environ rept,vol 1 of 4. - nuclear regulatory commissiona p p. o. box 2i666 'hoenix>arizona...
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P. O. BOX 2I666 'HOENIX> ARIZONA 85036December 5, 1979ANPP-14339 - JMA/DBK
Director of Nuclear Reactor RegulationU.S. Nuclear Regulatory CommissionWashington, D.C. 20555
Re:
Reference:
Dear Sir:
Joint Application for Operating Licensesfor Palo Verde Nuclear GeneratingStation Units 1, 2 and 3
NRC Docket Nos. STN 50-528/529/530
(A) Letter, ANPP-13904 dated October 1, 1979 toDirector of Nuclear Reactor Regulation fromE. E. Van Brunt, Jr., Vice President, APS
Pursuant to 10 CFR Par t 50, Arizona Public Service Company (APS)submitted by Reference (A) the joint application for issuance ofoperating licenses for the Palo Verde Nuclear Generating StationUnits 1, 2 and 3 (PVNGS).
As part of this joint application, and pursuant to 10 CFR 51.21,APS submits the PVNGS Environmental Report - Operating License Stage(ER-OL) .
This submittal of the PVNGS ER-OL completes the joint applicationfor issuance of operating licenses for PVNGS.
Respectfully submitted,
ARIZONA PUBLIC SERVICE COMPANY
EEVBJr /DBK/avAttachment: 20 copies of
the PVNGS ER-OL,as required by10 CFR 50.30 (C)(3) (iii)
)'
wean E. Van Brunt, Jr.Vice President
On its own behalf and as agentfor all other joint participants.
Director of Nuclear Reactor RegulationDecember 5, 1979ANPP-14339 - JMA/DBKPage 2
STATE OF ARIZONA )) ss.
County of Maricopa )
Subscribed and sworn to before me this@2 day of oct ~, 1979.
Notary Pub c
My Commission expires:
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Palo Verde Nuclear Generating StationER-OL
PIPING AND INSTRUMENT DIAGRAMLEGEND AND SYMBOLS
(Sheet 2 of 2)
Figure F-1
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1
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ili
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1
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PVNGS ER-OL
CONTENTS
1. PURPOSE OF THE PROPOSED FACILITY AND
ASSOCIATED TRANSMISSION
1.1 SYSTEM DEMAND AND RELIABILITY1.1.1 IOAD CHARACTERISTICS
1.1.2 SYSTEM CAPACITY
1.1.3 RESERVE MARGINS
1.1.4 EXTERNAL SUPPORTING STUDIES
1.2 OTHER OBJECTIVES
1.3 CONSE UENCES OF DELAY
APPENDIX 1A RESPONSES TO NRC UESTIONS
APPENDIX 1B ARIZONA PUBLIC SERVICE COMPANY LOAD
FORECAST METHODOLOGY
APPENDIX 1C LOS ANGELES DEPARTMENT OF WATER AND,
POWER LOAD FORECASTING METHODOLOGY
APPENDIX 1D EL PASO ELECTRIC COMPANY LOAD
FORECASTING METHODOLOGY
APPENDIX 1E PUBLIC SERVICE COMPANY OF NEW MEXICO
FORECASTING METHODOLOGY
APPENDIX 1F SALT RIVER PROJECT LOAD FORECASTING
METHODOLOGY
APPENDIX 1G SOUTHERN CALIFORNIA EDISON COMPANY
FORECASTING METHODOLOGY
APPENDIX 1H ARIZONA PUBLIC SERVICE COMPANY
RESPONSE TO FPC ORDER NO. 496
APPENDIX 1I LOS ANGELES DEPARTMENT OF WATER
AND POWER RESPONSE TO FPC
Pacae
1 ~ 1 1
1 ~ 1 1
1.1-21.1-91.1-101.1-121 ~ 2 1
1 ~ 3 1
APPENDIX 1J
APPENDIX 1K
ORDER NO. 496
EL PASO ELECTRIC COMPANY RESPONSE
TO FPC ORDER NO. 496 AND ENERGY
CONSERVATION PROGRAMS
PUBLIC SERVICE COMPANY OF NEW MEXICO
RESPONSE TO FPC ORDER NO. 496
PVNGS ER-OL
CONTENTS (cont)
2.42.4.12.4.22.4.32.52.5.12.5.22.5.32.5.42.6
HYDROLOGY
SURFACE WATER
GROUNDWATER
REFERENCES
GEOLOGY
REGIONAL GEOLOGY
SITE GEOLOGY
SEISMIC HISTORY
REFERENCES
REGIONAL HISTORIC, ARCHAEOLOGICAL,
ARCHITECTURAL, SCENIC, CULTURAL, AND
NATURAL FEATURES
APPENDIX 1L SALT RIVER PROJECT RESPONSE TO
FPC ORDER NO. 496
APPENDIX 1M SOUTHERN CALIFORNIA EDISON COMPANY
RESPONSE TO FPC ORDER NO. 496
2. SITE AND ENVIRONMENTAL INTERFACES
2.1 GEOGRAPHY AND DEMOGRAPHY
2.1.1 SITE LOCATION AND DESCRIPTION
2.1.2 POPULATION DISTRIBUTION
2) 2.1.3 USES OF ADJACENT LANDS AND WATERS
2.1.4 REFERENCES
2.2 ECOLOGY
2.2.1 VEGETATION
2.2.2 FAUNA
2.3 METEOROLOGY
2 '.1 REGIONAL CLIMATOLOGY
2.3.2 LOCAL METEOROLOGY
2.3.3 METEOROLOGICAL DATA RECOVERY
2.3.4 ATMOSPHERIC DISPERSION ESTIMATES
2.3.5 ABSOLUTE HUMIDITY
2.3.6 REFERENCES
Pacre
2.1-12%1 1
2%1 1
2%1 3
2.1-6A2%1 32
2%2 1
2+2 1
2%2 2
2%3 1
2.3-12%3 12
2.3-482.3-482.3-48A2.3-622.4-12.4-12.4-22.4-92.5-12.5-12.5-12.5-42.5-4
2.6-1
Supplement. 2 V3.3.X March 1981
PVNGS ER-OL
CONTENTS (cont,)
4.3.1 COMMITMENTS CONSIDERED
4.3.24 4.
