 2, the Company has cancelled plans to construct the Harris-Erwin South 230 kV line. Currently, the Company plans to add two additional 230 kV transmission lines.
Response (2): The following is a listing of changes in interconnections between January 1978 and July 1983:
Established a new 230 kV interconnection with Duke Power Company near Brevard, N. C.
Removed Method Durham 115 kV interconnection with Duke Power Company near Durham, N. C.
'trengthened tie with Appalachian Power Company by constructing Cane River 115/138 kV Substation.
Increased the voltage of the interconnection with Vepco at Farmville, N. C. from 115 kV to 230 kV.
This 230 kV interconnection at Farmville and another 230 kV interconnection near Chocowinity, NC were later eliminated and replaced with a tie with VEPCO at a 230 kV substation in Greenville, NC.
Increased capacity of 115 kV interconnection with ALCOA at Badin, N. C.
Increased capacity of 115 kV interconnection with TVA at Walters.
Changed the routing of the Halifax 230 kV tie with Vepco from the Roxboro Plant 230 kV switchyard to
.the Person 500/230 kV Substation.
Response (3): Carolina Power & Light provides service to its resale customers through various points of delivery.
Service to those customers requesting transmission service to specific points of delivery is normally provided without the Company having to make major alterations in its transmission system. The attached list provides information on those resale customer connections added from the time the Company received the Harris Construction Permit in January 1978 through July 1983.
CAROLINA POWER & LIGHT COMPANY POINTS OF DELIVERY ADDED FOR RESALE CUSTOMERS (JANUARY 1978 TO JULY 1983)
POINT OF DELIVERY ELECTRIC MEMBERSHIP CORPORATIONS NAME & DELIVERY VOLTAGE Carteret-Craven EMC Cherry Point 115 kV Central EMC Siler City 115 kV Four County EMC Powell 230 kV Lumbee River EMC Hog Swamp 115 kV Lumbee River EMC Raeford 115 kV Lumbee River EMC West Lumberton 115 kV Pitt & Greene EMC Arba 115 kV South River EMC Wade 115 kV Tri-County EMC Falling Creek 115 kV Tri-County EMC Genoa 115 kV Wake EMC Rolesville 69 kV MUNICIPALITIES Date Added Town of Ayden May 24, 1980 City of Lumberton 82 June 1, 1981 NCEMPA Date Added Greenville Utilities Commission December 10, 1982 To'wn of Wake Forest 82 April 21, 1982 City of Wilson f34 June 24, 1983
Changes in the ownership or contractual allocation of the output of the nuclear facility. Reasons and basis for such changes should be included.
Response: In resp'onse to an expression of interest by North Carolina Eastern Municipal Power Agency (NCEMPA) in acquiring ownership interests in certain of CP&L's generating capacity and upon completion of extensive negotiations between CP&L and NCEMPA, CP&L entered into an agreement in 1981 for the sale of an undivided'wnership interest in the Harris Plant to NCEMPA. -NCEMPA consists of thirty-two (32) participating municipal utilities. Of these thirty-two municipal utilities, eleven are former full requirements customers of Virginia Electric & Power Company. A listing of these participants is provided in the response to 1.f(1).
The Company submitted a request for a construction permit amendment to the NRC in a letter and transmittal package on September 3, 1981 to reflect the addition of The issuance of the Construction Permit a'o-owner.
Amendment was received by CP&L from the NRC in a transmittal letter dated November 3, 1981. Further details on the ownership agreement are contained in the amended application and related documents.
Changes in design, provisions, or conditions of rate schedules and reasons for such changes.
Response: In 1977, under FERC Docket No. ER77-485, Carolina Power &
Light Company (CP&L) filed, as in prior rate increase filings, a single rate tariff that was applicable to all resale customers. As a result of a settlement with all parties, the one tariff was divided into two tariffs; one applicable to Electric Membership Corporations (EMC) and the other applicable to municipal'nd private distribution utilities. In developing the two rate tariffs, the Company deleted previous provisions in both rate tariffs that required a 60,000 KV minimum billing demand for totalization of points of delivery served at 115 KV or higher. Also, the Company deleted the 95% billing demand ratchet that had been incorporated in previous rate tariffs. The effective period of the rates in Docket No.
ER77-485 was from December 29, 1977 to August 18, 1980.
In 1980, under FERC Docket No. ER80-344, the Company initially filed two separate tariffs; one applicable to EMCs and the other applicable to municipal and private distribution utilities. As a result of a settlement, the two filed rate tariffs were divided into three rate tariffs. One applicable to EMCs, another applicable to full requirements municipal and private distribution utilities, and the third one applicable to partial
. requirements resale customers. These rates were effective from August 18, 1980 to January 12, 1982.
In 1981, under FERC Docket No. ER81-538, the Company filed three rate tariffs; one applicable to EMCs,'nother applicable to municipal and 'private distribution utilities, and the third one applicable to partial requirements resale customers. The settlement tariff for partial requirements incorporated an 80% minimum billing demand whereas the other two tariffs had no provision for minimum billing demand. The settlement rates were effective from January 12, 1982 to January 1, 1983.
In 1983, under FERC Docket No. ER 83-765, the Company filed three rate tariffs; one applicable to EMCs, another applicable to municipal and private distribution utilities, and the third one applicable to partial requirements resale customers. A tentative settlement of the demand ratchet provisions of the partial requirements tariff incorporated an 85% minimum billing demand whereas the other two tariffs have no provision for minimum I
billing demand. The Phase rates are effective from November 27, 1983 to April 27, 1984, and the Phase II rates are to become effective on April 17, 1984; however, a'll tariffs are subject to refund pending final disposition of this Docket.
1.f(l) List of all new wholesale customers.
Response: Carolina Power & Light Company currently provides service to eighteen (18) Electric Membership Corporations, three (3) Full Requirements Municipal Utilities, one (1) Partial Requirement Municipal Utility, one (1) Private Distribution Utility, and the North Carolina Eastern Municipal Power Agency (NCEMPA) consisting of thirty-two (32) participating municipal utilities. Of these thirty-two municipal utilities, eleven are former full requirements customers of Virginia Electric & Power Company. The participants in NCEMPA have purchased undivided ownership interests in varying'ercentages in some of Carolina Power & Light Company's generating facilities. Since 1978, Carolina Power & Light Company has added only one new wholesale customer f'rom within its service area, that being the Town of Ayden which now is a participant in NCEMPA. Attached is a list of Carolina Power & Light Company's present wholesale customers.
Full Re uirements Electric Membershi Cor orations (EMC)
Brunswick EMC Lumbee River EMC Carteret-Craven EMC Pee Dee EMC Central EMC Piedmont EMC Four County EMC Pitt & Greene EMC French Broad Randolph EMC EMC EMC'alifax South River EMC Harkers Island EMC Tideland EMC Haywood EMC Tri-County EMC Jones-Onslow EMC Wake EMC Full Re uirements Munici al Utilities City of Bennettsville, S. C.
City of Camden, S. C.
Town of Waynesville, N. C.
Partial Re uirements Munici al Utilit City of Fayetteville, N. C.
Private Distribution Utilit Laurel Hill Electric Company
North Carolina Eastern Munici al Power A enc Partici ants Town of Apex City of Laurinburg Town of Ayden Town of Louisburg
- Town of Belhaven City of Lumberton Town of Benson City of New Bern Town of Clayton Town of Pikeville
- Town of Edenton Town of Red Springs
- City of Elizabeth City *Town of Robersonville Town of Farmville City of Rocky Mount Town of Fremont "
- Town of Scotland Neck
~City of Greenville Town of Selma
>Town of Hamilton Town of Smithfield
- Town of Hertford City of Southport
- Town of Hobgood *Town of Tarboro Town of Hookerton Town of Wake Forest City of Kinston *City of Washington Town of La Grange City of Wilson
- Former full requirements customers of Virginia Electric & Power Company.
1.f.(2)
~ ~ List of all transfers from one rate schedule to another.
Response: In 1977, under FERC Docket No. ER77-485, Carolina Power 6 Light Company initially filed a single rate tariff that was applicable to all resale customers. As a result of a settlement with all parties, the one tariff was divided into two tariffs; one applicable to Electric Membership Corporations (EMC) and the other applicable to municipal and private distribution utilities. Through a process of reaching a settlement the following Resale Service Schedules were filed: RS-lg, RS-12A (superseded RS-12),
RS-12B and RS-12C (superseded RS-12A), and RS-12D and RS-12E (superseded RS-12B and RS-12C). Attached are copies of Resale Rate Schedules RS-12, RS-12A (both
'applicable to all resale customers), RS-12B (applicable to EMC), RS-12C (applicable to municipal and private electric distribution utilities), RS-12D (applicable to EMC), and RS-12E (applicable to municipal and private electric distribution utilities) which were all a part of the FERC Docket No. ER77-485. These electric tariffs were effective for part or all of the period from December 29, 1977 to August 18, 1980.
In 1980, under FERC Docket No. ER80-344, the Company initially filed two separate tariffs; one applicable to EMCs and the other applicable to municipal and private distribution utilities. As a result of a settlement, the Company filed with the Commission three electric tariffs.
One applicable to EMCs, another applicable to full requirements municipal and private distribution utilities, and the third one applicable to partial requirements resale customers. Attached are Resale Service Schedules RS-13, RS-13A (both applicable to EMCs), RS-14, RS-14A (both applicable to municipal and private distribution utilities), and RS-14B (applicable to partial requirements resale customers) which were all a part of the FERC Docket No. ER80-344. These tariffs were effective from August 18, 1980 to January 12, 1982.
1.f.(3)
~ ~ List of all changes in licensee's service area.
Response: The general service area of Carolina Power & Light Company has not changed since 1952. Attached is a system map on which is shown the general service area of the Company.
1.f.(4)
~ ~ List of all licensee's acquisitions or
~
mergers.
Response: On April 18, 1978 the North Carolina Utilities Commission (NCUC) .approved in Docket No. E-2, Sub 325, the purchase by Carolina Power & Light Company (CP&L) of Domestic Electric Company which owned an electric distribution system serving an area in and around Rocky Mount, North Carolina. In the same Docket, the NCUC approved the exchange and reassignment of customers between CP&L and the City of Rocky Mount. Former Domestic Electric customers inside the City were reassigned to Rocky Mount in exchange for City customers located outside the City limits of Rocky Mount.
On October 19, 1982 the NCUC approved .in Docket No. E-2, Sub 424, the purchase by CP&L of the electric distribution system owned by Pinehurst, Inc., which provided service in the Pinehurst, North Carolina area.
List of those generating capacity additions committed for operation after the nuclear facility, including ownership rights or power output allocations.
Response: The following is a listing of the current generation additions schedule for CP&L, which includes the Harris unit . This schedule reflects only those generating unit additions for which the Company has made commitments to construct. Based on the Company's long-range load forecast, other generating units will be needed in addition to those listed; however, CP&L has made no commitment to a particular unit site, type, size, or in-service date.
IN-SERVICE DESIGN UNIT DATE TARGET RATING OWNERSHIP Harris No. 1 1986 900 MW 754.5 MW CP&L 145.5 MW NCEMPA Mayo No. 2 1991 720 MW 603.6 MW CP&L 116.4 MW NCEMPA Summary of requests or indications of interest by other electric power wholesale or retail distributors, and licensee's response, for any type of electric service or cooperative venture or study.
