ML17053D517
| ML17053D517 | |
| Person / Time | |
|---|---|
| Site: | Nine Mile Point  |
| Issue date: | 02/14/1983 |
| From: | NIAGARA MOHAWK POWER CORP. |
| To: | |
| Shared Package | |
| ML17053D518 | List: |
| References | |
| NUDOCS 8302180348 | |
| Download: ML17053D517 (72) | |
Text
Docket No,. 50-410 INFORMATION FOR ANTI-TRUST REVIEW OP OPERATING LICENSE APPLICATION As Requested By Regulatory Guide 9.3 NINE MILE POINT NUCLEAR STATION, UNIT 2, Owners: Niagara Mohawk Power Corporation Central Hudson Gas and Electric Corporation Rochester Gas and Electric. Corporation New York State Electric and Gas Corporation Long Island Lighting Company
'8302180348 830214
PDR,ADQCK 05000410
"" N
NINE MILE POINT UNIT NO. 2 Information Reguired by the NRC Regulatory Staff in Connection With Its Anti-Trust Review of Operating License Application in Accordance With Regulatory Guide 9.3 Supplementing Information Submitted to the Attorney General For Anti-Trust Review in Connection With The License Application For This Facility Pursuant To 10 CFR 50, Appendix L NIAGARA MOHAWK POWER. CORPORATION
>'C4' g
(C'.J&
boa .
~ Q
NIAGARA MOHAWK POWER CORPORATION NINE MILE POINT UNIT 42 - ANTI-TRUST REVIEW Regulatory Guide 9.3 l(a) Chan es. in antici ated ca aci reserves.
Since the 1978 fQing of the 9 Mile Point Anti-Trust Review, the forecasted- capacity reserves have been altered somewhat. This is a result of changes in the forecasted electric peak demand as indicated in Attachment 1. The decrease in forecasted load and energy has been great enough'o alter the timing, of Niagara Mohawk,'s capacity additions." Attachment 2 highlights some of the major changes in the capacity plans from the 1978 projected capacity addi-tions to today'- projected capacity additions. Because of these-reductions in planned capacity,. the level of'reserves do not differ substantially today from'the original review; Attachment 3 compares 1978 and 1983 projections of excess-capacity.
~
1(b) Chan es in structure activities olicies or ractices of ower ools.
No changes have occurred in participation of new power pools or coordi'nating groups .
Niagara Mohawk plans generation and transmission in conjunction with other members of the New York Power Pool. Along withthe other members of the New York Power Pool, all participants are members of the Northeast Power Coordinating Council (NPCC) . The NPCC was established for the purpose of promoting maximum reliability and efficiency of electric service in the interconnected areas of signatory parties by extending the coordination of their system planning and operating procedures within the area, including parts of northeastern United States and eastern Canada.
1(c) Chan es in transmission with res ect to:
1,. Nuclear Plant Since information was last provided in 1978, the transmission plans for connecting the Nine Mile Point generating plant with the cross-state transmission grid have changed as follows: The originally planned single circuit 765 kV transmission line from
0 Nine Mile to Volney, 9 miles south, will be replaced with a single circuit,345 kV transmission line. A new 345 kV station is planned for construction just south. of the Nine Mile plant.
This station wQ1 interconnect all three nuclear plants Nine Mile Unit 1-, Nine Mil'e Unit 2, and J. A. Fitzpatrick. In addition, the 765 kV transmission line from Volney to Marcy (Utica. area) will be, energized at 345 kV rather than 765 kV as originally planned .
The change from 765 kV transmission to 345 kV transmission is a result of a change in plans for generation additions in New York State, especially in the Oswego area.
- 2. Interconnections
. In May 1978, the 345 kV interconnection between Homer City (Penna) and Stolle Road, a NYSEG station, was placed in service.
Although the line is under NYSEG control, NMP owns a 37 mile, portion which is within NMP franchise territory. In December, 1982, a 345 kV interconnection between Lafayette (vicinity of and Oakdale (vicinity of Binghamton) was placed in 'yracuse) service. Since. 1978, a 115 kV interconnection between Wells-vQle (NMP) and Bennett, (NYSEG) has been placed in service to provide mutual reliability of service to these, local areas and some short 115 kV interconnections have been placed in service to provide supply to local substations- and/or improve reliability.
These include Hamilton Road, Hyatt Road, and Dennison.
- 3. Wholesale Customers The Village of Green Island, New York was the last wholesale customer of Niagara Mohawk. On December l., 1978, Green Island ceased to be a Niagara Mohawk customer and-began to purchase its energy requirements from the Power Authority.
1(d) Chan es in the ownershi or contractual out ut of the nuclear facili No changes have occurred in the ownership or contractual, allocation-,
of the output of the nuclear facility..
l(e) Changes in design, provisions or conditions of rate schedules and reason for chan es.
Three new rate schedules have been added since 1978. Service
0 Classification 1-A is an optional time of use rate for residential customers. Service Classification 3-A is a time of use rate for large general service customers with a basic demand of not less than 2,000 kilowatts. Service Classification 3-B is an optional interruptible ser vice rate for large general service customers whose measured demand exceeds 2,000 kilowatts for two consecutive months and who receive three phase, 60 hertz alternating current service at a delivery voltage in excess of 22,000 volts.