4.4.14.4.24.54.5.14.5.24.5.3
REFERENCES
RADIOACTIVITYCONSTRUCTION DOSES
REFERENCES
CONSTRUCTION IMPACT CONTROL PROGRAM
GENERAL DESCRIPTION
RESPONSIBILITY AND AUTHORITY
PROGRAM DESCRIPTIONS
5.1 EFFECTS OF OPERATION OF HEAT DISSIPATIONSYSTEM
APPENDIX 4A RESPONSES TO NRC UESTIONS
5. ENVIRONMENTAL EFFECTS OF STATION OPERATION
Pa<ac
4.3-14. 3-44.4-14.4-14.4-14.5-14.5-14.5-24.5-3
5.1-15.1-1
5.1.1
5.1.25.1.35.1.45.1.55.25.2.15.2.25.2.3
EFFLUENT LIMITATIONS AND WATER QUALITYSTANDARDS
PHYSICAL EFFECTS
BIOLOGICAL EFFECTS
OTHER EFFECTS
REFERENCES
RADIOLOGICAL IMPACT FROM ROUTINE OPERATION
EXPOSURE PATHWAYS
RADIOACTIVITY IN ENVIRONMENT
DOSE RATE ESTIMATES FOR BIOTA OTHER
5.1-2
5.1-25.1-35.1-35.1-235.2-15.2-15.2-25.2-6
5.2.45.2.55.35.3.15.3.25.3.35.4
DOSE RATE ESTIMATES FOR MAN
SUMMARY OF ANNUAL RADIATION DOSES
EFFECTS OF CHEMICAL AND BIOCIDE DISCHARGES
BLOWDOWN EFFECTS
EFFECTS OF COOLING TOWER DRIFTREFERENCES
EFFECTS OF SANITARY AND OTHER WASTE DISCHARGES
5.2-85.2-125.3-15.3-15.3-35.3-35.4-1
PVNGS ER-OL
CONTENTS (cont)
5.4.1 SANITARY WASTE
5.4.2 GASEOUS EFFLUENTS
5 . 4. 3 REFERENCES
5.5 EFFECTS OF OPERATION AND MAINTENANCE OF THE
TRANSMISSION AND CONVEYANCE SYSTEMS
5.5.1 TRANSMISSION SYSTEM
5.5.2 WASTEWATER CONVEYANCE PIPELINE5.5.3 REFERENCES
5.6 OTHER EFFECTS
5.6.1 ENVIRONMENTAL EFFECTS OF WATER DIVERSION5.6.2 PLANT OPERATION NOISE
5.6.3 OPERATIONAL WORKFORCE IMPACTS
5.6.4 REFERENCES
5.7 RESOURCES .COMMITTED
5.7.1 REPLACEABZE COMPONENTS AND CONSUMABZE
MATERIAZS
5.7.2 CONSUMPTIVE WATER USE
5.7.3 ENVIRONMENTAL LOSSES
5.7.4 LAND RESOURCES
5;8 DECOMMISSIONING AND DISMANTLING5.8.1 DECOMMISSIONING AND DISMANTLING POLICIES5.8.2 REFERENCES
APPENDIX 5A RESPONSES TO NRC UESTIONS
APPENDIX 5B EVALUATION OF COMPLIANCE WITH
APPENDIX I OF 10CFR50 AND 40CFR190APPENDIX 5C SUMMARY OF THE INDUSTRIAL SOURCE
COMPLEX MODEZ ISC6. EFFLUENT AND ENVIRONMENTAL MEASUREMENTS AND
MONITORING PROGRAMS
6,1 APPLICANT'S PREOPERATIONALENVIRONMENTAL'ROGRAMS
6.1.1 SURFACE WATER
Pacre
5.4-15.4-15.4-85.5-1
5.5-15.5-65.5-65.6-15.6-15.6-85.6-125.6-135.7-15.7-1
5.7-15.7-15.7-15.8-15.8-15.8-2
6.1-1
6.1-1
6.1-1
Supplement 4 Xii December 1981
PVNGS ER-OL
CONTENTS (cont)
6.1.26.1.36.1.46.1.56.1.66.1.76.2
6.2.16.2.26.2.36.2.46.2.56.2.66.3
GROUNDWATER
METEOROZ OGY
LAND
RADIOLOGICAZ MONITORING
NOISE
REFERENCES
APPZICANT'S PROPOSED OPERATIONAL MONITORING
PROGRAMS
SURFACE WATER MONITORING
OPERATIONAZ GROUNDWATER MONITORING
METEOROZOGICAL MONITORING PROGRAM
OPERATIONAL ECOLOGICAL MONITORING
RADIOZOGICAZ MONITORING
OPERATIONAL NOISE MONITORING
RELATED ENVIRONMENTAL MEASUREMENT AND
Pacae
6.1-26.1-56.1-216.1-286.1-366.1-406.2-1
6.2-16.2-16.2-26.2-26.2-26.2-26.3-1
MONITORING PROGRAMS
6.3.1 NONRADIOLOGICAL MONITORING PROGRAMS
6.3.2 RADIOLOGICAZ MONITORING PROGRAMS
6.4 PREOPERATIONAL ENVIRONMENTAL RADIOLOGICAZ
MONITORING DATA
APPENDIX 6A RESPONSES TO NRC UESTIONS
7. ENVIRONMENTAL EFFECTS OF ACCIDENTS
6.3-16. 3-26.4-1
F 1 1
7.1 STATION ACCIDENTS INVOLVING RADIOACTIVITY " 7.1-17.1.1 INTRODUCTION
7.1.2 SHORT-TERM ACCIDENT WIND DIFFUSION ESTIMATES
7.1.3 ACCIDENT DISCUSSION
7.1.4 SUMMARY OF ENVIRONMENTAL CONSEQUENCES
7.2 TRANSPORTATION ACCIDENTS INVOZVING
RADIOACTIVITY
7.3 OTHER ACCIDENTS
7.3.1 ACCIDENTS INVOZVING THE SWITCHYARD
7 ~ 1 1
7 ~ 1 1
7 ~ 1 2
7.1-227 ~ 2 1
7 ~ 3 1
7.3-1
March 1981 X3.1,3. Supplement 2
PVNGS ER-OL
CONTENTS (cont)
7.3.2 ACCIDENTS INVOLVING FUEL OIL AND IPGSTORAGE TANKS
7.3.3 ACCIDENTS INVOLVING HAZARDOUS GASES