Response: CP&L has begun discussions with the North Carolina Electric Membership Cooperatives and the City of Fayetteville to explore the possible sale to them of certain ownership interests in some of the Company's generating plants and, in the case of the Cooperatives, in transmission facilities also.
14
0
- 2. Licensees whose construction permits include conditions pertaining to antitrust aspects should list and discuss those actions or policies which have been implemented with such conditions.
Response
The following is a listing of all commitments contained in the construction permit for the Shearon Harris Nuclear Power Plant, along with a statement of CP&L's actions to comply with each commitment.
Commitment No. 1:
APP licant recognizes that it is generally in the public interest for electric utilities to interconnect, coordinate reserves, and engage in bulk power supply transactions, in order to increase electric system reliability and reduce the costs of electric power. Bulk power supply arrangements should be such as to provide benefits, on balance, each to applicant and to other participant(s), respectively. The benefits to participants in such arrangements need not be equal and the benefits realized by a small system may be proportionately greater than those realized by a larger system. In implementing the commitments which it makes in the succeeding paragraphs, applicant will act in accordance with the foregoing principles.
Response
CP&L recognizes that it is generally in the public interest for electric utilities to interconnect, coordinate reserves, and engage in bulk power supply transactions in order to increase electric system reliability and reduce the cost of electric power.
Therefore, CP&L maintains 34 interconnections with surrounding utilities and is a member of the Virginia Carolinas Reliability Group (VACAR), which in addition to CP&L includes Duke Power Company, South Carolina Electric & Gas Company, South Carolina Public Service Authority, Southeastern Power Administration, Virginia Electric & Power Company, and Yadkin Inc. Member companies of VACAR coordinate to maintain adequate spinning reserves throughout the group and have standard agreements for the interchange of spinning reserve capacity and energy. VACAR companies also have standard agreements for the direct and third-party interchange of the following types of energy transactions: Emergency, Short-Term, Limited-Term, and Economy.
CP&L also has similar agreements for the interchange of power with other neighboring utilities, such as Appalachian Power Company and the Tennessee Valley Authority.'n addition to the interchange agreements with neighboring utilities, CP&L has a standard transfer agreement with Duke Power Company, which allows the transfer of energy between the eastern and western portions of CP&L's service areas, over Duke transmission facilities.
Commitment No. 2:
Applicant will interconnect with and coordinate reserves by means of the sale and exchange of emergency bulk power with any entity or entities in its service area engaging in or proposing to engage in electric bulk power supply on terms that will provide for applicant's costs (including a reasonable return) in connection therewith; and allow the other participant(s), as well as applicant, full access on a proportionate basis to the benefits of reserve coordination. ("Proportionate basis" refers to the equalized percentage of reserves concept rather than the largest single-unit concept, unless all participants otherwise agree.)
Response
CP&L is currently interconnected with and can exchange emergency power with other entities located within its service area which are engaged in bulk power generation. These entities include SEPA preference customers, the City of Fayetteville, and a number of small cogenerators.
Commitment No. 3:
App licant w ill purchase from or sell "bulk power" to any other entity in its service area engaging in or proposing to engage in the generation of electric power in bulk at the seller's cost (including a reasonable return) whenever such transactions would serve to reduce the overall costs of new bulk power supply, each, for itself and other participant(s) to the transaction, respectively. ("Costs" refers to costs of bulk power supply determined in accordance with the seller's normal practices, without regard to the purchaser's intended use of the power or the status of the purchaser.) This paragraph refers specifically to the opportunity to coordinate in the planning of new generation, transmission and associated facilities. If applicant questions the desirability of a proposed transaction on the ground that it would not reduce its overall bulk power costs, it will make available upon request to the entity proposing the transaction such information as is relevant and reasonably necessary to establish its bulk power costs.
Response
Carolina Power & Light Company (CP&L) has always strived to conduct transactions for the purchase and sale of bulk power that would serve to reduce the overall costs of bulk power supply. This is evidenced by CP&L's efforts in negotiating and reaching agreements with the North Carolina Eastern Municipal Power Agency (NCEMPA) for (a) the purchase by NCEMPA of an undivided ownership interests in several of CP&L's generating facilities, (b) the fueling of these generating facilities, and (c) the provision for the transmission of supplemental service to NCZtPA. These agreements became effective on April 22, 1982. The benefits of this sale will be realized by the Participants of NCEMPA as well as customers of CP&L.
Under the requirements of PURPA, CP&L has negotiated with several customers and private developers for the purchase of power derived from -cogeneration and small hydro power production. CP&L has developed rates for the purchase of such power and presently have several customers under contract.
18
Commitment No. 4 Applicant its w ill facilitate the exchange of bulk power by transmission over system between or among two or more entities with which it is interconnected on terms which will fully compensate it for the service performed, to the extent that such arrangements reasonably can be accommodated from a functional and technical standpoint.
Response
CP&L currently has agreements with the VACAR companies to transfer power through its system as a third-party in power interchange transactions between neighboring utilities, insofar as it does not jeopardize the integrity of the CP&L system. Also, CP&L transfers the power produced by generation capacity owned by NCEMPA to NCEMPA member cities.
19
Commitment No. 5:
APP licant engaging w ill sell power in bulk to any entity in the aforesaid area now in or proposing to engage in the retail distribution of electric power.
Response
Carolina Power & Light Company will negotiate with any entity for the purchase of bulk power from CP&L for the purpose of engaging in the retail distribution of power so long as'he sale of bulk power by CP&L does not adversely impact service to its other service area customers. CP&L in the past has negotiated such sale of power. The Town of Ayden approached CP&L and contracted for the purchase of bulk power for the period from May 19, 1980 to April 21, 1982, at which time Ayden became a participant of the North Carolina Municipal Power Agency. Prior to May 19, 1982, the Town of Ayden received electric service from the City of Greenville which was a full requirements customer of Virginia Electric & Power Company.
CP&L currently sells bulk power to 18 electric membership cooperatives for retail distribution, one private utility and 4 municipal utilities, which are not members of NCEMPA. CP&L is currently engaged in discussions with the cooperatives concerning the possible sale to them of ownership interests in certain of CP&L's generating and transmission facilities. CP&L is also discussing with the City of Fayetteville the possible sale to the City of ownership interests in certain of CP&L's generating facilities.
1 Commitment No. 6:
The imp leme ntation of these numbered paragraphs shall be in all respects on reasonable terms and conditions as consistent with the Federal Power Act and all other lawful regulation and authority, and shall be subject to engineering and technical feasibility for applicant's system.
Applicant will negotiate (including the execution of a contingent statement of intent) with respect to the foregoing commitments with any entity in its service area engaging in or proposing to engage in bulk power supply transactions, but applicant shall not be required to enter into any final arrangements prior to resolution of any substantial questions as to the lawful authority of an entity to engage in the transactions.
Response
All transactions or commitments as described in response to Commitment Nos. 1-5 above have been made in good faith and with the intent of complying with all applicable laws and regulations.
Commitment No. 7:
In c ont racts between applicant and its wholesale customers, applicant will not attempt to restrict such customers from electrically connecting with other sources of power if reasonable written notice to applicant has been made and agreement reached by the parties on such measures or conditions, if any, as may be required for the protection and reliability of both systems.
Response
Carolina Power'& Light Company's General Terms and Conditions for Resale Electric Power Service allows the resale customer to receive service from other sources of power as long as reasonable written notice has been given to CP&L and agreement by both parties has been reached. The Power Coordination Agreement between CP&L and the North Carolina Fastern Municipal Power Agency (NCEMPA) allows NCEMPA to pursue other sources of power. At the present time, a contract exists between CP&L and French Broad EMC (FBEMC) whereby FBEMC is to receive power from a restored hydroelectric facility in conjunction with power received from CP&L. With the requirements of PURPA and its effect on the purchase of power by resale customers, CP&L is prepared to negotiate with our resale customers as their purchase from other sources of power.
it relates to ATTACHMENT II NORTH CAROLINA EASTERN MUNICIPAL POWER AGENCY RESPONSE TO REGULATORY GUIDE 9.3
l.a) Response: Not applicable to Power Agency.
- 1. b) Response: None.
l.c) Response: Not applicable to Power Agency ~
1.d) Response: Th'e only change in the ownershi p or contractural allocation of output of Harris Unit No. 1 results from CP&L's sale to Power Agency of a 16.17% undivided ownership interest in the unit. Power Agency's ownership interests entitle it to receive 16.17% of the capacity and'energy output of Harris Unit No. 1, subject to Power Agency's sale to CP&L of Purchased Capacity and Energy in amounts declining to zero over a sixteen-year period following the Date of Commercial Operation of the unit.
l.e) Response: No such changes have been made by Power Agency, other than increases. ~
1.f) Response: None for Power Agency.
1.g) Response: The only generating capacity addition committed for operation after Harris Unit No. 1 is Unit No. 2 at the Mayo Electric Generating Plant. CP&L's current construction schedule calls for achieving commercial operation in March 1991 for Mayo Unit No. 2. CP&L owns 83.83% of Mayo Unit No. 2 and Power Agency owns 16.17% of the unit.
1.h) Response- Power Agency has not received any request or indication of interest by other electric power distributors for any type of electric service or cooperative venture or study .
2.) Response: Not applicable to Power Agency.
(9425PSA/ccc)
ATTACHMENT I II RESALE RATE SCHEDULES
Carolina Power 6 Light Company FPC Electric Tariff 2nd Revised Sheet No. 5 Volume No. 1 Superseding 1st Revised Sheet No. 5 RESALE SERVICE SCHEDULE RS" 12 AVAILABILITY Service hereunder is available throughout Company's area of service from Company's existing facilities of adequate type and capacity, for use 'and resale by a municipal utility, private distribution utility or an electric membership corporation.
This Schedule is not available for breakdown or standby service. Exceot as may be agreed to bv Company in writing, this Schedule is not availabie for supplementarv service other than for "Excess Power and Energy" sold to a Government preference customer.
APPLICABILITY This Scheaule is applicable to all elect ic service of a single type delivered at one point through one metering installation at, or compensated to, the poin" of delivery. This Schedule shall apply to each point of Qeliverv separately, except metering will be electrically totalized for single rate application where Customer takes delivery of all service at each point at a voltage of 115 D'r higher and accepts a minimum Billing Demand of 60,000 KV.
TYPE OF SERVICE This Schedule is applicable to alternating current, 60 c)cles per second (Hertz), three phase electric service at the voltage set forth in Exhib t A for the point of deiivery.
MONTHLY RATE S 3t'0. 00 plus 5.00 pe" 45'f Billing Demand 1.19c per i'NH for all IQCH 15c pe" V/AR for all Excess KVAR (See POt~R FACTOR ADJUST<ENT)
Adjustment: The bill computed under the above Monthly Rate will be increased or decreased by an amoun" calculated in accordance with Company s appl'cable rider(s), which is incorporated as a part of the monthly billing under this Schedule.