These new rate schedules were added by order of the New York State Public Service Commission.
1.(f) List the following:
1)= New wholesal'e electric customers since 1978.
No new wholesale customers have been added..
2)'ransfers from one rate schedule to another since 1978.
With the inclusion of three new rates schedules, six customers have transferred to Rate 41-A,.227 customers have transferred to Rate 43-A and currently there are no customers in Rate 43-B (this is primarily due to the short time the rate,has been in existence);
- 3) Chan es in service area since 1978.
On May 8, 1981, the closing and transfer of the distribution facilities in the Village of Massena and parts of the towns of Brasher, Louisville, Massena, Norfolk and Stockholm took place. Massena now purchases its energy needs from PASNY. The service area involved is approxi-mately 120 square miles and the transfer involved 7640 customers.
- 4) Ac uisitions or me ers since 1978.
Niagara Mohawk Power Corporation has made no acquisitions or mergers since 1978.
1(g) List any new generating capacity additions committed for operation since 1978.
0 0
NIAGARA MOHAWK POWER CORPORATION
SUMMARY
OF ANTICIPATED GENERATING CAPACITY ADDITIONS AFTER NINE MILE POINT $ 2 YEAR UNIT 1'987 Glen Park Hydro 15.5 Oswegatchie Hydro 1.4 Oswego Falls W. Hydro 3.2 1988 Hudson Falls Hydro 36.1 Me chanicvill'e Hydro 10.0 Sugar'Island, Hydro 2:.4 1989 S. Glens Falls Hydro 12.0 1991 Lake..Erie 41 Fossil/Coal 850.0 1992 1993 Hadley '
Felts Mills
'Sherman Spier Falls
'ydro Islandydro Hydro Hydro 25.0 11.0 8.0 25.0.
1(h) Summary of requests or indications of interest by other retail or wholesale electric power distributors for any type of electric service or coo erative venture or stud Niagara Mohawk as a member of the New York Power Pool participates in studies with other member utilities in order to evaluate possible opportunities for-cooperative ventures to supply the needs of our future generation system.
Since 1978 Niagara Mohawk has established a wholly-owned subsidiary, HYDRA-CO., for the purpose of developing small hydro and co-generation..
This is a joint venture with Consolidated Gas.
~ g, ~ q Attachment 1 NIAGARA MOHAWK POWER CORPORATION FORECAST OF PEAK LOAD AND ENERGY 1977 PROJECTIONS 1982 PROJECTIONS Pe'ak-MW Ener -GWH Peak-MW Ener -GWH 1982 6420 38270 5380 31824 83 6630 39500 5430 32327 84 6870 40910 5450 32610 85 7100 42270 5560 33030 7310 43560 5740 34052 87 N/A 5930 35058 N/A'/A 88 N/A 6110 35964 ss N/A N/A 6210 36517 90 N/A N/A 6320 37035
V 4
Attachment 2 NIAGARA MOHAWK POWER CORPORATION COMPARISON OP PROJECTED CAPACITY ADDITIONS IN SERVICE DATES UNIT SIZE-MN ~1977 7 0 C* ON ~!'982 0 CZIO 9 Mile Point 42 1080* 1982 1986 Sterling 1] 50** 1986 Cancelled Lake Erie 41 850 1987 1'991 Lake Erie.@2 850 1989 Unknown
- NMF's share O 41%
- NMP's share Q 2'2%
Attachment 3 NIAGARA MOHAN'OWER CORPORATION PROJECTED EXCESS CAPACITY (MEGAWATTS) 1977 Pro ection 1982 Pro ection Required . Total Required Total Year ~Ca ecit~ ~Ca acit~ Excess ~Ca -~citC * ~Ca abaci Excess 1982 7576 8194 618 6348 6987 639 1983 7823 8220 397 6407 6964 557 1984 810.7 8482 376 6431 7222. 791 1985 8378 9326 948 6561 . 7202 641 1986. 8626 9326 700. 6773 7550 777 1987 N/A , N/A N/A 6997 7543 546
'/A 1988 N/A N/A 7210 7576 366 1989 N/A N/A N/A 7327 7583 256 1990 N/A N/A N/A 7458 7582 124
- Peak load + 18%
0 NRC Docket No. 50-410 NINE MILE POINT UNIT NO. 2 Information Required by the NRC Regulatory Staff in Connection with its Anti-Trust Review of
,Operating License Application Supplementing Information Submitted to the Attorney General for Anti-Trust Review in connection with the License Application for this Facility pursuant to 10 CFR 50, Appendix L CENTRAL HUDSON GAS 5 ELECTRIC CORPORATION (CH)
RF'-25(31)
0 INTRODUCTION During 1978 the information requested by the Attorney General for anti-trust review'f facility license applications (Appendix L) was submitted by CH, Long Island Lighting Company (LILCO), New York State Electric and Gas Corporation (NYSEG), Niagara Mohawk Power Corporation (NMPC), Rochester Gas and Electric Corporation (RGSE). In this proceeding NMPC is the applicant and the other utilities are co-owners.. >le have reviewed the CH portion of said 1978 filing with regard to the requirements of Regulatory Guide 9.,3 and have the following comments:
Item B.l(a)- Anticipated excess'r 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 other-wsse ut>1>zed or how the shorta e w>ll be obtained.