7.3.4 ACCIDENTS INVOLVING HAZARDOUS LIQUIDSAND CHEMICALS
APPENDIX 7A RESPONSES TO NRC UESTIONS
8. ECONOMIC AND SOCIAL EFFECTS OF STATION
CONSTRUCTION AND OPERATION
8.1 BENEFITS
8.1.1 DIRECT BENEFITS
8.1.2 INDIRECT BENEFITS
8.1.3 OTHER BENEFITS
.8.1.4 IMPACTS IF OPERATION IS DELAYED
8.1.5 REFERENCES
8.2 COSTS
8.2.1 ESTIMATED INTERNAL COSTS
8.2.2 EXTERNAL COSTS
APPENDIX 8A RESPONSES.TO NRC UESTIONS'. 'LTERNATE ENERGY SOURCES AND SITES
APPENDIX 9A RESPONSES TO NRC UESTIONS
10. STATION DESIGN ALTERNATIVES
APPENDIX 10A RESPONSES TO NRC UESTIONS
11. SUKlARY COST-BENEFIT ANALYSIS11; 1 INTRODUCTION
11.2 BENEFITS
11.2.1 DIRECT BENEFITS
11.2.2 INDIRECT BENEFITS
11.3 COSTS
11.3.1 DIRECT COST
11.3.2 INDIRECT COST
11.4 CONCLUSION
APPENDIX 11A RESPONSES TO 'NRC UESTlONS
Parcae
7 ~ 3 1
7 ~ 3 2
7 ~ 3 3
8.1
8.1-18.1-18.1-18.1-138.1-178.1-18
'.2-1
8.2-18.2-1
9-1
10-1
11-111-111-111-111-111-211-211-211-3
Supplement 4 X3.V December 1981
PVNGS ER-OL
CONTENTS (cont)
12. ENVIRONMENTAL APPROVALS AND CONSULTATIONS
12.1 STATUS OF LICENSES, PERMITS AND APPROVALS
12.2 STATUS OF TRANSMISSION SYSTEM PERMITS
12.3 WATER. UALITY CERTIFICATION UNDER SECTION 401OF THE FEDERAL WATER POLLUTION CONTROL ACT,
AS AMENDED
12.4 STATUS OF CONTACTS WITH STATE, LOCAL AND
REGIONAL PLANNING AUTHORITIES
APPENDIX 12A RESPONSES TO NRC UESTIONS
13. REFERENCES
APPENDIX 13A RESPONSES TO NRC UESTIONS
Pacae
12-112-112-112-1
12-1
13-1
PVNGS ER-OL
CHAPTER 1
PURPOSE OF THE PROPOSED FACILITYAND ASSOCIATED TRANSMISSION
CONTENTS
1.1 SYSTEM DEMAND AND RELIABILITY1.1.1 LOAD CHARACTERISTICS
1.1.1.11.1.1.21.1.1.31.1'. 2
1.1.3
Load Anal sisDemand Pro'ectionsPower Exchan es
SYSTEM CAPACITY
RESERVE MARGINS
1.1.4 EXTERNAL SUPPORTING STUDIES
1.2 OTHER OBJECTIVES
1.3 CONSE UENCES OF DELAY
APPENDIX lA RESPONSES TO NRC UESTIONS
APPENDIX 1B ARIZONA PUBLIC SERVICE COMPANY LOAD
FORECAST METHODOLOGY
APPENDIX 1C LOS ANGELES DEPARTMENT OF WATER AND
POWER LOAD FORECASTING METHODOLOGY
APPENDIX 1D EL PASO ELECTRIC COMPANY LOAD
FORECASTING METHODOLOGY
APPENDIX lE PUBLIC SERVICE COMPANY OF NEW MEXICO
FORECASTING METHODOLOGY
APPENDIX 1F SALT RIVER PROJECT LOAD FORECASTING
METHODOLOGY
APPENDIX 1G SOUTHERN CALIFORNIA EDISON COMPANY
FORECASTING METHODOLOGY
APPENDIX 1H ARIZONA PUBLIC SERVICE COMPANY
RESPONSE TO FPC ORDER NO. 496
Pacae
1.1-11 ~ 1 2
1. 1-21.1-41.1-9A1.1-91.1-101.1-121 ~ 2 1
1.3-1
March 1981 Supplement 2
PVNGS ER-OL
CONTENTS (cont)
APPENDIX 1I LOS ANGELES DEPARTMENT OF WATER
AND POWER RESPONSE TO FPC
ORDER NO. 496APPENDIX 1J EL PASO ELECTRIC COMPANY RESPONSE
TO FPC ORDER NO. 496 AND ENERGY
CONSERVATION PROGRAMS
APPENDIX 1K PUBLIC SERVICE COMPANY OF NEW MEXICO
RESPONSE TO FPC ORDER NO. 496APPENDIX 1L SALT RIVER PROJECT RESPONSE TO
FPC ORDER NO. 496APPENDIX 1M SOUTHERN CALIFORNIA EDISON COMPANY
RESPONSE TO FPC ORDER NO. 496
Supplement 3 1-ii July 1981
PVNGS ER-OL
TABLES
1.1-11 Q 1 2
1.1-3
1.1-4
1.1-5
1.1-6
1.1-7
Loads and Resources Summary 1964 Through 1992Load and Energy Requirements by Month 1981
Through 1988PVNGS ParticipantsArizona Public ServiceLos Angeles Department of Water and PowerEl Paso Electric CompanyPublic Service Company of New MexicoSalt River ProjectSouthern California Edison
Load and Resources Summary Combined Arizona-New Mexico (AZ-NM) and SouthernCalifornia-Nevada (SoCA-NV) Systems asReported to the WSCC (1972 Through 1987)
Loads Summary by Month Combined Arizona-New Mexico (AZ-NM) and Southern California-Nevada (SoCA-NV) systems as Reported to theWSCC (1982 Through 1987) .