DEKkND >' ENERGY DETER~flK'TION The kV of metered or computed demand shall be the kilowatts metered o.
computed during the fifteen-minute period measured in ffteen-minute clock hour .'ntervals except as prov'ded n the General Terms ana Conditions, of greates t energy use during the current month, appropriately adjusted to preclude the duplication of any demand caused by switching of loaa between Issuea by: Effective: Julv 29, 1977 James i~.'. Davis, Jr., ~fanager Rates 6 Service Practices Issued on: June 29, 1977
Carolina Power & Light Company FPC Electric Tariff 2nd Revised Sheet No. 6 Volume No. 1 Superseding 1st Revised Sheet No. 6 Customer's points of delvery served by Company. The Billing Demand shall be the metered or computed demand, less the Government preference customez demand allotment, if any, for any point of delivery but not less than 95%
of the greatest metered or computed demand (less the Government preference customer demand allotment, if any) in the preceding months of June, July, August and September. Notwithstanding the foregoing, when a point of delivery is added or load is transferred between points of delivery, the preceding June, July, August and September metezed or computed demands at each point of delivery from which load is transferred shall be reduced, for the purpose of future determinations of the minimum Billing Demand hereunder, to reflect the metered or computed demand had sucn new point of delivery been in existence during such period. The total by which the demand of the existing points of"delivery is thereby reduced shall be considered as the preceding June, July, August and September maximum metered or computed demand at the new point of delivery.
Prior to the billing date, Customer will provide written notification to Company of each load transfer, to a point of delivery served by Company, including the names of the points of delivery involved, the amount of load being transferred and the effect that such load had on the actual maximum demand, in the previous months of June, July, August and September. A load transfer zor 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or less will not be considered for current or future billing as having been served at the point of delivery to which was it temporarily connected; however, load which is tempo=arily connected to another point of delivery will be considered for current and future billing as having been served at the point of del.ivery from which it was temporzz'ly transferred.
Monthly metered or computed demand and energy quantit'es shall be reduced by the monthly kilowatts of al.lotted Contract Demand and kilowatthours of a Government preference customer as determined in the Government-Company Cont act.
A p eference customer's monthly kilowatts of total allotted Contract Demand vill be prorzted among Customer's points of delivery in proportion to month'y delivery point maximum metered or computed demands of Customer..
POiiER FACTOR ADJUSZKXT When the power factor, determined in accordance with the Gene.al Terms and Conditions, in the current billing month is less than 85/, the monthly bill will be 'increased by a sum eaual to S0.15 multiplied by the dif ezence between the maximum reactive demand (HVAR) metered or computed dur ng a ifteen-m'nute interval and 62% of the maximum 9'emand metered or computed in the current billing month.
PAPER'T Suoject to the applicable provisions of the General Tez..s and Conditions, bills aze due when rendered and are payable within 15 days from the date of the bill.
Issued by: Effective: Julv 29, 1977 James H. Davis, Jr., Manager Rates 6 Service Practices Issued on: June 29, 1977
Carolina Power & Light Company FPC Electric Tariff 2nd Revised Sheet No. 7 Volume No. 1 Superseding 1st Revised Sheet No. 7 CONTRACT PERiOD The initial contract period for contracts entered into after the effective date of this Schedule shall be seven years unless Company and Customer agree to a longer or shorter period. Subject to the applicable provisions of the General Terms and Conditions, either Company or Customer may terminate any such contract at the end of such initial period, or at any time thereafter, upon three years'ritten notice. Customer may, upon three years'ritten notice, terminate within the initial seven-year period, by reimbursing Company for the unamortized portion of its investment in transmission, distribution and transformation facilit.'es installed by Company for such point of delivery to the extent devoted to Customer' service, in accordance with the General Terms and Conditions.
When Customer's load growth reauires and Company agrees to install add'tional transmission., distribution, or transformation facilities for services to Customer at a point of delivery, the contract period for the point of delivery will automatically be extended for seven years unless Company and Customer agree, in writing, to a different extended contract period.
The provisions set forth herein shall not apply with respect to any facilities installed as additional facilities, and the charges for any such additional facilities shall be in accordance with the contract between the parties.
GE."ZRAL Semice under this Schedule is subject to the provisions contained in Company's FPC Elect'ric Tariff filed with the Federal Power Commission.
Nothing contained herein shall be construed as affecting in any way the right of the party furnishing service, under the rate schedule, to unilaterally make application to the Federal Power Commission for a change in the rates, charges, classification, o service, or any rule, regulation, or contract related thereto, under Section 205 of the Federal Power Act and pursuant to the Commission's Rules and Regulations promulgated thereunder.
issued by: Effective: July 29, 1977 James ."l. Davis, Jr., Manager Rates & Service Practices issued on: June 29, 1977
Carolina Power & Light Company FERC Electric Tariff 3rd Revised Sheet No. 5 Volume No. 1 Superseding 2nd Revised Sheet No. 5 RESALE SERVICE SCHEDULE RS-12A AVAILABILITY Service hereunder is available throughout Company's area of service from Company's existing facilities of adequate type and capacity, for use and resale by a municipal utility, private distribution utility or an electric
'membershi.p corporation.
This Schedule is not available for breakdown or standby service. Except ~
as may be agreed to by Company in writing, this Schedule is not available for
'upplementary service other than for "Excess Power and Energy" sold to a Covernment preference customer.
APPLICABILITY This Schedule is applicable to all electric service of a single type delivered at one point through one metering installation at, or compensated to, the point of delivery. This Schedule shall apply to each point of delivery separately, except metering will be electrically totalized for single rate application where Customer takes delivery of all service at each point at a voltage of 115 KV or higher and accepts a minimum Billing Demand of 60,000 Kfl.
TYPE OF SERVICE This Schedule is applicable to alternating current, 60 cycles per second (Hertz), three phase electric service at the voltage set forth in Exhibit A for the point of delivery.
MONTHLY RATE
$ 340.00 plus
$ 4.69 per KM of Billing Demand 1.19'er KMH for all lGJH 15'er KVAR for all Excess KVAR (See POWER FACTOR ADJUSTAEHT)
Adjustment: The bill computed under the above ffonthly Rate will be increased or decreased by an amount calculated in accordance with .
Company s applicable rider(s), which is incorporated as a part of the monthly billing under. this Schedule.
DEtfAND AND I'.Nl'.RGY DETER.'fT,.".ATIO.f The Kfg o f metered or comput.cd demand shall be the kilowatts metered or computed during the fi teen-minute period, measured in fifteen-minute clock hour intervals except as provided in thn General Terms and Cc nditions, of greatest energy use during the current month, <<ppropri "tely adjusted to preclude. the duplication of <<ny d~'mand caused by switching of load between Issued by: ECfectivc Cor bills rcndcred James ~f. Davis, Jr., !fanaf;cr on and <<Ctcr April 1, 1979, i<ates 6 Service Practices s ub j cc f. to r>> f und issued on: ffarch l3, 1979
Carolina Power 6 Light Company PERC Electric Tariff 3rd Revised Sheet No. 6 Volume No. 1 Superseding 2nd Revised Sheet No. 6 Customer's point" of delivery served by Company. The Billing Demand shall be the metered nr computed demand, loss the Government preference customer demand allotment, if any, for any point of delivery but not less than 95%
of the greatest metered or computed demand {less the Government preference customer demand allotment, if any) in the preceding months of June, July, August and September. Notwithstanding thc fozegoing, when a point of del'very is added or load is transferred between points of delivery, the preceding June, July, August and September m'etezed or computed demands at each point of delivery from which load is transferred shall be reduced, for the purpose of future determinations of the minimum Bil.ling Demand hereunder, to reflect the metered oz computed demand had such new point of delivery been in existence during such period. The total by which the demand of the existing points of delivery is thereby reduced shall be considered as the preceding June, July, August and September maximum metered oz computed demand .at the new point of delivery.
Prior to the billing date, Customer will provide written notification to Company of each load transfer, to a point of delivery served by Company, including the names of the points of delivery involved, the amount of load being transferred and the effect that such load had on the actual maximum demand in the pzevious months of June, July, August and September. A load transfer for 4S hours or less will not be considered for current or future billing as having been served at the point of delivery to which it was temporaril.y connected; however, load which is temporarily connected to another point of. delivery will be considered for cuzrent and future billing as having been served at the point of delivery from which it was temporarily transferred.
Iionthly metered or computed demand and energy quantities shall be reduced by the monthly kilowatts of allotted Contract Demand and kilowatthours of a Government preference customer, as determined in the Government-Company Contract.
A preference customer's monthly kilowatts of total allotted Contract Demand will be prorated among Customer's points of delivery in proportion to monthly delivery point maximum metered or computed demands of Customer.
POINTER FACTOR ADJUSTIENT Ighen the power factor, determined in accordance with the General Terms and Conditions, in the current billing month is less than 85%, the monthly bill will be increased by a sum equal to $ 0.15 multiplied by the difference between the maximum reactive demand (KYAR) metezed or computed during a fifteen>>minute interval and 62%%u, of the maximum kM demand metered or computed in the current billing month.
PATIENT Subject to the applicable provisions of the General Terms and Conditions, bills are due when rendered and are payable within 15 days from the date of the bill.'ssued by: Effective for bills rendered James H. Davis, Jr., Hanager on and after April 1, 1979, Rates 6 Service Practices subject to refund Issued on; Harcli 13, 1979
Carolina Power & Light Company FERC Electric Tariff 3rd Revised Sheet No. 7 Volume No. 1 Superseding 2nd Revised Sheet No. 7 CONTRACT PERIOD The initial contract period for contracts entered into after the effective date of this Schedule shall be seven years unless Company and Customer agree to a longer or shorter period. Subject to the applicable provisions of the General Terms and Conditions, either Company or Customer may terminate any such contract at the end of such initial period, or't any time thereafter, upon three years'ritten notice. Customer may, upon three years'ritten notice, terminate within the initi"l seven-year period, by reimbursing Company for the unamorti"ed portion of its investment in transmission, distribution and transformation facilities installed by Company for such point of delivery to the extent devoted to Customer's service, in accordance with the General Terms and Conditions.
When Customer's load growth requires and Company agrees to install additional transmission, distribution, or transformation facilities for services to Customer at a point of delivery, the contract period for the point of delivery will automatically be extended for seven years unless Company and Customer agree, in writing, to a different extended contract period.
The provisions set forth herein shall not apply with respect to any facilities installed as additional facilities, and the charges for any such additional facilities shall be in accordance with the contract between the parties.
Service under this Schedule is subject to the 'provisions contained in Company's FERC Electric Tariff filed with the Federal Energy Regulatory Commission. Nothing contained herein shall be construed as affecting in any way the right of the party furnishing service, under the rate schedule, to unilaterally make application to the Federal Energy Regulatory Commission for a change in the rates, charges, classification, or service, or any rule, regulation, or contract related thereto, under Section 205 of the Federal Power Act and pursuant to the Commission's Rules and Regulations promulgated thereunder.