Since the original filing of the CH material, as part of Appendix L in 1978, CH's forecasted loads have been reduced. However, the forecasted installed capability has also been reduced. In this regard, the Sterling Nuclear Plant has been cancelled by Order of the Siting Board and the in-service date of the Nine Mile Point No. 2 Plant has been slipped to 1986. Accordingly, the anticipated excess capacity now projected by CH is approximately the same as that projected by CH in the Appendix L filing'. (See attached Table 2 for comparison.)
B.l(b) - New power pools or coordinating groups or changes in structure, activities, policies, practices, or membership of power pools or coordinating groups in which the licensee was, is, or will be a participant.
There have been no changes within these categories.
B.l(c) - Changes in transmission with respect to (1) the nuclear plant, (2) interconnections, or (3) connections to whole-sale customers.
There have been no changes in this regard which directly affect CH.
8 B.l(d) - Changes in the ownership or contractual allocation of the output of the nuclear facility. Reasons and basis for such chan es should be included.
There have been no changes in this regard.
B.l(e) - Changes in design, provisions, or conditions of rate schedules and reasons for such changes, rate increases or decreases are not necessar .
One new rate schedule has been added and one has been removed since the; 1978 submittal. These changes in service classification went into effect on October 22, 1982 as foll.ows.: Service CTassi-fication 6 was added. It is an optional Time-Of-Use rate for residential customers. Service Classification 4 was removed and customers taking service thereunder were transferred to Service Classification 3. Service Classification 3 was converted to- a Time-Of-Use- rate during 1978..
B.l(f)--- List the followinq:
(I) New wholesale electric customers since 1978:
No change (2) Transfers from one rate schedule to another since 1978:
Four customers. have. transferred to Service Classification 3 from.
Service Classification'4. At present, there are no customers on Service Classification 6 - Optional Residential Time-of-Use Service.
(3) Chan es in service area since 1978:
No changes (4) Ac uisitions or mer ers since 1978:
No changes B.l(g) - List of those generating capacity additions committed for operation after. the nuclear facility, including ownership ri hts or ower out ut allocations.
CH has no generating capacity additions committed for operation after the nuclear facility, including ownership rights or power output allocations.
0 B.l(h) - 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.
CH, as a member of the New York Power Pool, participates in studi.es with other member utilities in order to evaluate possible opportunities for cooperative ventures to supply the needs of, our future generation system. These studies are continuous in nature and have resulted in joint ventures such as Nine Mile Point 2 and Sterling. Also, Long Island Lighting Company contacted CH in the spring of 1982 concerning interest in a joint coal unit at Jamesport for inservice in the 1990's.
A preliminary study indicated that CH may possibly be interested, however, a more detailed study will be necessary before any conclusions could be reached.
In addition',. from time to time, CH receives unsolicited requests for the purchase of or offers for the sale of electric generating capacity. In recent years CH has not seriously considered offers for the sale of additional capacity other than for, very limited periods and due to the current excess .
capacity situation. In this regard, CH does, when excess capacity is avai,lable, send out solicitations to members of the New York Power Pool as well as to the members af PJM (Pennsylvania, New Jersey, Maryland Power Pool) and NEPEX (New England Power Exchange) which have resulted in several short .
term economy sales.
CH is not interested in the purchase of additional capacity other than from small scale hydro projects and other customer owned electric generating capacity as required by PURPA.
r 0
~ ~
TABLE 1 CENTRAL HUDSON COMPARISON OF PROJECTED EXCESS CAPACITY (mr)
Excess- Capacity Total Available Capabilitv Available Capability Re ized Ca acit Minus RequirecPCa ac8 1977'49b 1982 1977 1982 1977 '1982.
5-112 149b 5-112 149b 5-112 1982 1073 993 1015 802 58 1983 1089 1074 844 15 98 1984 1316 1093 1133 897 183 1985 1314 1091, 1204 938 15'3 1986 1314 1074 1274 956 40 118:
(l)Peak Load plus 18%. Reserve
8 NINE MILE POINT UNIT NO, 2.
Information Reguired by the NRC Regulatory Staff-in Connection With Its Anti-Trust Review of Operating License Application, in Accordance With Regulatory Guide 9.3 Supplementing Information Submitted to the Attorney General For Anti-Trust Review in Connection With The License Application. For. This Facility Pursuant To.
10 CFR SO, Appendix L ROCHESTER GAS AND ELECTRIC CORPORATION
~ ~ ~ ~
Rochester Electric Gas &
Nine Mile Point II Corp.
NRC Antitrust Review Reg. Guide 9. 3 Section 1(a) Su l chan es in. antici ated ca acit . reserves from those rolectxons submit.tted xn 1978.
Su l reasons wh chan es occurred and ow shorta e wall be obtained (or how excess will be utilized).
Changes in anticipated reserve projections since the 1978 submittal are shown in Attachments 1 & 2~
The changes in Required Capacity, Installed Capacity and resultant Excess Capacity shown on attachment 1 between the 1977 forecast and the 1982 .forecast. are predominately due 'to reduced system load growth. The excess capacity will be made available to other utilities through either, firm transaction or economy energy sales.'(b)
Describe an . chan es in structure, activities. policies or ractices. of ower ools since the 1978 submittal.