Comparison of Actual Peak Demands and EnergyRequirements in 1973 Through 1978 WithForecasts Made in Prior Years for CombinedWSCC Southern California-Nevada andArizona-New Mexico System
Actual 1978 Demands and Energy RequirementsCompared With WSCC Forecasts Made in1972-1977 for Combined WSCC SouthernCalifornia-Nevada and Arizona-New MexicoSystem
Comparison of Monthly Peak Demands and EnergyRequirements 1972 Through 1978
Pacae
1.1-15
1.1-291.1-451.1-611 ~ 1 771.1-931.1-1091.1-1251.1-141
1.1-143
1.1-149
1.1-150
1.1-151
July 1981 1-iii Supplement 3
PVNGS ER-OL
TABLES (cont)
1.1-8
1.1-9
1.1-10
1.1-11
1 ~ 1 1 2
Capability of Resources 1968 Through 1988
PVNGS 1,2&3 ParticipantsArizona Public ServiceLos Angeles Department of Water and Power
El Paso Electric Company
Public Service Company of New MexicoSalt River ProjectSouthern California Edison
Western Systems Coordinating Council ExistingGenerating Capability as of January 1, 1979
Arizona-New Mexico Power AreaSouthern California-Nevada Power Area
Western Systems Coordinating Council Summary
of Generation AdditionsArizona-New Mexico Power AreaSouthern California-Nevada Power Area
Comparison of Participants GeneratingCapacity, Load, and Energy Generation
Arizona Public ServiceLos Angeles Department of Water and Power
El Paso ElectricPublic Service of New MexicoSalt River ProjectSouthern California Edison
SCPPA Member Agencies Loads and ResourcesCity of Anaheim Electric Utility SystemCity of Azusa Electric Utility SystemCity of Banning Electric Utility System
PacCe
~ 1.1-1651.1-1671 ~ 1 1731.1-1771.1-1791.1-1811.1-187
1.1-1911.1-201
1.1-2131.1-217
1.1-2231.1-2241.1'-225
- - 1. 1-2261.1-2271.1-228
1.1-2291;1-2301.1-231
Supplement 3 1-iv't
July 1981
PVNGS ER-OL
Tables (cont)
Pa<ac
City of Burbank Electric Utility SystemCity of Colton Electric Utility SystemCity of Glendale Electric Utiltiy SystemCity of Pasadena Electric Utility SystemCity of Riverside Electric Utility Syst: em
City of Vernon Electric Utility SystemImperial Irrigation District Electric
Utility System
1.1-2321 ~ 1 2331.1-2341.1-235 „,
1.1-2361.1-2371.1-238
1.1-13 M-S-R Member Loads and ResourcesModesto Irrigation District Electric
Utility Company
City of Santa Clara Electric UtilityCompany
City of Redding Electric UtilityCompany
1.1-240
1.1-241
1.1-242
1.3-1 Margin Comparison Between ParticipantsReserve Margin With and WithoutPVNGS-1,2S3 Delayed
1. 3-4
1.3-2 1981 Reverse Margin Due to Delay of PVNGS 1.3-14
1.3-3 Effect of Delay on Participant's SystemReliability, Arizona Public ServiceReliability Index (One Day In-Years)
1.2-24
1.3-4 Effect of Delay on Participant s OilConsumption, Arizona Public Service
1.3-29
1.3-5 Effect of Delay on Participant's Gas
Consumption, Arizona Public Service1.3-36
December 1981 1-ivA Supplement 4
PVNGS ER-OL1
Tables (cont)
Pacae
1.3-6 Effect of Delay on Participant's CoalConsumption, Arizona Public Service
1.3-43
1.3-7 Effect of Delay on Participant's UraniumFuel Consumption, Arizona Public Service
1.3-50
1.3-8 1981 Production Costs Due to Delay of PVNGS 1.3-57
1.3-9 Average System Data
1.3-10 SCPPA Members Energy Mix
1.3-68
1. 3-74
1.3-11 M-S-R Members Energy Mix 1.
3»74'upplement
4 1-ivB December 1981
PVNGS ER-OL
S ~
t'a~'
, FIGURES
PVNGS Units 1,2 Participants 1987-88 CoincidentJC
Load Duration urveArizona Public Service 1987-88 Coincident Load
Duration CurveEl Paso Electric. 1987-88 Coincident Load~
4
Duration Curve Il
Los Angeles Department of Water and Power 1987-88Coincident Load Duration Curve
Public Service Company of New Mexico 1987-88 'Coincident'Load Duration Curve
Salt River Project 1987-88 Coincident Load DurationCurve
Southern California Edison 1987-88 Coincident Load
Duration CurveGeographical Boundaries of WSCC Subareas
S
S
PVNGS ER-OL
1. PURPOSE OF THE PROPOSED FACILITYAND ASSOCIATED TRANSMISSION
Information presented in ER-CP Chapter 1 and the FES has been
updated by the use of more current participant load forecasts.The information presented in sections 1.1 and 1.3 reflects par-ticipant forecasts made in late 1978 and early 1979. Subse-
quent to these forecasts, the PVNGS Unit 1 commercial operationdate was delayed one year from May 1982 to May 1983 and licens-ing activities on PVNGS Units 4 and 5 were suspended. Both ofthese changes reduce the available resources and reserve marginsfor the participants'ystem beyond those presented in sec-tion 1.1, making the need for PVNGS even more acute. Informa-tion presented in section 1.3 reflects the new commercialoperation date of PVNGS Unit 1.
1.1 SYSTEM DEMAND AND RELIABILITY
The areas served by the participants have experienced and con-
tinue to experience growth in both peak demand and energyrequirements. The average annual growth rate for the compositearea for the years 1968 to 1978 was approximately 5.6% for peak
demand and 4.5% for energy requirements (refer to table l.l-l).The forecasted annual growth rate for the years 1978 to 1988 isapproximately 3.8% for peak demand and 4.3% for energyrequirements.
The total 'forecasted growth .in combined system annual peak
demand from 1980 to 1986 is 6567 megawatts. The forecastedgrowth in annual energy requirements for the same time periodis 34,868 GWh. Thus, it is clear that the total nominal net
'capacity of 3810 megawatts from PVNGS-1,263 constitutes onlya part of the new resources needed to meet the load require-ments forecast in this time frame, and to provide the reserves
requisite for reliable service. Likewise, PVNGS will supply
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
approximately 25,600 GWh annually, which is only a portion ofthe total additional energy requirements in this time frame(refer to table S.l-l).Data presented to support the participants'orecasted growthis given for each participant, for the participants'ombinedsystem, and, where applicable, for the Western Systems Coor-dinating Council (WSCC). The WSCC is a regional reliabilitycouncil to which all of the participants subscribe.
In addition to subscribing to the WSCC, the PVNGS participantsare committed to the following agreements: Arizona Public Ser-vice Company (APS), the Los Angeles Department of Water and
Power (LADWP), El Paso Electric Company (EPE), Public ServiceCompany of New Mexico (PNM), Southern California Edison Company
(SCE) and Salt River Project Agricultural Improvement and Power
District (SRP) are committed to the Principles of InterconnectedOperation for Four Corners Interconnection Agreement. APS,
LADWP and SRP are parties to the Navajo Participation Agreementand the. Navajo Operation Agreement. SCE is a party to the San
Onofre No. 1 Ownership Agreement and Operation Agreement.IADWP, SCE and SRP are parties to the Mohave Project OperationAgreement, the Mohave Plant Site Convenience and Co-Tenancy
Agreement, the Eldorado System Operating Agreement, and theEldorado System Convenience and Co-Tenancy Agreement. SCE isa member of the California Power Pool. EPE and PNM are members
of the New Mexico Power Pool. These agreements serve tostrengthen the coordination among the PVNGS participants.
1.1.1 LOAD CHARACTERISTICS~1Information on annual peak demand, energy requirements, power
purchases, and sales for all PVNGS participants, and for indi-vidual participant's systems, is presented in table 1.1-1.