Jr' Issued bv: ECCectl.ve for bill" rendered James Il. Davis, , 1'!anagur on and aftor April 1, 1979 Rates 'i Service Practices subject to reCund Issued on: -i!arch I'3, 1979
Carolina Power & Light Company FPC Electric Tariff 3rd Revised Sheet No. 7 Volume No. l Superseding 2nd Revised Sheet No. 7 CONTRACT PERIOD The initial contract period for contracts entered into after the effective date of this Schedule hall be seven years unless Company and Customer agree to a longer or shorter period. Subject to the applicable provisions of the General Terms and Conditions, either Company or Customer may terminate any such contract at the end of such initial period, or at any time thereafter, upon three years'ritten notice. Customer may, upon three years'rit'ten notice, terminate within the initiaL seven-year period, by reimbursing Company for the unamortized portion of its investment in transmission, distribution and transformation facilities installed by Company for such point of delivery to the extent devoted to Customer' service, in accordance with the General Terms and Conditions.
When Customer's load growth requires and Company agrees to install additional transmission, distribution, or tran formation facilities for services to Customer at a point of delivery, the contract period for the point of delivery will automatically be extended for seven years unless Company and Customer agree, in writing, to a different extended contract period.
The provisions set forth herein shall not apply with respect to any facilities installed as additional facilities, and the charges for any such additional facilities shall be in accordance with the contract between the parties.
GENERAL Service under this Schedule is subject to the provisions contained in Company's FPC Electric Tariff filed with the Federal Power Commission.
Nothing contained herein shall be construed as affecting in any way the, right of the party furnishing service, under the rate schedule, to unilaterally make application to the Federal Power Commission for a change in the rates, charges, classification, or service, or any rule, regulation, or contract related thereto, under Section 205 'of the Federal power Act and pursuant to the Commission's Rules and Regulations promulgated thereunder.
Is ucd by: Effective for bills rendered James ~~1. Davi.">, J r., Yianager on and after April 1, L~7'),
Rates S Service Prvcti,ces sub Ject to refund Issued on: ~farch ]3, ]c)7()
Caro'ina Po>>er 6 Light Conpany Revised Sheet bo. 5 FPC elec"-'c Ta-'"= Superseding Orig'nal and 1st Revisec Sne r rs= Rev.'se'olume Yo. 1 No. 5 o Scnecules RS-12 6 RS-'A Elec tric Ne-..bership R:-SM'". SiRVI E Co Do " G~
SCH:.DJLK RS-125 AVATLAH L'IVY Sea- "e hereunder 's available hroughout the Company's area oe spy c fror Co=pany's ezistin~ fac lities of adequate type anc capacity fo use an resa e. by an elect"ic membership corporation.
$ Sched le 's not available for breakdown or standby service.
Zsxcep t as r;ay be ag ee" to by Company in vri in', this Schedule is no ava' able fo= supple..enta y service other than for ""=xcess Poser an" "ne=- y" sold o z Government pre"erence customer..
AT)'D TC Q TT e
~ o Th s Schedule is,appcable to all electric service o= a s'ng'e type del vered a one po n- through one meter'n-. installation at, o" compensated to, the po'n of del.'very. This Schecule shall apply to each point of delivery separate" y; except that a the points of del-ve y served at a vo'tape o. 115EV or hi~her, the K~ o de~and and R~".<<: o" energy vill be totali"ec or single ra=e application.
Pr OP 8Lv.r-.Cr This Schedu'e is appcab'e to alternatirg cur=ent, 60 cvc'- pe=
second (-.: rt=), thre phase e~ectric se ~ice at the vo taoe se= =or=h E.".ib' A for he po'nt oz delivery.
"?ON
3'.00 pe" po n of del've"v 6.18 pe" K~ o" 3ill'ng De'anc 0.88c per Y4"c! for all K4"9 12c per KV~ fo" all Excess yg~
(See POL:"R PACTQR ~JUS i!=.';y)
Ad 'us t-...ent cor.:puted under the a'oove Hont?;ly Rate vill be increase" cecreasec by an amount calculate" in accordance arith the Co=p ny's co" 'a'v b-applicaole unoer h's Sche '.
rider(s), vhich is 'ncoroorated as a part o= Le Issued bv: L=fec-':e ~o" se".v-'ce renderec =ro=
?'orr's L. Edge, Mz..age Dece=ber ~o 1c"", rhru August 17, 1980 Ra es P" ct'ces
I I ~
~%
~~
0 Carona Povar & 7.ight Co-.'..pan: Rev'sed Shee". No. 6 PPC iieet ic Tar'f Supersed'ng Original and 'st Rev'sed First Revised Volume Np. Vo. 6 of Schedules RS-12 & RS-':
The imari of energy sha' 'oa metered or computed at, or compensated o, the po'nt o delivery. Tha K~ o" metered or computed demand sha 1 oe the kilovatts metered or computed during the fi.fteen-."'nute period, measurec in ifteen-minute clock hour 'nt vals except as provided 'n the Genera'e .. s and Concons, of greatest energy use during the currant montn, zppropr ately a'-'us ac to preclude tha dup3.'cat'on of any demand caused by switching o" load bet.-een non-totalized op'nts of dal vary'erved by Company.
(a) For non- otzli"ed points o deve y, the Bi13.ing Derand sha ba the tered or computed demznd, less the Goverr~ent ore erenca customer cia=and allotmert, if any, for that poin o cielivery.
(b) Ppr tota'zed ponts o" del'very, the 3illing Demand shall be the totzlired metered or computed derand, less the sum o. the Government preference customer demand allotments, if any.
Pr or to the bi.ng data, Customer vill provide vr t=en not'ca"'on to Company of each load transfer, incluc.ng the names of the ponts o delive~ invo'vec, the amount of load be"'ng transferred and the effect that suc".. load had on the actual maxi-.. m demand, if any, established during tne cu.rant b'1'ing rpnth. A load transfer fo" forty-eight hours or less ~wll not be considara'or current b1'ng ashaving been served a the point of del'very to vnicn it -zs te-porzrily connected,'owever, load which is "'"
temporzr='y connected to anotner point of del.very chill be considered for currert billing as having oeen served, at the po nt o. delivery from c:hich it vzs te-..porzril y transferred.
The Government pre erence customer's al3.otted Contract Demand and ki.'o"att-hours she':.1 be cie er."ned indapendantl.'pr each po'rt o. cavary p"ipr to totalization.
Monthly metered o. compu a da=.and and energy quznt't'es shall be reduced by the month'y kilos:at s of allotted Contrac- Demand an" kilpvatt-hours o= a Government p.efarence custor.er as date.,.ined 'n the Governmant-Co=pany Con=rap preference customer's mprthly k'loc:at s of to:al allotted Contract De,anc c.'i3.1 be prorated a...ono Customer's oo'nts o. de3.'very 'n propprtipn tp pnthlv del:very point maximum metered or co=pure cier ands of Customer.
p0e ~ ~
F
> r ~0p g+ ~gfc'r>~
xnan ha ppc;er factor, dat .. inad 'n accordance t ith the General Te ....s and Conditions, in the c rrant b 1ng month at an ind"-'idua'oint of del've y is less har. 85':, the mon=h'y bill w'il'e 'ncraased by a su...
equal p SQ. l jul"'lied by the dc f @rance bet+can the maximum reactive kovo't ampe as (KV~~) reg'ste:a= by a demand meter sutaole .for measuring issued Effect'; a for serv'ce rencerac 'rp=
~orris L. Edge, +anagar Dace oa '79 lcII rh u Aurus 17> lo 0
& Serv e P act'ces sued o- Da-e-'-~- 15 1 pQ
IQ
~ ~
~ ~ ~ ~
~ ~
~ ~
~ ~
(IQ
~ 0 ~ ~
~ ~
~ ~
I ~
~ ~
~- ~
~
Caro'inz Po"ar 6 L "ht Cor>>pany 0r'g'n-1 She t No. 7A Supers acing Orig'nal an ls t ¹visad Sh
- irs= Rev'sad 'iclune .io. 'L I ho. 5 ef Schadu'es RS-12 6 PS- 2.
Nunic ipa1 5 Private RESr" " SEE'F CE D st "but on Utilitv SCHEDULE RS-12C
~ T 0 fT Serv ce nareun"ar is ava'labia tiroucrou- the Company's area of ser; ce "o= Co-pan-'s axis:in= =ac=i't as o: adequzt type and capac'=y, for use an"'asa' by a nunicipzl u :y or a pr'vate distribu-'on util'y.
This Schedule is not avai'ab'e for breakdowns or standby service.
Except as nzy be agreed to by Co"..pany in vri in"-, this Schedule is not ava lzb ' for supp'amen ary>> service o-.har than o xcass P var anc Ena soo a Government pre arence custonar.
A~?::C'3 L:~:
Th Scnedule is applicab e to all electric se>>vice oc a sinnla t<<pa da 'vered at one point through one ne erin'nsta'lation at, or co=pensata=
to, the point o delivery. This Schedu'e sha apply to each point or.
deliv ry sepzr te'; except that at the points of del'ver'erved at a voltage o 1' KV or h" her,tha Kii'= de- nd and KVi o energy t.'ll be i total'ed or single ra- app c 'I
-'n.
~PE 0"" SER'F"C" This Schecu'a 's applicable to a'arne ing currant, 60 c, c es per seco¹rt"), tnrea phase alectr=c se" ce a. the vol=aoe set ror h Exh'bi' for the point of delivery.
<<f0
$ 3'.00 plus
$ 5.731 pa>> i~ osC 5S~
3 'so~
1 C~r Bess>> e>> ~
1.05c per Vr n =o a vash~ \~
~
12c pe" HVAR fo z 1 xcess HVAR
>> p>>qg (See ?0~ER ~
0 ~J45>>,l s
~ ~q tI ~
yp qo>>y ')
Ac jus t...ent: The bil 1 co puca>> uncer th0 above ':!anth v Rata increased or decreasac oy an azoun. calcu zte'n accor ance v tn na
's inc"rporzta" zs a part of "na "o=pany's app'.'cable i='ar(s), <<hi '.".
r>>onthly b.'1'.."." under t'.-.'s Schedu'.
Ls sue Q v ~
ance>>ac ger>>is - -ea)
T
~
~I >> re D ar bg>> 1Q ] c+>>'>>>> Aug'.s I, -.00 Rz- es c Sere ~ c r~ g>>qs>> cas ss>>ad Deca- a" '5,
~~
Carolina owa" & Light Compary Origin 'heet i!o. 7"-"
Supersadino Ori"'na'nc 1st 3e sed She-7 rst R v'sed Volume Xi'o. No. 6 of Sche" 's RS-12 & RS-12A ll ~>a ~1+>>he A4 ' i isa~ l% LUlT The K .";: o= energy sha be metered or computed at, or compensated to, the po'nt of dal'very. The KV of metered o" computed demand sha' be the ki owatts metered or computed du ing the fifteen- inuta period, measured fifteen-=inure clock hour inta"vals except as prov ded 'n the General Te s anc Con""tio..s, of greates energy use durino the currant month, anthrop a aly ad-'.usted to prec'uda the duplica= on o= anv demand causec by s.>>.itchirg o:
load betwea.. non-to a ed points of delivery semed by Company.
(a) For non-totalized poi"..ts of delivery, the Billin= Demand s'na" 'ne the r.a red or computed de=and, less the Goverr~ent pra erence custo= "
de"and allotment, if any, for that point of delivery.