The data, as originally submitted, regarding power pool activities is still accurate.
1(c) Describe chan es in transmission with res ect, to (1) the nuclear lant (2) interconnections, (3) connections to wholesale customers since the 1978 submittal.
The only major change associated..with the nuclear plant transmission interconnection is a reduction by Niagara Mohawk in the proposed operating voltage from 765 kV to 345 kV and associated substation modifications.'..
RG&E has increased the interconnection capability the NYPP transmission grid by adding a 345/115
'o kV transformer.
- 3. There were no changes with respect to interconnections with wholesale, customers.
1(d) Describe chan es in ownershi or allocation of nuclear facilit since 1978.
No Changes 12/15/82'
0 1(e) Describe chan es in desi n, rovisions, or conditions of rate schedules and reasons for chan es. (Rate increases are not re uired.)
Two new rate schedules have been added since the 1978 submittal. Service classification 1-A is an optional time o f use rate for res identia 1 customers. Service classification 8 is a time of use rate for large general service customers with a basic demand of not less than 700 kilowatts.
These new rate schedules were added by order of the N.Y'.S. Public Service Commission on July 12, 1982 and apply to all New York State electric utility companies under PSC jurisdiction.
1(f) List the followin (1) Few wholesale electric customers since 1978, No change (2) Transfers from one rate schedule to another since 1978, With the inclusion of two new time of use rate= schedules 58 customers have transferred to rate g1-A and 150 customers.
have transferred to rate 58.
(3) Chan es in. service area since 1978 No changes in the electric service, area have taken place since 1978.
(4) Ac uisitions or mer ers since 1978 As to electrical. service, RGGE has made no mergers or aquisitions.
l(g) List an new eneratin ca acit additions committed for o eration since 1978.
No new commitments have been made. Since 1978, the Oswego 6 850 MW oil unit has been put in service. ln accordance with a 1975 Basic Agreement with Niagara Mohawk, RC&E is a cotenant with a 24% (204 MW) share
,of: the Oswego 6 unit. This Basic Agreement was submitted as Attachment 8-31 of. the 1978 Appendix L submittal.
12/15/82
0 1 (h) Su l summar other retail of re uests, or indications of interest b or wholesale electric ower distributors for an t e of electric service or coo erative venture or stud . Su l RGGE's res onse.
RGGE as a member of the New York Power Pool participates in studies with other member utilities in order to evaluate possible opportunities for cooperative ventures to supply the needs of our future generation system. These studies are continuous in nature and have. resulted in several previously reported joint ventures. In addition, from time to time the Company receives unsolicited requests for the purchase of or offers for the sale of electric generating capacity. In recent years the Company has not seriously considered offers for the sale of additional capacity other than for very limited periods and due to the current excess capacity situation the Comapny is not interested in the purchase of additional capacity. No file of these solicitations is kept and the Company typically does- not respond formally to them.
, JW4-I4 12/15/82
0 0
NINE MILE. POINT UNIT NO. 2 Information Reguired by the NRC Regulatory Staff in Connection With Its Anti-Trust Review of Operating License Application in Accordance With Regulatory Guide 9.3 Supplementing Information Submitted to the Attorney General Por Anti-Trust. Review in Connection With The License Application. Por This Facility Pursuant To 10 CPR 50, Appendix L.
NEW. YORK STATE'LECTRIC AND GAS
8 Nine Mile Pt. 2 Anti-Trust Review Regulatory Guide 9.3 la. Changes in anticipated capacity reserves.
Since the information on anticipated deficiencies on the NYSEG system was filed in 1978, the magnitude of those deficiencies have decreased.
The amount of planned installed capacity and- peak load forecasts have also decreased. Attachment 1 sets forth data comparing the current capacity.and peak load forecasts with those supplied in 1978. Attach-ment 2 sets forth a comparison of. current forecasted energy requirements since the 1978 submission.
The deficiencies between forecasted peak loads and installed capacity have been and will.be met primarily by purchases from the Power Authority
,of the. State. of New York (PASNY) as indicated in the 1978. filing. The availability of capacity from.PASNY has been presumed to continue over the forecast period.
- b. New power pools or changes.
No changes.
lc.. Changes in transmission with respect to:
- 1) nuclear plant Since Nine Mile Pt. 2 is located outside of NYSEG's service area, changes in transmission facilities associated with it do not directly affect NYSEG.
- 2) interconnections The Lafayette-Oakdale 345 kV transmission line connecting facilities of Niagara Mohawk Power Corporation in Lafayette, New York and NYSEG's Oakdale Substation near Binghamton, New York was placed in service on December 16, 1982. The Homer City-Stolle Road 345 kV transmission line, a portion of which is owned by Niagara. Mohawk Power Corporation became fully operational on April 28, 1978. Such line connects the Homer City generating station in which NYSEG and Pennsylvania Electric 'Company-each have a 50% interest to. the NYSEG Stolle Road Substation in the Town of Elma, New York. On December. 7, 1978 operation of a transmission line at 115,000 volts began between NYSEG's Bennett Substation and a Niagara Mohawk Power Corporation
0 0
Substation in Wellsvllle, New York. The Somerset-Dysinger 345 kV transmission lines connecting NYSEG's Somerset'enerating Station to the transmission grid in the State of New York through facilities of the. Power Authority of the State of New York are nearing completion.