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
This table and all other tables and figures in this section forPVNGS present the cumulative data as well as individual datafor all participants. Where appropriate (that is, sales andpurchases between participants), the cumulative data have beenadjusted to prevent duplication.Information in table 1.1-1 shows that the participants had acombined demand compound growth rate of about 5.6% per annumfrom 1968 to 1978, and that they anticipate a combined growth .
rate of 3.8% per annum between 1978 and 1988. Between 1988 and1992, it is expected that the combined system demand will begrowing at an average rate of more than 1170 megawatts per year.All participants are summer peaking utilities. The electricdemand and energy growth rate in the areas served by the parti-cipants can be attributed to a rate of population expansiongreater than the national average, increased use of air condi-tioning, and a general trend toward higher per capita use ofelectricity.Most of the participants do not have and do not anticipate hav-.ing any interruptible- load. SCE includes interruptible loadsin its load management reductions, which reduce the peak fore-cast used in SCE planning studies.
'Monthly demand and energy requirements for 1981 through 1988for the combined systems of all participants as well as for anindividual participant s systems, are presented in table 1.1-2.Figures 1.1-1 through 1.1-7 are projected 1987 to 1988 loadduration curves for the participants'ombined system as wellas for each participant. The anticipated 1987 to 1988 loadfactor for the combined system is 60.3%, with individual loadfactors ranging from 57.4 to 70.2%. Analysis of the load dura-tion curves indicates that nuclear energy production can dis-place higher priced coal resources, and that the full potentialproduction "of the nuclear units can be used in the combinedsystems of all participants. The displacement of coal resources
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
will in turn displace the need for the addition of oil-burningunits, such as combined cycle and combustion turbine units.Thus, the use of domestic coal and nuclear resources will, eachin turn, result in the area being less dependent on oil, an
expensive and uncertain future energy resource.
All of the participants are members of the WSCC. Part of theirmembership obligation is to periodically report certain of theabove load-resource data to the WSCC for use in various reportsand studies. These data are compiled and published annually inthe WSCC Summary of Estimated Loads and Resources. The loadsand resources for the PVNGS Arizona and New Mexico participantsare included in the total for Region III, Arizona-New MexicoPower Area; the PVNGS Southern California participants are
- included in the totals for Region IV, Southern California-NevadaPower Pool. Figure 1.1-8 shows the geographic boundaries ofthese areas.
The total'nnual peak demand and energy requirements for thesetwo areas, as extracted from WSCC reports, are listed intable 1.1-3. These data, compiled from the 1972-1987 reportperiod, pertain to all utilities in the geographical area andtherefore are larger in magnitude than the data compiled solelyfor the PVNGS participants. Table 1.1-4 is a list of themonthly demand and energy requirements for the areas asextracted from the WSCC report for 1982 through 1987.
The loads and resources of SCPPA members except Los AngelesDepartment of Water and Power are presented in table 1.1-12.Comparabl'e data for LADWP is presented in table 1.1-1,sheet 3 of 7.,The loads and resources of M-S-R members are presented intable 1.1-13.
Supplement 4 1.1-4 December 1981
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
1.1.1.2 Demand Pro'ections
The need for PVNGS and;other'additional generating capacityrests on the validity of the forecasts made by the participantsfor their respective loads through 1990. To establish thisvalidity the following topics are addressed:
~ Methodology of forecasting~ Histori'cal accuracy of forecasting~ Impact of energy conservation measures
.
December 1981 1.1-4A Suaplement 4
PVNGS ER-OL
'C
SYSTEM DEMAND AND RELIABILITY
This page intentionally blank
Supplement 3 1.1-4B July 1981
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
1.1.1.2.1 Methodology of Forecasting
Accurate load forecasting is vital to the proper planning ofgeneration and transmission facilities required to ensure eco-nomical and reliable service. Accurate forecasting is needed
not only to'stablish the timing of additional capacity, but todetermine the most economic mix of base, intermediate, and peak-ing types of generating capacity. Moreover, the forecastingperiod must reach far enough into the future to permit the con-sideration of all types of capacity, including those with thelongest lead time from commitment to commercial service.
All of the participants have developed methods of forecastingwhich are designed to permit orderly planning and produce reli-
I
able and economical electric service. Each participant preparesits annual forecasts independently for its own system, usingtechniques and exercising judgment suitable 'to its operationsand circumstances. Details of each participant's forecastingmethodology are included in appendices 1B through 1G.
1.1.1.2.2 Historical Accuracy of Forecasts
Tables 1.1-5 and 1.1-6 support the validity of the forecasts ofannual peak demands and energy requirements from 1983 to 1986,
when PVNGS will be placed in service. The data sources foreach table are the reports made by the WSCC for Region III(principally Arizona and New Mexico) and Region IV (principallySouthern California and Nevada) commencing in 1973. Informationin table 1.1-5 illustrates the accuracy of the short-term(1-year) forecasts by comparing the actual peak demands and
annual energy requirements experienced by all participants from
1973 through 1978 with the reported forecasts for each of those
years made during the preceding year. The table shows that, inall years but one, the forecasts overestimated actual experi-ence. The mean deviation of the forecasts from actual experi-ence is about 4.3% for peak demands and about 5.9% for energy
requirements.
1.1-5
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
The effects of consumer conservation with reductions in peakloads and energy requirements first became noticeable in 1974
and 1975, following the Organization of Petroleum ExportingCountries, (OPEC) oil embargo. As these effects are not pre-dicted in the forecasts prior to 1974 and 1975, the forecastspredicted peak demands and eriergy requirements substantiallyhigher than were experienced. Forecasts made after the 1974-1975 period include the effects of conservation and are there-fore substantially more accurate. ,If only the years 1976
through 1978 are considered, the mean deviations for peakdemand and energy requirements in table 1.1-5 are 2.0% and 2.4%
respectively.Table 1.1-'6 is a comparison of the actual 1978 peak demand and
energy requirement experienced in WSCC Region III and Region IVwith the 1978 forecasts made in each of the preceding 6 years.As can be seen in table 1.1-5, the short-term forecast made in1972 for 1973, was quite accurate. However, because of theabsence of any allowance for conservation, the long-term fore-casts such as 1972 for 1978, and 1973 for 1978, as seen intable 1.1-6 were quite high. The later, short-term forecastssuch as 1976 for 1978 and 1977 for 1978, again became more
accurate. Based on the data presented in tables 1.1-5 and
1.1-6, it is apparent that forecasts made in 1976 and laterincorporate the effects of conservation and exhibit a higherdegree of accuracy.