(b) Fpr total'zed points o de'verv, the Bi}'ng Demand shpll be the total'zed metered or computed demand, less the sum,o the Govar".=.en=
p-e=aracce cus>>orna>> de and allot eats, if anv.
Pr or to the bi}ling data, Customer wi provide s-.itten not'cation to Company o each load t"ans=e", including the names of the po nts of del've ~ 'nvolved, the amoun= of load be'ng trans erred an"'he ef=ect that such load had on the actual razimum de-anc, if cu"rent billing month. A loa" trans er fo" or y-eight hours or less any, estab}'shed during the ail.
not be c nsidered =or current bill"ng as hav- ng been se.ved a- the po nt of dal've"y to which it was te'porar'ly connected; however, }dad wh'ch .s temporar" v connected to another point of del"'very vill be co..s'cerac for it was te=po"ar '
c 'rrent b''ng as hav ng been served at the pont of da}ivary from whi"h t"ans=er.ad.
T'e Gover"...ent preference cus=omer's allotted Contract Demand anc ki'owatt-hours sha}1 be date'ri inca indapenden<<y fo each pc'nt of da}'v prior to o a}ization.
Yionthly metered or comout ed e~ d a~d a~e gv ouan.. 'es siam' be recuced by the mor.thly ki'owa:=s of al}o:ted Contract Daman and kwatt-hours o a Govern...ant p>>eference customer as de erminad in .he Governmant-Co;pany Contract.
Damanc to A
month'y
-i 'e prer rance customer's nor.thly ki}owatts of total al'orred Con"rac:
prorated among'Custo..e" s po. nts oi dal'ver'.. p.opo del've.y po'nt .mz mum ma e>>ed or computed da nds of Cus o,e-on g0e>> g>> g CttlQQ ~f J'Qg>>l~g tl%
i;hen tha power factor, dere .. nad .'".. acco" ance with "re Genera} e....s an'ond't'ons, 'n =he c rren: b'='"..'on=h at an 'ndv'cu } point of da}: .y is ass tnan 3>-, the month y oi wil } ba incraas bv a sum A CI
'~
aqua':o $ Q.'.2 multiplied bv he d'a=ence between the map, mu. react C
"lovo}t ampares (NV reg'stared by a de=.anc rater su':ab'a for measurin~
"-.)
I.ssued by: >>mac ct vc or sarv ca ana a ac Ferris L. --dga, ~!anager Da elba>> o 1977 th u August 7y 9S0 Pate~ & Sa-"'"e ~"act ces
-'ssued ba>>
y~
~ ~
Caro'ina Power & Light Company Original Shee" No. 7C FPC ilectric Tariff Supersedinm Original and 1st Re:ised Snee Qov-se Vo'u No . 7 o Schedules RS-12 & RS-12 .
the demands use" d ring a ifteen-=inute inteval and 62;! o the rvi-. u-. l">>
demand re"'sterec a. the indivicua point of devery.
Su ~ ct to the applicable prov'sions o he General Tems and Con"" =ions, bills are cue wnen "encerec an" are payab e with'n L5 dzys ro-,. the da e of .
the b.
CONT."=-'.C i P KRTOD The initial contract period for con=rac=s entered into after the e"ect ve date o" this Schedu'e shall be seven vezrs un'ess Company an=
Customer agree to a longer or sho"ter period. Sub-:ect to the applicable provisions of the Genera'-e ..s an" Con" i-=ons, e'thar Cot:pany or Custo= ".
- .ay te .. inate zny such cont"zct a tne enc o such initial per'oc, o" a" any tine thereafter, upon three vears r-.itten notice. Customer azy, up"n three years t=itten not'ce, te=. nate with='n the initial seven-year per'o"',
by reimbursing Co "zn: o" the unzmorti=ed portion of its investnen t=ans-.'ss=on, d stribution and transfor-..a" on facilities instzl ed by Co=pany for such point of del'very to the extent devoted to Custoner's service, -n accorcance with tne General Te=s and Con'tions.
linen Cus=c-.er's load grocah requires anc Co=pany agrees to insra,l add'iona trans-..ission, distr'but 'on, or transforation fa" serv ces to Customer at a point o devery, the contrac: period ilit -or
'es po'nt of de ivery will autoczticzliy be extended for seven years unless Co...pan: anc Gusto=e" a"ree, in writing, to a di.farent contrac=
extended'erio".
The provisions set or:h here n sha not apply with respect to any facilities insta le" as adc onzl =aci't.'es, an= the charges for an, such adc'onal fact.'es shaLL be in accordance with the cont"act between he parties.
G E
Ã".R.~-'er;ice under =his Schedule 's subject to,the provis 'ons cont z'n c in Co;.zany's FPC:-Lectric Tar f f ec =ith the Federal:-ner "" Beau'a to Co=ission.
anv wav the hothing contained herein sha be construed as a"fee=
r'"nt of he oartv u"nis"'g s "" ce, under he Yz e sched to un terally =ake aop'cation to the Federal Energy Pe (t\ 1 lopv Co-.".. ssion or a chance in "he ra" s, charges, classification, or se vice, or any
~
'on 205 of the Federal Po~er Ac and pursuant to =he Con".ission's Rules an= Regula ons pro"u'.ga ed thereun"er.
Tssuec bv Effective =or service ren"ared =ro
~o s ~ Zd~e . "n?ce Deca...oe '9 9II tn u Augus Lg 9
~
~
es 6 Se e Prac 'ces ICC1 ~ 0~ ga ~ ~ lg>O>> l>~ ~ 0 ' QC'1
Carolina Power & Light Company Revised Sheet No. 5 FPC Electric Tariff Superseding Revised Sheet No. 5 First Revised Volume No. 1 of Schedule RS-12B Electric Membership RESALE SERVICE Corporation SCHEDULE RS-12D AVAILABILITY Service hereunder is available throughout the Company's area of service from Company's existing facilities of adequate type and capacity, for use and resale by an electric membership corporation.
This Schedule is not available for breakdown or standby service.
Except as may be agreed to by Company in writing, this Schedule. is not available for supplementary service other than for "Excess Power and Energy" sold to a Government preference customer.
APPLICABILITY This Schedule is applicable to all electric service of a single type delivered at one point through one metering installation at, or compensated to, the point of delivery. This Schedule shall apply to each point of delivery separately; except that at the points of delivery served at a voltage of 115 KV or higher, the KW of demand and KWH of energy will be totalized for single ra"e application.
TYPE OF SERVICE This Schedule is applicable to alternating current, 60 cycles per second (Hertz), three phase electric service at the voltage set forth in Exhibit A for the point of delivery.
MONTHLY RATE
$ 340.00 per point of delivery
$ 6.18 per KW of Billing Demand 0.8220116< per KWH for all KWH 12C per KVAR for all Excess KVAR (See POWER FACTOR ADJUST.'LENT)
Ad)ustment: The bill computed under the above ~<monthly Rate will be increased or decreased by an amount calculated in accordance with Company's applicable rider(s), which is incorporated as a part of the monthly billing under this Schedule.
Issued by: Effective for service rendered Norris L. Edge, Vice President from December 29, 1977, through Rates & Service Practices August 17, 1980 Issued On: ofay 7, 1982
Carolina Power 8 Light Company Revised Sheet No. 7C FPC Electric Tariff Superseding Original Sheet No. 7C First Revised Volume No. 1 of Schedule RS-12C the demands used during a fifteen-minute interval and 62%%u of the maximum KM demand registered at the individual point of delivery.
PAYMENT Subject to the applicable provisions of the General Terms and Conditions, bills are due when rendered and are payable within 15 days from the date of the bill.
CONTRACT PERIOD The initial contract period for contracts entered into after the effective date of this Schedule shall be seven years unless Company and Customer agree to a longer or shorter period. Subject to the applicable provisions of the General Terms and Conditions, either Company or Customer may terminate any such contract at the end of such initial period, or at any time thereafter, upon three, years'ritten notice. Customer may, upon three years'ritten notice, terminate within the initial seven-year period, by reimbursing Company for the unamortized portion of its investment in transmission, distribution and transformation facilities installed by Company for such point of delivery to the extent devoted to Customer' service, in accordance with the General Terms and Conditions.
When Customer's load growth requires and Company agrees to install additional transmission, distribution, or transformation facilities for services to Customer at a point of delivery, the contract period for the point of delivery will automatically be extended for seven years unless
. Company and Customer agree, in writing, to a different extended contract period.
The provisions set forth herein shall not apply with respect to any facilities installed as additional facilities, and the charges for any such additional facilities shall be in accordance with the contract between the parties.
GENERAL Service under this Schedule is subject to the provisions contained in Company's FPC Electric Tariff filed with the Federal Energy Regulatory Commission. Nothing contained herein shall be construed as affecting in any way the right of the party furnishing service, under the rate schedule, to unilaterally make application to .the Federal Energy Regulatory Commission for a change in the rates, charges, classification, or service, or any rule, regulation, or contract related thereto, under Section 205 of the Federal Power Act and pursuant to the Commission's Rules and Regulations promulgated thereunder.
Issued by: Effective for service rendered Norris L. Edge, Vice President from December 29, 1977, through Rates 6 Service Practices August 17, 1980 Issued On: May 7, 1982 Next sheet is Revised Sheet No. 8
Carolina Power & Light Company Revised Sheet No. 7A FPC, Electric Tariff Superseding Original Sheet No. 7A First Revised Volume No. 1 of Schedule RS-12C Municipal Private RESALE SERVICE Distribution Utility SCHEDULE RS-12E AVAILABILITY Service hereunder is available throughout the Company's area of service from Company's existing facilities of adequate type and capacity, for use and resale by a municipal utility or a private distribution utility.
This Schedule is not available for breakdown or standby service.
Except as may be agreed to by Company. in writing, this Schedule is not available for supplementary service other than for "Excess Power and Energy" sold to a Government preference customer.
APPLICABILITY This Schedule is applicable to all electric service of a single type delivered at one point through one metering installation at, or compensated to, the point of delivery. This Schedule shall apply to each point of delivery separately; except that at the points of delivery served at a voltage of 115 KV or higher, the KM of demand and KMi of energy will be totalized for single rate application.
TYPE OF SERVICE This Schedule is applicable to alternating current, 60 cycles per second (Hertz), three phase electric service at the voltage set forth in Exhibit A for the point of delivery.
MONTHLY RATE
$ 340.00 plus 5.731 per Kll of Billing Demand 0.997297C per KWH for all KWH 12'er KVAR for all Excess KVAR (See POtKR FACTOR ADJUSTMENT)
Adjustment: The bill computed under the above Monthly Rate will be increased or decreased by an amount calculated in accordance with the Company's applicable rider(s), which is incorporated as "a part of the monthly billing under this Schedule.