Somerset Station is scheduled for commercial operation in December of 1.984.
- 3) No changes.
ld. No changes.
le. Rate changes'ince 1977, in addition. to normal increases, have generally simplified the rate structures by eliminating most blocks resulting in flatter rate structures. In May 1979 pursuant to a Public Service Commis-sion order Service Classification No. 2.General Service was made appli-.
cable to larger customers (over 5kw and more). and a new. Service Classifi-
- , cation No. 6'eneral, Service was made applicable to smaller customers (under. 5 kw). Pursuant.to an order of the Public Service; Commission. time of. day rates were*filed for large industrial and commercial customers in January,,1982,, but the Commission never made those rates effective.. In an order issued January 11, 1983, NYSEG was directed to file new time of.
day rates within 60 days .. Time of day industrial and commercial rates will be filed:within 60 days of January 11, and, if approved by the PSC, it is estimated. that. they would become effective in-the late winter or early.'pring of 1983..
lf. 1. There are no new wholesale customers on NYSEG's system.
- 2. See answer to le. above.
- 3. Effective October 31, 1980, the Village of Greene ceased taking ser-vice as a wholesale customer and reverted back to being a customer of the Power Authority of the State of New York.
On October 31, 1980, NYSEG acquired Peach Lake Utilities which was, until that time, a small wholesale customer of NYSEG serving appraximately 180 customers. Peach Lake Utilities was served under PPC No. 26 and NYPSC No. 194.
- 4. Same. as 3 above.
lg. None.
i 0
1h. NYSEG as a member of the New York Power Pool participates in studies, of a continuous nature, to evaluate possible opportunities for coopera-tive ventures to meet the generating capacity needs of individual companies and the New York Power Pool. These studies have resulted in joint ventures such as Nine MQe Point 2 and other units. In making planning studies, it is from time. to time necessary to determine the availability of capacity for purchases as an alternative to construction. However, these inquiries are for study purposes and do not evince an interest in buying or.
selling capacity.
In September 1980, NYSEG received an inquiry from Public Service Electric and Gas Corporation of New jersey (PSEGG) regarding NYSEG's interest in studies of possible joint ventures in generating capacity and energy exchange. Several discussions took place over a period of several months in exploring possible options. PSE&G withdrew from, the discussions in early 1981 with no joint studies. resulting from the discussions, largely due to obstacles caused by geographic separation of the two companies.
'n November, 1981', NYSEG was- approached.- by "Gas Alternative Systems, Inc; (GAS) regarding.'interest in developing a natural gas fired'co-genera- .
tion plant at the Clinton Corn, Products plant in NYSEG.'s Auburn District.
Negotiations are presentLy underway and could result in GAS developing a" co-generation plant of'approximately 100 Megawatts; the electrical out-,
put of which would. be sold to NYSEG, with process steam being sold to Clinton Corn Products.
+lY QtwQ'jg
~
)Earl NYSEG Requ'red and Installed Capacity (Megawatts)
Historical YEAR REQUIRED CAPACITY~ INSTALLED CAPACITY** DEFICIENCY"">>
1977 2400 1430 ,97 0 1978 2499 1779 720 1979 244S 1785 660 1980 2561 1793 768 1981 2588 1768 820 Pro 'ected 1977 Projection 1982 Projection REQUIRED* INSTALLED>>>> DEF IC IENCY*** REQUIRED>> INSTALLED>>* DEFICIENCY>>"
82 3434 1951 1483 2549 1783 1983 3611 2801 810 2572 1800 772 1984 3800 3376 424 2643 2432 1985 4000 3376, 624 2738 2432 306 1986 4213 3951 262 2832 2628 204 1987 2938 2628 310 1988 N/A N/A N/A 3044 2.62 8 416 1989 'N/A N/A N/A 3162 2628 534 1990 N/A 3280 2628 652
- Peak load + 18%
Does not include firm purchases. Reflects minor rating changes due to New York Power Pool semi-annual generator test procedures.
l
- ~ Deficiencies prior to 1982 were supplied by purchases of capacitY prima ~
li
~ ~
under long term contracts vith Pover Authority of the State of New York.
Subsequent to 1982 it, is presumed that the long term contracts identifie in the prior filing vill continue or be replaced with similar contracts.
>is:
ATTACHMENT 2 NYSEG System Energy Requirements
{Millions of Kilowatt-hours)
YEAR 1977 PROJECTION 1982 PROJECTION Historical 1977 11,600 11,316 1978 12,100 11,723 1979 12,600 12,113 1980 13,300 12,169 1981 13,900 12,258 1982 14,600 12,500 1983 15,3DD 12,750 1984 16,000 12,950 1985 16,800 13,200 1986 17,6DD 13i700; 1987 18,400 14,200 1988 19,300 14,700 1989 20,200 15,300 1990 21,000 15,900
~ a ~ y NINE. MILE.POINT UNIT NO. 2 Information Reguired by the NRC Regulatory'Staff in Connection With Its Anti-Trust Review of, Operating License Application in Accordance With Regulatory Guide 9.3 Supplementing Information Submitted to the Attorney, General For Anti-Trust Review in Connection With The License Application For This Facility Pursuant To l0 CFR 50, Appendix L LONG ISLAND LIGHTING COMPANY
LILCO Nine Mile Point 2 Anti-Trust Review Regulatory Guide 9.3 1(a) Chan es in antici ated ca acit reserves.