1.1.1.2.3 Impact of Conservation Measures on Forecasts
1.1.1.2.3.1 Effects of Conservation on Forecasts. Oil short-ages appeared after the imposition of the OPEC oil embargo inthe latter part of 1973. At that time, most of the partici-pants observed that, peak demands and energy consumption were
reduced below anticipated levels. System growth rate laggedfor a short period and then exhibited a partial recovery. This
1.1-6
PVNGS ER-OL
SYSTEM DEMAND AND REI IABILITY
can be seen from comparisons of monthly values to the precedingyear for 1972 through 1978 (refer to table 1.1-7).
By observing annual growth rates of combined system annual peakdemand it can be seen that the compound annual peak demand
growth was 8.3% from 1968 through 1972 (refer to table 1.1-1).A reduced annual growth rate of 2.1% followed during the next3 years (1973 through 1975). The growth rate recovered during1976 through 1978 when the compound annual combined system peakdemand growth rate was 5.4%. The load forecast in table 1.1-1relies on the assumption that consumers will continue to takeenergy conservation measures. The forecast also assumes thatmore efficient, electrical appliances will be available, some-
what, counterbalancing the trend of steadily rising per capitausage. The compound forecasted combined system peak demand
growth rate over the next 10 years (1978 to 1988) is 3.8%.
The reduced growth rate from 1973 through 1975 was caused bythe combination of the OPEC oil embargo, economic recession,consumer conservation education, and price elasticity. The
continued lower growth rates observed in 1975 and 1976, and
forecast for the future, are attributed to continuing consumer
conservation. The continued consumer conservation results fromthe utilities'onsumer education and conservation programs,and continuing price escalation.
I1.1.1.2.3.2 Partici ants'ner Conservation Pro rams. Each
of the participants offers a public communications and educationprogram designed to encourage prudent use of electric energy byits customers. These programs include newspaper and radioadvertisements, mailers in monthly billings, speakers, and
company programs to inspect customer premises and make recom-
mendations on energy-saving modifications and equipment. The
scope and nature of the programs of the participants. were
reported to the Federal Power Commission (FPC) in FPC Dkt.
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
No. RM-74-7, pursuant to FPC Order Nos. 496, 497, 497A, and,.497B issued November 29, 1973, December 7, 1973, April 5, 1974,and August 13, 1975, respectively.The scope and nature of the reported programs are set forth in .
appendices 1H through 1M. The programs urge customers to adoptpractices that would reduce peak demands and conserve energy.Such practices include the regulation of thermostatic controls,the use of insulation to reduce heat loss, the use of drapes,blinds, and other means typically found or available for use inhomes to reduce space heating energy requirements. Alsoincluded are methods for securing the most efficient use ofappliances such as electric dishwashers and washing machines.
Also, in new construction that uses electric space heating,incentives are used to assure the satisfaction of minimum stan-dards for installation of equipment, insulation, and othermeans of restricting heat losses. Active campaigns are cur-rently maintained to promote use of more efficient space heat-ing and cooling devices, such as the heat pump. Advertisingand incentive programs, such as wiring allowances and supportof dealer promotions, formerly used by many utilities to pro-mote the use of electric energy, have been discontinued com-
pletely or have been curtailed to selective applications.
Promotional rates for certain kinds of electric uses that were
designed to improve system load factors, such as electric hot,
water heating, have been discontinued. Those that have notbeen discontinued are undergoing regulatory proceedings toauthorize discontinuance.
Regulatory commissions in both Arizona and California are con-sidering changes in rate structure, such as demand rates and
time-of-day rates. While it is hoped these rates will reduce
peak demand, it is not expected that they will affect totalenergy requirements or reduce the need for base-load generation
1.1-8
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
units such as PVNGS. The par'ticipants will continue seekingmeans to promote effectively prudent electric energy managementpractices.
1.1.1.3 Power Exchan es
Past and expecte'd future net power sales and purchases outsidethe participants'ombined system, which are applicable at thetime of annual peak demand, are presented in table 1.1-1. Bothfirm sales and purchases and nonfirm sales and purchases aretabulated; they contribute respectively to load and generationtotals. Firm purchases are not included in the resourcesrequiring reserves as the reserves are provided by the seller.Reserve for firm sales is provided on the participants'om-bined system.
On a load'and resource tabulation, firm sales appear as loadadditions. Firm purchases appear as reductions in load.
A nonfirm sale is a sale of power if that power is available.The delivery of power is contingent on the operation of thestipulated source. The buyer must provide the reserves toback up a nonfirm purchase.
On a load and resource tabulation nonfirm sales and purchasesare treated as resources. A nonfirm sale of power reduces thecapacity of the machine the sale is made from and the resourcestotal is reduced by the amount of the sale. A nonfirm purchaseis added to the resources total.Table 1.1-1, Loads and Resources Summary, tabulates firm sales,firm purchases, nonfirm sales and nonfirm purchases. Table1.1-2, Load and Energy Requirements by Month, tabulates loadsbut not resources. It includes firm sales and firm purchases.Table 1.1-3 is a loads and resources summary. It includesfirm sales, firm purchases, nonfirm sales and nonfirm purchases.Table 1.1-4 is a monthly loads summary and includes firm sales
March 1981 1.1-9 Supplement 2
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
and firm purchases. Table 1.'1-8, Capability of Resources,tabulates resources but not loads. It includes nonfirm salesand nonfirm purchases.
1.1.2 SYSTEM CAPACITY
System capabilities for each of the participants at the time ofthe'nnual peak demand for 1968 through 1988 are presented intable 1.1-8 along with a combined resources summary for allparticipants. Representative capacity factors are providedin table 1.1-8A. These resource schedules are the result ofgeneration planning that makes use of the load forecastingdiscussed in section 1.1.1.2.Each participant is responsible for determining its own criteriafor bulk generation planning, including the methodology forlpad forecasting. The Reliability Council of the WSCC recentlyissued guidelines for the measurement of the adequacy of powersupply, including as an alternative a reliability test thatuses a loss-of-load probability (LOLP) criterion of one day ofoutage in 10 years.
Table 1.1-9 contains information showing the existing genera-tion capability as of January 1, 1978, for the Arizona-NewMexico Power Area and the Southern California-Nevada Power Area,respectively, as defined in WSCC. Table 1.1-10 is a summary ofgeneration additions for these two power areas. Table 1.1-11provides a comparison of participants generating capacity, load,and energy generation for the period 1981-1990.
.Supplement 3 1.1-9A July 1981
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY )2
This page intentionally blank.
March 1981 1.1-9B Supplement 2 l2
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
1.1.3 RESERVE MARGINS
The participants do not participate jointly in any singleregional power pool. Each participant is responsible forestablishing and maintaining its own reserve. Reserve criteriavary with the participant. Each participant's reserve require-ments are listed below in outline form.