Issued by: Effective for service rendered Norris L. Edge, Vice President from December 29, 1977, through Rates 6 Service Practices August 17, 1980 Issued On: May 7, 1982
Carolina Power & Light Company Revised Sheet No. 7B FPC Electric Tariff Superseding Original Sheet No. 7B First Revised Volume No. 1 of Schedule RS-12C DE>L4%) AND ENERGY DETER~fINATION The KWH of energy shall be metered or computed at, or compensated to, the point of delivery. The KM of metered or computed demand shall be the kilowatts metered or computed during the fifteen-minute period, measured in fifteen-minute clock hour intervals except as provided in the General Tezms and Conditions, of greatest energy use during the current month, appropriately adjusted to preclude the duplication of any demand caused by switching of load between non-totalized points of delivery served by Company.
(a) For non-totalized points of delivery, the Billing Demand shall be the metered or computed demand, less the Government preference customer demand al1otment, if any, for that point of delivery.
(b) For totalized points of delivery, the Bil'ling Demand shall be the totalized metered or computed demand, less the sum of the Government preference customer demand allotments, if any.
Prior to the billing date, Customer will provide written notification to Company of each load transfer, including the names of the points of delivery involved, the amount of load being transferred and the effect that such load had on the actual maximum demand, if any, established during the current billing month. A load transfer for forty-eight hours or less will not be considered for current billing as having been served at the point of delivery to which it was temporarily connected; however, load which is temporarily connected to another point of delivery will be considered for current billing as having been served at the point of delivery from which it was temporarily transferred.
The Government preference customer's allotted Contract Demand and kilowatt-hours shall be determined independently for each point of delivery prior to totalization.
Honthly metered or computed demand and energy quantities shall be reduced by the monthly kilowatts of allotted Contract Demand and kilowatt-hours of a Government preference customer as determined in the Government-Company Contract.
A preference customer's monthly kilowatts of total allotted Contract Demand will be prorated among Customer's points of delivery in proportion to monthly delivery point maximum metered or computed demands of Customer.
POWER FACTOR ADJUS'PfENT When the power factor, determined in accordance with the General Terms and Conditions, in the current billing month at an individual point of delivery is less than 851, the month1y bill will be increased by a sum equal to $ 0.12 multiplied by the. difference between the maximum reactive kilovolt amperes (KVAR) registered by a demand meter suitable for measuring Issued by: Effective for service rendered Norris L. Edge, Vice President from December 29, 1977, through Rates & Service Practices August 17, 1980 Issued On: Nay 7, 1982
E
~ II ~
~ ~
~ ~ ~
~ + ~ ~ ~
~ 'I ~ ~ ~ ~ ~ ~ ~
I~ II ~ ~ ~ 0 ~
~ ~
~ ~
~ ~ ~ ~ ~
~ I ~ II
~ ~
~ ~ ~ ~
~ ~ ~ ~
~ ~ ~ ~ ~ ~ ~ ~
~ 'l l ~ ~ ~ ~
~ ~
~ ~ ~ I ~ ~
~ ~
II ~ - ~ ~ ~ ~
~ ~ I.. ~
~
~ ~
' I
~ ~ ~ ~ ~ ~
~ ~ ~ ~
~ ~ ~ 0 ~ ~ ~ ~
~ ~
~ ~
Carolina Power & Light Company 2nd Revised Sheet No. 6 FPC Electric Tariff Superseding 1st Revised Sheet No. 6 First Revised Uolume No. 1 of Schedule RS-12A DEQDD AND ENERGY DETER'4INATION The IGTH of energy shall be metered or computed at, or compensated to, the point of delivery. The KM of metered or computed demand shall be the kilowatts metered or computed during the fifteen-minute period, measured in fifteen-minute clock hour intervals except as provided in the General Terms and Conditions, of greatest energy use during the current month, appropri.ately adjusted to preclude the duplication of any demand caused by switching of load between non-totalized points of delivery served by Company.
(a) For non-totali.zed points of delivery, the Billing Demand shall be the metered or computed demand, less the Government preference customer demand allotment, if any, for that point of delivery.
(b) For totalized points of delivery, the Billing Demand shall be the totalized metered or computed demand, less the sum of the Government preference customer demand allotments, if any.
Prior to the billing date, customer will provide written notification to Company of each load transfer, including the names of the points of delivery involved, the amount of load being transferred and the effect that such load had on the actual maximum demand, if any, established during the current billing month. A load transfer for forty-eight hours or less will not be con-sidered for current billing as having been served at the point of delivery to which it'as temporarily connected; however, load which is temporarily connected to another point of delivery will be considered for current billing as having been served at the point of delivery from which it was temporarily transferred.
The Government preference customer's allotted Contract Demand and kilowatt-hours shall be determined independe'ntly for each point of delivery prior to totalization.
Monthly metered or computed demand and energy quantities shall be reduced by the monthly kilowatts of allotted Contract Demand and kilowatt-hours of a Government preference customer as determined in the Government-Company Contract.
A preference customer's monthly kilowatts of total allotted Contract Demand will be prorated among Customer's points of delivery in proportion to monthly delivery point maximum metered or computed demands of Customer.
POVER FACTOR ADJUSTMENT When the po~er factor, determined in accordance with the General Terms and Conditions, in the current billing month at an individual point of delivery is less than 85%, the monthly bill will be increased by a sum equal to $ 0.12 mul-tiplied by the difference between the maximum reactive kilovolt amperes (KVAR)
Issued by: Effective: June 17, 1980 Norris L. Edge, Manager Rates & Service Practices Issued on April 18, 1980
Carolina Power 6 Light Company 2nd Revised Sheet No. 7 FPC Electric Tariff Superseding 1st Revised Sheet No. 7 First Revised Uolume No. 1 of Schedule RS-12A registered by a demand meter suitable for measuring the demands used during a fifteen-minute interval and 62% of the maximum KN demand registered at the individual point of'delivery.
PAEKNT Subject to the applicable provisions of the General Terms and Conditions, bills are due when rendered and are payable within 15 days from the date of the bill.
CONTRACT PERIOD The initial contract period for contracts entered into after the effective date of this Schedule shall be seven years unless Company and Customer agree to a longer or shorter period. Subject to the applicable provisions of the General Terms and Conditions, either Company or Customer may terminate any such contract at the end of such initial period, or at any time thereafter, upon three years'ritten notice. Customer may, upon three years'ritten notice, terminate within the initial seven-year period, by reimbursing Company for the unamortized portion of its investment in transmission, distribution and trans-formation facilities installed by Company for such point of delivery to the extent devoted to Customer's service, in accordance with the General Terms and Conditions.
i Mhen Customer's load growth requires and Company agrees to install addi-tional transmission, distribution, or transformation facilities for services to Customer at a point of delivery, the contract period for the point of delivery will automatically be extended for seven years unless Company and Customer agree, in writing, to a different extended contract period.
The provisions set forth herein shall not apply. with respect to any facilities installed as additional facilities, and the charges for any such additional facilities shall be in accordance with the contract between the parties.
GENERAL Service under this Schedule is subject to the provisions contained in Company's FPC Electric Tariff filed with the Federal Energy Regulatory'om-mission. Nothing contained herein shall be construed as affecting in any way the right of the party furnishing service, under the rate'schedule, to uni-laterally make application to the Federal Energy Regulatory Commission for a change in the rates, charges, classification, or service, or any rule, regulation, or contract related thereto, under Section 205 of the Federal power Act and pursuant to the Commission's Rules and Regulations promulgated thereunder.
Issued by: Effective: June 17, 1980 Norris L. Edge, .'hnager Rates & Service Practices Issued on April 18, 1980
Carolina Power & Light Company Revised Sheet No. 5 FPC Electric Tariff Superseding 2nd Revised Sheet No. 5 First Revised Volume No. 1 of Schedule RS-13 Electric
'Aembership RESALE SERVICE Corporation SCHEDULE RS-13A AVAILABILITY Service hereunder is available throughout the Company's area of service from Company's existing facilities of adequate type and capacity, for use and resale by an electric membership corporation.
This Schedule is not available for breakdown or standby service. Except as may be agreed to by Company in writing, this Schedule is not available for supplementary service other than for "Excess Power and Energy" sold to a Government preference customer.
APPLICABILITY This Schedule is applicable to all electric service of a single type delivered at one point through one metering installation at, or compensated to, the point of delivery. This Schedule shall apply to each point of delivery separately; except that at the points of delivery served at a voltage of 115 kV or higher, the kW of demani and kWh of energy wil'1 be total. ized for single rate application.
TYPE OF SERVICE This Schedule is applicable to alternating current, 60 cycles per second (Hertz), three phase electric service at the voltage set forth in Exhibit A for the point of delivery.
NOVTHLY RATE
$ 398.514 per point of delivery
$ 6.678 per kW of Billing Demand 1.4752C per kWh for all k'Ah 12C per kVAr for a11 Excess kVAr (See POWER FACTOR ADJUST.'lENT)
Adjustment: The bill computed under the above llonthly Rate will be increased-.or decreased by an amount calculated in accordance with the Company's applicabLe rider(s), <<hich is incorporated as a part of the monthly billing under this Schedule.
Issued by: Effective for Service Rendered Norris L. Edge, Vice President From August 18, 1980, Through Rates & Service Practices January 1.1, 1982 Issued on
Carolina Power G Light Company Revised Sheet No. 6 FPC Electric Tariff Superseding 2nd Revised Sheet No. 6 First Revised Volume No. 1 of Schedule RS-13 DEi~1AND AND ENERGY DETERi~IINATION The kWh of 'energy shall be metered or computed at, or compensated to, the point of delivery. The kW of metered or computed demand shall be the kilowatts metered or computed during the fifteen-minute period, measured in fifteen-minute clock hour intervals except as provided in the General Terms and Conditions, of greatest energy use during the current month, appropriately adjusted to preclude the duplication of any demand caused by switching of load between non-totalized points of delivery served by Company.
(a) For non-totalized points of delivery, the Billing Demand shall be the metered or computed demand, less the Government preference customer demand allotment, if any, for that point of delivery.
(b) For totalized points of delivery, the Billing Demand shall be the totalized,metered or computed demand, less the sum of the Government preference customer demand allotments, if any.
Prior to the billing date, Customer will provide written notification to Company of each load transfer, including the names of the points of delivery involved, the amount of load being transferred and the effect that such load had on the actual maximum demand, if any, established during the current billing month. A load tran fer for forty-eight hours or less will not be considered for current billing as having been served at the point of delivery to which it was temporarily connected; however, load which is temporarily connected to another point of delivery will be considered for current billing as having been served at the point of delivery from which it was temporarily transferred.
The Government preference customer's allotted Con'tract Demand and kilowatt hours shall be determined independently for each point of delivery prior to totalization.
~ifonthly metered or computed demand and energy quantities shall be reduced by the monthly kilowatts of allotted Contract Demand and kilowatt-hours of Government preference customer as determined in the Government-Company Contract.
A preference customer's monthly kilowatts of total allotted Contract Demand vill be prorated among Customer's points of delivery in proportion to monthly delivery point maximum metered or computed demands of Customer.
POWER FACTOR ADJUST':LENT When the power factor, determined in accordance with t'e General Terms and Conditions, in the current bill.ing month at an individual point of delivery is less than 85%, the monthly bill will be increased by a sum equal to $ 0.12 multiplied by the difference between the maximum reactive kilovolt amper s (kVAr) registered by a demand meter suitable tor measuring the demands P
Issued by: Effective for Service Rendered Norris L. Edge, Vice Presldi nt, From Auoust l.8, 1980, Through Routes Issued on 6 Service Practices January ll, 1982
Carolina Power & Light Company Revised Sheet No. 7 FPC Electric Tariff Superseding 2nd Revised Sheet No. 7 First Revised Volume No. 1 of Schedule RS-13 used during a fifteen-minute interval and 62% of the maximum kW demand registered at the individual point of delivery.