Since information on anticipated reserves was last provided in 1978, the magnitude of such reserves has increased. Although the level of planned installed capacity has decreased since 1978, the peak load forecast has also dropped substantially in the same period.
Besides showing historical data, Attachment 1 compares the current and previous capacity and peak load projections.
Attachment 2 shows the drop in forecasted energy requirements since the 1978 filing.
Proj ected reserves have been allowed to increase, rather than abandon completion of two nuclear plants, to permit displacement of more costly oil-fired'eneration and to provide'uel diversification. Both LILCO and New York .'.
State as a whole are heavily dependent on imported oil.
Displacement of oil-fired capacity promotes the national and state goals of energy independence as well as enabling LILCO over.; the'ong-term to provide the lowest cost of service possible for its customers.
1(b) New ower ools or chan es in structure, etc.
No changes.
l(c) Chan es in transmission with res ect to:
- 1) nuclear plant Since the plant is located outside of LILCO's territory, changes in plant transmission do not affect LILCO directly.
- 2) interconnections Since 1978, a 345KV interconnection was installed between the LILCO and Consolidated. Edison systems.
This interconnection is used for- economy interchange under the New York Power Pool's system for economic dispatch. It's also used to transmit power from the Power Authority of the State of New York (PASNY) to Long Island municipal electric systems and to Brookhaven National Laboratory. Starting in 1987, the load of the Metropolitan Transit Authority's Long
LILCO Island Rail Road will be served by this interconnection.
- 3) connections to wholesale customers Since 1978, several Long Island wholesale customers have entered into contracts with PASNY to receive power which is transmitted over LILCO's 345 KV tie interconnection (see 1C-2 above). The Villages of Freeport and Rockville Centre now receive increased allocations from PASNY and are no longer normally served by LILCO. The Village of Greenport is also served by PASNY. These contracts have been approved by the Federal Energy Regul'atory Commission.
Brookhaven National Laboratory is still served in part by LILCO, but now receives an allocation of power from
- PASNY.
1(d) Chan es in the ownershi or contractual out ut of the nuc ear aci zt No changes.
l(e) Chan es in desi , rovisions or conditions of rate sc e u es an reasons or c an es. ate increases are In 1978, LILCO added a restricted demand rate provision to its existing mandatory time-of-use rate for large commercial/industrial customers, i.e., those whose maximum demand exceeds 750 KW in any two of the previous twelve months. The provision allows large commercial/industrial customers to choose a modified demand rate.
In January 1980, LILCO's mandatory time-of-use rate for large residential customers, i.e., those whose annual electric use is in excess of 45,000 KWH, became effective. The "temperature sensitive" rating period in this rate, which was effective during the summer months, was eliminated in May of 1982, since i6 was not cost-effective.
1(f) List the followin
- 1) New wholesale electric customers since 1978, No change.
LILCO
- 2) Transfers from one rate. schedule to another (inc u in co ies o sc e u es).
Two hundred fifty-six commercial/industrial customers have been transferred to the SC2-NRP mandatory time-of-use. rate, including 8 who have chosen the restricted demand rate provision. described above.
Nine hundred twenty-two have been transf'erred to the mandatory rate for large residential customers (SC1-IEP). Copies of both of these time-of-use rate classifications are attached.
- 3) Chan es in service. area since 1978 No changes.
- 4) Ac uisitions or mer ers since 1978 LILCO has made no mergers- or acquisitions since the 1978 filing.
1(g) Generatin ca acit additions committed for o eration a ter Nine Mi e Unit g2 No generating capacity additions are committed for operation after Nine Nile Point g2.
1(h) Summar of re uests or indications of interest b other e ectric ower w o esa e or retai z.stri utors, an icensee s res onse, or an t e o e ectrx.c service or coo erative venture or stu LILCO on a regular basis receives unsolicited.-offers for the sale of co-owned electric generating capacity. The Company, with its present excess generating capacity, has not proceeded with the. procurement of additional capacity, except for very limited periods, where energy is purchased as available purely from an economic viewpoint. Because of the numerous quantity of'hese requests and the varied degree of plant development and'onception, the Company does not'aintain a complete file of these solicitations nor does it always. respond to these requests.
member of the New York Power Pool'NYPP) at times does LILCO as a participate in joint studies with other member utilities to evaluate possible opportunities for cooperative ventures to supply the needs of its future generation system. As a result of these joint efforts, LILCO currently is pursuing two joint venture projects: Nine
LILCO llile Point 2 and Jamesport. As to the status of the Jamesport project, in May 1982, LILCO solicited expressions of possible interest in capacity ownership of an 800 NW coal-fired power plant, to be located at Jamesport, Long Island, which has previously been certified for construction by the New York State Board on Electric Generation Siting and the Environment. LILCO's solicitation was sent to a number of wholesale. and retail distributors of'lectricity, in both New York State and New England. Four companies expressed. potential interest in participation in the Jamesport coal plant and LILCO is currently conducting studies, which it will make available to the companies, with respect to the optimum size and timing of-future -coal plant capacity on Long Island.