A. Arizona Public Service Company: The APS generationreserve reguirements are based on an LOLP criterionapplied to the proposed Cactus Pool. The proposedpool includes Arizona Electric Power Cooperative, APS,
EPE, Plains Electric Generation and Transmission Coop-
erative, Public Service Company of New Mexico, and SaltRiver Project. Although formal operating agreementshave not been established for this pool, the pool con-cept has been used in planning studies to establish APS
installed reserve requirements. The LOLP criterion isexpressed in terms of the expected number of times in a
specified period that the pool generating capacity fails'o meet load.
The criterion used by APS (in conjunction with the APS
load forecast on May 31, 1978) is that the pool reservesshall be 16% of pool load from 1979 through 1981 and
sufficient to yield an expected failure to meet poolload of no more than one occurrence in 3 years beyond1981. This is sometimes referred to as a 1/3 LOLP
index. A computer simulation that represents bothforced and maintenance outages is used to compute theprobability of failure to meet load on a daily basis,with the daily probabilities added to yield an annualindex. Allocation of the pool reserves among indivi-dual utilities is in proportion to the sum of theirpeak load, plus twice their largest hazard.
1.1-10
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
El Paso Electric Company: El Paso Electric Company'sminimum installed reserve criterion is the WSCC guideof "single largest hazard" plus 5% of the load. El PasoElectric as a separate entity does not use probabilisticmethods. However, a new pooling arrangement. currentlyunder negotiation among the Arizona-New Mexico utilitiesand El Paso Electric (Cactus Power Pool) will use thismethodology.
Los Angeles Department of Water and Power:, The LADWP
uses an LOLP computer program developed inhouse todetermine minimum system reserve requirements for plan-ning purposes.'he LOLP is defined as a measure of theexpected risk that the available generating resourceswill not be able to meet the system load. It isexpressed in terms of number of days during which lossof load may be expected to occur in a given number ofyears. The criterion used by LADWP is that the proba-bility of losing load because of a lack of availablegenerating capacity should not, exceed 1 day in 10 years.
Public Service Company of New Mexico:'ublic ServiceCompany of New Mexico's minimum installed reserve cri-terion is 20% of peak load or the "single largesthazard", whichever is greater.
Southern California Edison Company: SCE's installedcapacity reserve criteria requires that sufficientinstalled capacity be provided to meet or exceed each
of the following minimum planned criteria:1. Installed capacity margin of 18%, plus or minus 2%
of the annual estimated peak demand before sched-
uled maintenance.
1.1-11
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
2.
3.
Installed capacity margin (after deducting sched-uled maintenance) sufficient to allow the loss ofthe larger of either of the two largest risks(generating unit or interconnection); or 7% ofsystem demand and the largest risk.A reliability criterion based on probabi:lity calcu-lations; the criterion .requires that the resourceprogram result in a raliability index of 0.95 when
considering all hourly loads in a year, plannedgeneration maintenance and random forced outages,and assumed availability of emergency capacitythrough SCE's interconnections. A reliabilityindex of 0.95 indicates that interconnection assis-tance in excess of that assumed normally availablewill be required for approximately 1 hour every20 years.
F. Salt River-Project: Salt River Project's requiredreserve margin criterion is 16% of peak load through1982 and 20 percent of peak load beginning in 1983.
I
1.1.4 EXTERNAL SUPPORTING STUDIES
The Principles of Interconnected Operation for the Four CornersInterconnection Agreement have been incorporated in participa-tion agreements involving APS, SRP, PNM, EPE, LADWP, and SCE.
The Principles of Interconnected Operation provide, in part, as
follows:
The Participants recognize that it is prudent practicethat each provide a Forecast, Capacity Resources Marginat least equal to 15% of the Estimated Peak Demand foreach month of each calendar year, but the InterconnectionAgreement shall not obligate any Participant to do so.
1.1-12
PVNGS ER-OL
SYSTEM DEMAND AND RELIABILITY
The foregoing provision is a statement of the minimum acceptableplanning objective. It is not obligatory in the sense that noparticipant can be forced to add additional capacity; however,failure to comply can affect rights to, and costs of, emergencyservice.
This page intentionally blank
1.1-14
PVNGS ER-OL
NEED FOR POWER
ARIZONA PUBLIC SERVICE COMPANY
Year 1981
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Jan Feb Mar
1628 1587 1560
2290
229
2230
223
2190
219.
1857 1810 1779
(4) (3) (3)(126) (123) (121)(130) (126) (124)
1727 1684 1655
Apr
1778
2510
251
2029
(4)(138)(142)
1887
May JUA
3100
310
2512
(5)(170)(175)
2337
3630
369
2996
(6)(203)(209)
2787
2202 262
Aug Sep
2722
3830
, 383
63105
(6)(211)(217)
2736 2654
3850
385
3730
3 73
3121 3027
(6) (6)(212) (205)(218) (211)
888 2903 2816
Oct
2025
2850
385
2310
(4)(158)(162)
2148
Nov Dec
1655 1669
2330
233
2350
235
1888 1904
(4) (4)(128) (129)(132) (133)
1756 1771
TotalEnergy
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 9 of 56)ARIZONA PUBLIC SERVICE
Page 1 of 8
Company monthly energy
Firm energy sales outsidePVNGS 1,283
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
972 885 942
196 178 190
(2) (2) (2)
1166 X061 1130
936
188
(2)
1122
1079
218
(3)
1294
1248
252
(3)
I,'497
l439 1474 1196
290 298 242
(4) (4) (3)
1725 1768 1435
992
199
(2)
1189
880 989 13032
177 199
(2) (2)
2629
(32)I-
1055 1186 15629
1.1-45/46 Blank
fi
E
PVNGS ER-OL