PAYIKNT Subject to the applicable provisions of the General Terms and Conditions, bills are due when rendered and are payable within 15 days from the date of the bill.
CONTRACT PERIOD The initial contract period for contracts entered into after the effective date of this Schedule shall be seven years unless Company and Customer agree to a longer or shorter period. Subject to the applicable provisions of the General Terms and Conditions, either Company or Customer may terminate any such contract at the end of such initial period, or at any time thereafter, upon three, years'ritten notice. Customer may, upon three years'ritten notice, terminate within the initial seven-year period, by reimbursing Company for the unamortized portion of its investment in transmission, distribution and trans-formation facilities installed by Company for such point of delivery to the extent devoted to Customer's service, in accordance with the General Terms and Conditions.
When Customer's load growth requires and Company agrees to install addi-tional transmission, distribution, or transformation facilities for services to Customer at a point of delivery, the contract period for the point of delivery will automatically be extended for seven years unless Company and Customer agree, in writing, to a different extended contract period.
The provisions set forth herein shall not apply with resoect to any facilities installed as additional facilities, and the charges for any such additional facilities shall be in accordance with the contract between the parties.
GENERAL Service under this Schedule is subject to the provisions contained Company's FPC Electric Tariff filed with the Federal Energy Regulatory Commission. Nothing contained herein shall be construed as affecting in any way the right of the party furnishing service,.under the rate schedule, to unilaterally make application to the Federal Energy Regulatory Commission for a change in the rates, charges, classification, or service, or any rule, regulation, or contract related thereto, under Section 205 of the Federal Power Act and pursuant'to the Commission's Rules and Regulations promulgated thereunder.
Issued by: Effective for Service Rendered Norris L. Edge, Vice President From August 13, 1980, Through Rates & Service Practices January 11, 1932 Issued on
Carolina Power & Light Company FPC Electric Tariff First Revised Volume No. 1 Original Sheet No. 7A Municipal &
Private RESALE SERVICE Dis tribution Utility SCHEDULE RS-14 AVAILABILITY II Service hereunder is available throughout the Company's area of service from Company's existing facilities of adequate type and capacity, for use and resale by a municipal utility or a private distribution utility.
This Schedule is not available for breakdown or standby service. Except as may be agreed to by Company in writing, this Schedule is not available for supplementary service other than for "Excess Power and Energy" sold to a Government preference customer.
APPLICABILITY This Schedule is applicable to all electric service of a single type de-livered at one point through one metering installation at, or compensated to, the point of delivery. This Schedule shall apply to each point of delivery separately; except that at the points of delivery served at a voltage of 115KV or higher, the KW of demand and KMH of energy will be totalized for single rate application.
TYPE OF SERVICE This Schedule is applicable to alternating current, 60 cycles per second (Hertz), three phase electric service at the voltage set forth in Exhibit A for the point of delivery.
MONTHLY RATE
$ 977.00 per point of delivery
$ 7.527 per KM of Billing Demand 1.56'er KWH for all KMH 12'er KVAR for all Excess KVAR (See POWER FACTOR ADJUSPifENT)
Adjustment: The bill computed under the above Ifonthly Rate will be increased or decreased by an amount calculated in accordance with the Company's applicable rider(s), which is incorporated as a part of the monthly billing under this Schedule.
Issued by: Effective: June 17, 1980 Norris L. Edge, Manager Rates & Service Practices Issued on April 18, 1980
Carolina Power & Light Company FPC Electric Tariff First Revised Volume, No. 1 Original Sheet No. 7B DERED AiD ENERGY DETER1INATION The K!% of energy shall be metered or computed at, or compensated to, the point of delivery. The KW of metered or computed demand shall be the kilowatts metered or computed during the fifteen-minute period, measured in fifteen-minute clock hour intervals except as provided in the General Terms and Conditions, of greatest energy use during the current month, appropriately adjusted to preclude the duplication of any demand caused by switching of load between non-totalized points of delivery served by Company.
(a) For non-totalized points of delivery, the Billing Demand shall be the metered or computed demand, less the Government preference customer demand allotment, if any, for that point of delivery.
(b) For totalized points of delivery, the Billing Demand shall be the totalized metered or computed demand, less the sum of the Government preference customer demand allotments, if any.
Prior to the billing date, customer will provide written notification to Company of each load transfer, including the names of the points of delivery involved, the amount of load being transferred and the effect that such load had on the actual maximum demand, if any, established during thecurrent billing month. A load transfer for forty-eight hours or less will not be con-sidered for current billing as having been served at the point of delivery to which it was temporarily connected; however, load which is temporarily connected to another point of delivery will be considered for current billing as having been served at the point of delivery from which it was temporarily transferred.
The Government preference customer's allotted Contract Demand and kilowatt-hours shall be determined independently for each point of delivery prior to totalization.
Monthly metered or computed demand and energy quantities shall be reduced by the monthly kilowatts of allotted Contract Demand and kilowatt-hours of a Government preference customer as determined in the Government-Company Contract.
A preference customer's monthly kilowatts of total allotted Contract Demand will be prorated among Customer's points of delivery in proportion to monthly delivery point maximum metered or computed demands of Customer.
POWER FACTOR ADJUSTMENT When the power factor, determined in accordance with the General Terms and Conditions, in the current billing month at an individual point of delivery is less than 85%, the monthly bill will be increased by a sum equal to $ 0.12 mul-,
tiplied by the difference between the maximum reactive kilovolt amperes (KVAR)
Issued by: Effective: June 17, 1980 Norris L. Edge, Manager Rates & Service Practices Issued on April 18,'980
Carolina Power 6 Light Company FPC Electric Tariff First Revised Volume No. 1 Original Sheet No. 7C registered by a demand meter suitable for measuring the demands used during a fi.fteen-minute interval and 62/ of the maximum IQ< demand registered at the individual point of delivery.
PAYNENT Subject to the applicable provisions of the General Terms and Conditions, bills are due when rendered and are payable within 15 days from the date of the bill.
CONTRACT PERIOD The initial 'contract period for contracts entered into after the effective date of this Schedule shall be .seven years unless Company and Customer agree to a longer or shorter period. Subject to the applicable provisions of the General Terms and Conditions, either Company or Customer may terminate any such contract at the end of such initial period, or at any time thereafter, upon three years'ritten notice. Customer may, upon three years'ritten notice, terminate within the initial seven-year period, by reimbursing Company for the unamortized portion of its investment in transmission, distribution and trans-formation facilities installed by Company for such point of delivery to the extent devoted to Customer's service, in accordance with the General Terms and Conditions.
When Customer's load growth requires and Company agrees to install addi-tional transmission, distribution, or transformation facilities for services to Customer at a point of delivery, the contract period for the point of delivery will automatically be extended for seven years unless Company and Customer agree, in writing, to a different extended contract period.
The provisions set forth herein shall not apply wi.th respect to any facilities installed as additional facili.ties, and the charges for any such additional facilities shall be in accordance with the contract between the parties.
Service under this Schedule is subject to the provisions contained in
,Company's FPC Electric Tariff filed with the Federal Energy Regulatory Com-mission. Nothing contained herein shall be construed as affecting in any way the right of the party furnishing service, under'the rate schedule, to uni-laterally make application to the Federal Energy Regulatory Commission for a change in the rates, charges, classification, or service, or any rule, regulation, or contract related thereto, under Section 205 of the Federal Power Act and pursuant to the Commission's Rules and Regulations promulgated thereunder.
Issued by: Effective: June 17, 1980 Norris L.'dge, ~tanager Rates & Service Practices Issued on April 18, 1980 Next Sheet is Sheet No. 8
Carolina Power & Light Company Revised Sheet No. 7A FPC Electric Tariff Superseding Original Sheet No. 7A First Revised Volume No. 1 of Schedule RS-14 Hunicipal &
Private RESALE SERVICE Distribution Utility SCHEDULE RS-14A AVAILABILITY Service hereunder is available throughout the Company's area of service from Company's existing facilities of adequate type and capacity, for use and resale by a municipal utility or a private distribution utility.
This Schedule is not available for breakdown or standby service. Except as may be agreed to by Company in writing, this Schedule is not available for supplementary service other than for "Excess Power and Energy" sold. to a Government preference customer.
APPLICABILITY This Schedule is applicable to all electric service of a single type delivered at one point through one metering installation at, or compensated to, the point of delivery. This Schedule shall apply to each point of delivery separately; except that at the points of delivery served at a voltage of 115 kV or higher,'the kW of demand an'; kWh of energy will be totalized for single rate application.
TYPE OF SERVICE This Schedule is applicable to -alternatin current, 60 cycles per second (Hertz), three phase electric service at the voltage set forth in Exhibit A for the point of delivery.
MONTHLY RATE
$ 4S7.705 per point of delivery 7.200 per kW of Billing Demand 1.5390c per kWh for all kMh 12c per kVAr for all Excess kVAr (See POWER FACTOR ADJUSTMENT)
Adjustment: The bill computed under the above tfonthly Rate will be increased or decreased by an amount calculated in accordance with the Company's applicable rider(s), which is incorporated as a part of the monthly billing under this Schedule.
Issued by: Effective for Service Rendered Norris L. Edge, Vice President From August 1S, 1980, Through Rates & Service Practices January 11, 19S2 issued on
Carolina Pover 6 Light Company Revised Sheet No. 7B FPC Electric Tariff Superseding Original Sheet No. 7B First Revised Volune No. I. of Schedule RS-14 DEMAND AND ENERGY DETERMINATION The kWh of energy shall be metered or computed at, or compensated to, the point of delivery. The kW of metered or computed demand shall be the kilovatts metered or computed during the fifteen-minute period, measured in fifteen-minute clock hour intervals except as provided in the General Terms and Conditions, .
of greatest energy use during the current month, appropriately adjusted to preclude the duplication of any demand caused by svi,tching of load betveen non-totalized points of delivery served by Company.
(a) For non-totalized points of delivery, the Billing Demand shall be the metered or computed demand, less the Government preference customer demand allotment, if any, for that point of delivery.
(b) For totalized points of delivery, the Billing Demand shall be the totalized metered or computed demand, less the sum of the Government preference customer demand allotments, if any.
Prior to the billing date, Customer will provide vritten notification to Company of each load transfer, including the names of the points of delivery involved, the amount of load being transferred and the effect that such load had on the actual maximun demand, if any, established during the current billing month. A load transfer for forty-eight hours or less vill not be considered for current billing as having been served at the point of delivery to which it was temporarily connected", however, load which is temporarily connected to another point of delivery will be considered for current billing as having been served at the point of delivery from which it was temporarily transferred.
The Government preference customer's allotted Contract Demand and kilovatt-hours shall be determined independently for each point of delivery prior to totalization.