I I I ~ /
"C ar es,J. Davis Senior Vice President
g II Te ATTACHE.=l:.T' LXLCO Required. and, Installed Capacity (Negawatts)
Historical Yeas. Re unbred Cacac1t Insta11ed Ca acitv<<<< Excess 3727 60 1977'978 3667'536 3874 '38 1979 3444 3874 43P 1980 3709 3721 12 19 81 3696 3721 25 Pro ected 1977 Pro)ection 1982 Pro) ection
~ll 1 1 1.;-11 Heaufred<<'- Xnsta 11 d."":-xces 1982 4602 4793 191 3599 3731 122 1983 4755 4987 232 3646, 4023 1984 4956 4987 31 3693 4562 869 1985 5151 5562 4p5 4562 821.
1986 5'381 5562, 181 4562 774.
3788'776 1987 N/A N/A. N/A 4756 980 1988 N/A N/A N/A 3835 4752. 917 1989 N/A: N/P N/A 3894 850 1990 N/A N/A N/a-. 3959 4740 '781
<< Peak load +
18~'ot
<<<<Does include firm purchases
ATTACVi.=:.: 2 LILCO System Energy Requirements (Millions of Kilovatt-hours)
I Year 1 Pro ect on 1 82 Pro'e""'".
Historical 1977 13 >930 13,603 1978 14,500 .130720 1979 15,140 13>734 19 80 15,880 14,014 19 81. I6,600 13,811 Pro ect 1982 17 0510 13 466 1983 -
18',110 13',605'3,851 1984 18 ~990 1985 19,810 14,256 1986 20,690 14,623
. 1987 N/A 14 >951 1988 N/A 15,143 19 89 N/A ',5,448 1990 N/A 15a730
'$C gr A
's~ I I) / s
(
I~
0 ~ ~
h
,J tp f!':atlgC'
~ . ~
~ ~
~ ~
~ o
~ ~
~ ~ ~ . ~
~ ~ o o o
' ~
' ~
' I ~ o ~ ~
o o o . ~ 1 ~ ~ ~ ~ ~ ~ I o ~ ~
' ~ ~
o ~ ~ << ~
~ o ~ o
~ ~
~ I II I
<<I I ~
~
I I
II <<<<'
'l o ~ '
~
~
~ o o
~ ~
I I~
~ ~
~
~
II ~
o~
~ ~ ~ ~ ~ ~ ~
' o I III ' '
~ ~
o'II ~ ~ ~ ~ ~ ~ ~ ~
' III ~ III ~ o
~
<< III o ~ ~
~
~ ~ ~ o '
~ o
~ o I <<
o<< ~ <<o I o ~
~
~
~ o
~
~
~
~
' o ~ ~ ~
~ ~ o ~ ~
~
' ~ o ~ ~ ~ ~
V 0 ~
I
~ ~
~ i
P. S. C. No. 7 Electricity Fifth Revised Leaf No. 33J Long Island Lighting Company Superseding Fourth Leaf No. 33J SERVICE CLASSIFICATION No. 2-MRP Large- General and Industrial Service With Multiple Rate Periods (Continued)
Minimum Charge:
None.
Determination of Demand:
The maximum 15 minute demand during the month in each rate period shall be determined by a recording demand meter furnished and maintained by the Company. The demand as cletermined shaH be taken to the nearest one-tenth kilowatt.
Terms of Payment:
Net cash, subject to late payment charge in accordance with'rovisions of Rule 3E.2.
Terms i One year and thereafter until terminated by 30-days'ritt'en notice by either
.party. ghe Company may, with the permission of the Public Service Com-mission, require the customers to agree to- take service. at rates from time effectiv- for a longer term, dependent upon the investment required or to'ime other unusual conditions incident to this service.
Special Provisions:
(a) Where the installation includes welders, X-rays or other inherently single phase apparatus liaving a highly fluctuating or large instantaneous demand, the customer shall provide batteries, rotating equipment or otlier correc-tive equipment to reduce the inr'ush current to an amount acceptable to the Company.
(b) For service at 69,000 volts or higher, the applicant wiH be required to provide and maintain voltage regulating equipment and circuit breakers complete with appurtenances in accordance with procedures and schedules
">>'i
>> as specified by the Company.
(c) KVhen there is an applicant for an existing account and in the Company's opinion the type of activity in which the applicant's establishment is engaged'wiH change the characteristics of the account's loads, it will be considered as a new account for eligibility as explained in the Applica-bility Clause.
(d) Interim Bill: In the case of malfunction of any portion of, the metering installation that would delay the rendering of a bill at the scheduled time, an interim bill may be submitted based on the Intermediate Period Demand Charge and the Off-Peak Period Energy Charge or in accor<l-ance ivith Rule 3F
'i >>
Date of Issue: February 3, 1978 Date Effective: hlarch 20, 197S Issu<<d by KYilfred O. Uhl, President 250 Old Country Road, Mineola, N. Y.