Monthly metered or computed demand and energy quantities shall be reduced by the monthly kilowatts of allotted Contract Demand and kilovatt-hours of a
. Government preference custoner as determined in the Government-Conpany Contract.
A preference customer's monthly kilowatts of total allotted Contract Demand will be prorated among Customer's points of delivery in proportion to monthl.y delivery point naxinum metered or computed demands of Customer.
POWER FACTOR ADJUSTMENT When the Power factor, determined in accordance with the General Terms and Conditions, in the current hi.llin nonth at an individual point of del.ivery is less than 85/, the monthly bill will be increased by a sum equal to $ 0.1.2 'ultiPlied by the difference between the maxinum reactive kilovolt amperes (kVAr) registered hy a demand meter suitabl for measuring the demands Issued by: Ef fective for Service Rendered Norris L. Edge, Vice Pres ident From August 13, l980, Through Rates 5 Service Practices January ll, 1.982 Issued on
i'll Carolina Power FPC Electric Tarif First Revised Volume PAYNE during a used 5 Light Company No. 1 fifteen-minute interval and 62% of the registered at the individual point of delivery.
~
Revised Sheet No. 7C Superseding Original Sheet tfo.
of Schedule RS-14 maximum Mf demand Subject to the applicable provisions of the General Terms and Conditions, 7C bills are due when rendered and are payable within 15 days from the date of the bill.
CONTRACT PERIOD The initial contract period for contracts entered into after the effective date of this Schedule shall be seven years unless Company and Customer agree to a longer or shorter period. Subject to the applicable provisions of the General Terms and Conditions, either Company or Customer may terminate any such contract at the end of such initiaL period, or at any time thereafter, upon.
three years 'ritten notice. Customer may, upon three years 'ritten notice, terminate within the initial seven-year period, by reimbursing Company for the unamortized portion of its investment in transmission, distribution and trans-formation facilities installed by Company for such point of delivery to the extent devoted to Customer's service, in accordance with the General Terms and Conditions.
When Customer's load growth 'requires and Company agrees to install addi-tional transmission, distribution, or transformation facilities for'ervices to Customer at a point of delivery, the contract period for the 'point of delivery will automatically be extended for seven years unless Company and Customer agree, in writing, to a different extended contract period.
The provisions set forth herein shall not apply with respect to any facilities installed as additional facilities, and the charges for any such additionaL facilities shalL be in accordance with the contract between the parties.
GEiVER.Q.
Service under this Schedule is subject to the provisions contained in Co'mpany's FPC Electric Tariff filed with the Federal Energy Regulatory Commission. Nothing contained herein shalL be construed as affecting in any way the right of the party furnishing service, under the rate schedule, to unilaterally make application to the Federal Energy Regulatory Commission for a change in the rates, charges, classification, or service, or any rule, regulation, or contract related thereto, under Section 205 of the Federal Power Act and pursuant to the Commission's Rules and Regulations promulgated thereunder.
Issued by: Effective for Service Rendered Norris L. Edge, Vice President From August 13, 19SO, Through Rates 5 Service Practices'ssued
.January 11, 19S2 on
Carolina Power & Light Company Sheet No. 7D FPC Electric Tariff Superseding Equivalent Provisions First Revised Volume No. 1 of Schedules RS-13 & RS-14 PARTIAL REQUIREHENTS RESALE SERVICE SCHEDULE RS-14B AVAILABILITY Service hereunder is available throughout Company's area of service from Company's existing facilities of adequate type and capacity, for use and resale by a municipal utility, a private distribution utility or an electric membership corporation when the Customer has generation installed on the load side of Company's metering facilities of (1) two 1'Ã summer-rated capacity; or (2) summer-rated capacity sufficient, exclusive of reserves, to generate not less than 15X of the Customer's annual maximum system demand, whichever is greater.
This Schedule shall not apply to service for those Customers to which Resale Service Schedule RS-13A or RS-14A, or successor(s), is applicable. A Customer receiving service under this Schedule shall remain on this Schedule or its successor(s) in accordance with the Contract Period, but in no event less than three years after notice that the Customer intends to discontinue operation of its generation capacity or falls below the minimum capacity requirements set forth above, except upon mutual agreement of Company and Customer.
Except as may be agreed to by Company in writing, this Schedule is not av ilable for breakdown or standby service.
APPLICABILITY This Schedule is applicable to all electric service of a single type delivered at one point through one metering installation at, or compensated to, the point of delivery. This Schedule shall apply to each point of delivery separately; except that, at the points of delivery served at a voltage of 115 kV or higher, the kW of demand and kWh of energy will be totalized for single rate application.
TYPE OF SERVICE This Schedule .is applicable to alternating current, 60 cycles per second (Hertz), three-phase electric service at the voltage set forth in Exhibit A for the point of delivery.
PARTIAL RE UIREHENTS MONTHLY RATE
$ 1,198.760 per point of delivery
$ 7.050 per kW of Billing Demand Issued by: Effective for Service Rendered Norris L. Edge, Vice President From August 18, 1980, Through Rates & Service Practices January Ll, 1982 Issued on
Carolina Power & Light Company Sheet No. 7E FPC Electric Tariff Superseding Equivalent Provisions First Revised Volume No. 1 of Schedules RS-13 & RS-14 1.540< per kWh for all kWh 12'er kVAr for all Excess kVAr (See POWER FACTOR ADJUSTMENT)
Adjustment: The bill computed under the above Monthly Rate will be increased or decreased by an amount calculated in accordance with the Company's applicable rider(s), which is incorporated as a part of the monthly billing under this Schedule.
DEfAND AND ENERGY DETERMINATION The kWh of energy shall be metered or computed at, or compensated to, the point of delivery. The kW of metered or computed demand shall be the kilowatts metered or computed during the fifteen-minute period, measured in fifteen-minute clock hour intervals except as provided in the General Terms and Conditions, of greatest energy use during the current month, appropriately adjusted to preclude the duplication of any demand caused by switching of load between non-totalized points of delivery served by Company.
(a) For non-totalized points of delivery, the Billing Demand shall be the metered or computed demand, less the Government preference customer demand allotment, if any, for that point of delivery.
(b) For totalized points of delivery, the Billing Demand shall be the totalized metered or computed demand, less the sum of the Governmen=
preference customer demand allotments, if any.
Prior to the billing date, Customer will provide written notification to Company of each load transfer, including the names of the points of delivery involved, the amount of load being transferred and the effect that such load had on the actual maximum demand, if any, established during the current billing month. A load transfer for forty-eight hours or less will not, be considered for current billing as having been served at the point of delivery to which it was temporarily connected; however, load which is temporarily connected to another point of delivery vill be considered for current billing as having been served at the point of delivery from which it was temporarily transferred.
The Government preference customer's allotted Contract Demand and kilowatt-hours shall be determined, independently for each point of delivery prior to totalization.
Monthly metered or computed demand and energy quantities shall be reduced by the monthly kilowatts of allotted Contract Demand and kilowatt-hours of a Government preference customer as determined in the Government-Company Contract.
Issued by: Effective for Service Rendered Norris L. Edge, Vice President From August 18, 1980, Through Rates & Service Practices January 11, 1982 Issued on
Carolina Power & Light Company Sheet No. 7F FPC Electric Tariff Superseding Equivalent Provisions First Revised Volume No. 1 of Schedules RS-13 & RS-14 A preference customer's monthly kilowatts of total allotted Contract Demand will be prorated among Customer's points of delivery in proportion to monthly delivery point maximum metered or computed demands of Customer.
POWER FACTOR ADJUSTMENT When the power factor, determined in accordance with the General Terms and Conditions, in the current billing month at an individual point of delivery is less than 85%, the monthly bill will be increased by a sum equal to $ 0.12 multiplied by the difference between the maximum reactive .kilovolt amperes (kVAr) registered by a demand meter suitable for measuring the demands used during a fifteen-minute interval and 62% of the maximum kM demand registered at the individual point of delivery.
PAYMENT Subject to the applicable provisions of the GeneraL Terms and Conditions, bills are due when rendered and are payable within fifteen days from the date of the bill.
CONTRACT PERIOD The initial contract period shall be seven years unless'ompany and Customer agree, or have previously agreed, to a Ldnger or shorter period. Subject to the applicable provisions of the General Terms and Conditions, unless otherwise agreed to in a contract between Company and Customer, either Company or Customer may terminat- any such contract at the end of such initial period, or at any time thereafter, upon three years'ritten notice. Unless otherwise'greed to in a contract between Company and Customer, Customer may, upon three notice, terminate within the initial seven-year period, by reimbursing years'ritten Company for the unamortized portion of its investment in transmission, distri-bution and transformation facilities installed by Company for such point to the extent devoted to Customer's service, in accordance with the of'elivery General Terms and Conditions.
When Customer's load growth requires and Company agrees to install addi-tional transmission, distribution, or transformation facilities for service to Customer at a point of delivery, the contract period for the point of delivery will automatically be extended for seven years unless Company and Customer agree, in writing, to a different extended contract period.
The provisions set forth herein shall not apply with respect to any facili-ties instaLLed as additional facilities, and the charges for any such additional facilities shall. be in accordance with the contract between the parties.
Issued hy: Effective for Service Rendered Norris L. Edge, Vice President From August 18, 1980, Through Rates & Service Practices January 11, 1982 Issued on
CaroLina Power 6 Light Company Sheet No. 7G FPC Electric Tariff Superseding Equivalent Provisions First Revised Volume No. 1 of Schedules RS-13 6 RS-14 GENERAL Service under this Schedule is subject to the provisions contained in Company's FPC Electric Tariff filed with the Federal Energy Regulatory Commis-sion. Nothing contained herein shall be construed as affecting in any way the right of the party furnishing service, under the rate schedule, to unilaterally make application to the Federal Energy Regulatory Commission for a change in the rates, charges, classification, or service, or any rule, regulation, or contract related thereto, under Section 205 of the Federal Power Act and pursuant to the Commission's Rules and Regulations promulgated thereunder.
Issued by: Ef fective for Service Rendered Norris L. Edge, Vice President From August 18, 1980, Through Rates 6 Service Practices January 11, 1982 Issued on
ATTACHMENT IV CP&L SYSTEM MAP
M C~
<<~l~
j
~
'"'I
't '
Q~ /
M I X-/'aMM
/
C I $~<<<<C
,aa /
C, C
% r
~ ~, ~ ~
! f' M I l
~
l/
"/
I II
~ MM
-i ~
~ ar r ~ M ~ c
~ ~ CM C ~O~f
~
2 ~ COIIII OM
~ I g(c r' 1
a ~I.IJ OO 4 ac
~ a r,rr 'I f Ia IC
~ ~ II ~
r
~ IC C
"s" aa IIOMOMMMaM\
~ a ~ IMMMOMIMI rl Iaaral MMMOMICI
~
OMMMMII MI IOIM 4 MclllalOMI
~CMMIIC IMaaa M MMIOICMMIOIM H IVM
~ 4 aa olcl IHM Ol 1M CMM NOM M OIMMMI MOIMM CMMOO MIM IMO MCM OMMCMM M ~C MMMOICNCMMM ~aaJ Oar CIMIM MIMOMCMM MMcrr coKcMM
'rcl CO\IOOMM