~ ~
~
(
/
I
~ .
I
~~
P. S; C. No. 7'-Electricity Third Revised Leaf No. 33K Long bland Lighting Company Superseding Second Revised Leaf No. 33K SERVICE CLASSIFICATION No. 2-MRP Large General, and Industrial Service With Multiple Rate Periods (Continued)
Special Provisions (Continued):
(e) Restricted Demand Service:
.1 Customers or applicants who by written contract agree, upon a minimum of 18-hours notice from, the Company of the anticipat.ion of a Critical Peak Day Occurrence, to limit their On-Peak Rate Period K% to an On-Peak Rate Period "Contract KlV" ( renewable every ibfay 1) will substitute the following Demand Charges for the On-Peak Rate Periods shown above:
On Peak Period Y I Pr iod ~Ciii al Da Demand Charge: % uf Abave Per KIV Demand Charges 0 to "Contract,KEV"..., 100 100 Excess of "Contract KW" ...., 50- 200'2 Customers that have their own generating equipmcnt may provide all.or a portion of. their curtailed Critical Peak Day KlV by said equipmcnt if they meet the applicable requirements of Rulc 9D.2 Emergency Generating Facilities, as to wiring and switching, equipment; and if by the above contract they specify that the generating equipment will be used only during the critical days. and for necessary testing purposes.
(f) Submctering may bc aiailablc under-certain conditions sct forth in Rule 2F.
Date of Issue: September 24, 1982 Date Eftcctivc: November 26, 1982 Issued by IVilfrcd 0. Uhl, President 250 Old Country Road, Mineola, N. Y.
~ ~
~(
'I(. ~ ~ ((
~,
~ ~
Q 'I o
~
Q (4 (
Sh h g
- 5. <L:;La ?9: ';
tl" p o.".
'( ~ .
n4
(/ f I
~~ I t I'It h
P. S. C. No.? Electricity Fift'eenth, Revised Leaf No. 28C Long bland Lighting Company Superseding Fourteenth Revised Leaf No. 28C SERVICE CLASSIFICATION No. I.MRP Large Residential Service With Multiple Rate Periods Applicable to Use of. Service for.
All residential purposes as defined in Rule 9C of this schedule which by reference is made a part hereof and when the annual consumption for and existing account exceeds 45,000 KWH for the year ending September 30 or when a new dwelling unit with no previous electric consumption is estimated to exceed 45,000 KWH annually. If after twelve months a new dwelling unit does not,record an annual consumption exceeding 45,000 KWH, at the option of the customer, the account will be transferred to Service Classification No. 1. Applicability optional to qualifying religious accounts.
Character of Service:
Continuous, 60 hertz, alternating current; at approximately 120/208 or 120/240 volts, single phase
'e or three phase; depending upon the characteristics of the load and the circuit from which service is to supplied.
Rate: Total of two Rate Periods (per meter, per month)
Energy Charge:
C r KiVH Rate Period Hourt Junc through October through Eastern Da li ht Time ~Sc !ember ~lla 10-p.m, to 10 a.m. Period 1 Period 2 and Sunday 7.9? ( 7.47(
10 a.m. to 10 p.m. Period 3 Period 4 except Sunday. 17.80$ 8.97$
Fuel Adjustment:
The kilowatthours billed. for Periods 1, 2, 3 and 4 shall be subject to a fuel cost adjustment as explained'on Leaf No. 26 and No. 26A.
Increase in Rates and Charges:
All rates and charges under this service classification are increased by the applicable percentage as explained on Leaf No. 26A for service supplied within the municipality where the customer is taking service.
Minimum Charge:
$ 9.93 per meter per month, exclusive of Fuel Adjustment and Increase in Rates and Charges Maximum Charge:
The annual charges as calculated under this rate, including Fuel Cost Adjustment and Increase in Rates and Charges are not to exceed the annual charges as calculated under Residential Service Classification No. 1 by more than 10 percent. This limitation will only apply to customers taking this service for the first time and only after their first 12 months of experience.
Terms of Payment:.
Net cash.
Terin Terminable by the customer on five (5) days'ritten notice to the Company and by the Company in the manner provided by law and the rules and regulations of the Company.
Termination by qualifying religious accounts followed by renewed service at the same location by the same account within one year will not be permitted.
Date of Issue: April 7, 1982 Date Effective: May 7, 1982 Issued by Wilfred 0. Uhl, President 250 Old Country Road, Mineola, N. Y.
1'I
)B
'I
'0
'l' C.
4
P. S. C. No. 7 Electricity Sixth Revised Leaf No. 28D Superseding Fourth Revised Leaf No, 28D Long Island Lighting Company (Fifth Revised Leaf No, 28D Canceled)
SERVICE CLASSIFICATION No. I-MRP Large Residential Service With Multiple Rate Periods
( Con tinued )
Special Provision:
(a) Canceled (b) ~Vhere there is an applicant for an existing account and in the Company's o'pinion the eligibility for this rate no longer exists, it v ill be considered as a new account for eligibilityas explained in the Applicability Clause.
Date of Issue: April 7, 1982 Date Effective: May 7, 19S' Issued by Nilfred 0. Uhl, J'rcsidear 2SO Old Country Road, Mineola, N. Y.
I
'