ARIZONA PUBLIC SERVICE COMPANY
Year 1982
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,2E3
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
Jan Feb
1710 1667
2380
238
2320
232
1034 941
204 186
(2) (2)
1236 1125
1948 1899
(4) (3)(132) (129)(136) (132)
1812 1767
Mar
1638
2280
228
1866
(3)(127)(130)
1736
1002
198
(2)
1198
Apr May
1868 2314
2600
260
3220
322
995 1148
197 227
(2) (3)
1190 1372
2128 2636
(4) (5)(144) (179)(148) (184)
1980 2452
nfl
2759
3s40
3s4
3>43
I(I)
(213)(219)
2924
1328
~261
(3)
1587
Jul Aug
2860 2874
3980
398
4000
400
3258 3274
(6)(221)(227)
3031
(6)(222)(228)
3046
(4) (4)
1829 1874
1530 1568
303 310
Sep
2788
3880
388
3176
(6)(215)(221)
2955
1273
251
(3)
1521
Oct Nov Dec
2127 1739 1753
2960
296
2420
242
2440
244
2423 1981 1997
(4) (4) (4)(165) (134) (135)(169) (138) (139)
2254 1843 1858
1261 1118 1258
1055 936 1052
208 184 208
(2) (2) (2)
Total.Energy
13863
2738
(32)
16569
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 10 of 56)ARIZONA PUBLIC SERVICE
Page 2 of 8
1.1-47/48 Blank
PVNGS ER-OL
ARIZONA PUBLIC SERVICE COMPANY
Year 1983
1.1.1 Load characteristics, demand (MW)
.Company peak demand
Jan
1815
Feb Mar Apr
1770 1739 1983
May
2456 2929 3036
I
Jun 'ul Aug
3051
Sep Oct Nov
2959 2258 1846
Dec
1861
TotalEner9Y
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet ll of 56)
ARIZONA PUBLIC SERVICE
Page 3 of 8
-Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
2450
245
2380
238
2340
234
2670
267
3310
331
395i 0
395
4090
409—
4110
411
3990
399
3040
304
2490
249
2510
251
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,283Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
2060
(4)(137)(141)
1919
2008 1973 2250
(3) (3) (4)(134) (132) (150)(137) (135) (154)
1871 1838 2096
2787
(5)(186)(191)
2596
3324
(6)(222)(228)
3096
3445
(6)(230)(236)
3209
3462
(6)(231)(237)
3225
(6) (4)(224) (171)(230) (175)
3128 2387
(4)(140)(144)
1951
3358 2562 2095 2112
(4)(141)(145)
1967
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
1110
207
(2)
1315
1010 1076 1068
189 200 199
(2) (2) (2)
1197 .1274 1265
1232
230
(3)
1459
1426 1643
265 306
(3) (4)
1688 1945
1683
314
(4)
1993
1366 1132 1004
255 211 187
(3) (2) (2)
1618 1341 1189
1129
211
(2)
1338
14881
2773
(32)
17622,'.1-49/50
Blank
I
I
t
n
i
I
PVNGS ER-OL
NEED FOR POWER
ARIZONA PUBLIC SERVICE COMPANY
Year 1984
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,283Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
Jan
1-913
2520
252
2165
(4)(143)(147)
2018
1177
214
(2)
1389
Feb Mar Apr
1865 1833 2090
2450
245
2410
241
2750
275
2110 2074 2365
1071 1140 1132
195 208 207
(2) (2) (2)
1264 1346 1337
(3) (3) (4)(140) (138) (157)(143) (141) (161)
1967 1933 2204
May
2588
3410
341
2929
(5)(194)(199)
2730
1306
239
(3)
1542
JuIl
3086
4060
406
3492
(6)(231)(23,7)
3255
1511)
I
276I
(3)
1784
Jul
3lgg
4210
42l
3620
(6)(240)(246)
3374
1741
319
(4)
2056
Aug
3215
4230
423
3638
(6)(241)(247)
3391
1784
326
(4)
2106
Sep Oct Nov
3119. 2379 1945
4100
410
3130
313
2560
256
3529 2692 2201
1448 1200 1065
264 219 194
(3) (2) (2)
1709 1417 1257
(6) (4) (4)(234) (179) (145)(240) (183) (149)
3289 2509 2052
Dec
1961
258~ 0258
2219
(4)(146)(150)
2069
1197
218
(2)
1413
TotalEnergy
15772
2879
(32)
18619
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 12 of 56)ARIZONA PUBLIC SERVICE
Page 4 of 8
1.1-51/52 Blank
j
PVNGS ER-OL
ARIZONA PUBLIC SERVICE COMPANY
Year 1985
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1, 263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Jan Feb
2013 1963
2620
262
2540
254
2275 2217
(4) (3)(149) (146)(153) (149)
2122 2068
Mar
1929
2500
250
2179
(3)(143)(146)
2033
Apr May
2200 2724
2850
285
3540
354
2485 3078
(4) (5)(163) (202)(167) (207)
2318 2871
3249
421I
0
421
3670
j(6)(241)(247)
3423
Jul Aug
3367 3384
4370
437
3804
4390
439
3823
(6) (6)(250) (251)(256) (257)
3548 3566
Sep
3282
4260
426
3708
(6)(243)(249)
3459
Oct
2504
3250
325
2829
(4)(186)(190)
2639
Nov Dec
2047 2064
2660
266
2680
268
2313 2332
(4) (4)(152) (153)(156) (157)
2157 2175
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 13 of 56)
ARIZONA PUBLIC SERVICE
page 5 of 8
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purcha'ses outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
1247 1135
223 203
(2) (2)
1468 1336
1209
216
(2)
1423
1201 1384 1602
214 249 286
(2) (3) '(3)I
1413 1630 1885
1846 1891
331 339
(4) (4)
2173 2226
1535
275
(3)
1807
1272
228
(2)
1498
1129 1269 16721
201 227 2991
(2) (2) (32)
1328 1494 19680
1.1=53/54 Blank
0
s
ARIZONA PUBLIC SERVICE COMPANY
Year 1986
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sa1es outside PVNGS 1,283Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load character'sties, energy (GWh)
Jan
2110
2710
271
2381
(4)(155)(159)
2222
Feb
2057
2640
264
2321
(3)(152)(155)
2166
Mar Apr May
2022 2306 2855
2590
259
2950
295
3670
367
2281 2601 3222
(3) (4) (5)(150) (170) (211)(153) (174) (216)
2128 2427 3006
JuIlI
3405
437I0
437
3842
(6)(251)(257)
3585
3529
4530
453
;3982
(6)(261)(267)
3715
Aug
3547
4550
455
4002
(6)(262)(268)
.3734
Sep Oct, Nov
3441 2625 2146
4410
441
3360
336
2750
275
3882 2961 2421
(6) (4) (4)(254) (194) (158)(260) (198) (162)
3622 2763 2259
Dec
2164
2770
277
2441
(4)(159)(162)
2278
TotalEnergy
PVNGS ER-OL
}>
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 14 of 56)ARIZONA PUBLIC SERVICE
Page 6 of 8
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
1310
232
(2)
1193
211
(2)
1270 1261 1454
224 223 258
(2) (2) (3)
1683
297
, 1939
344
(3) (4)
1986
352
(4)
1612 1337 1186
286 236 209
(3) (2) (2)
1333
236
(2)
17564
3109
(32)
Monthly energy requirement(CME+FES-FEP)
1540 1402 1492 1482 1709 1977 2279 2334 1895 1571 1393 1567 20641
1.1-55/56 Blank
C y ~
PVNGS ER-OL
ARIZONA PUBLIC SERVICE COMPANY
Year 1987
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2F3Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Jan
2218
2810
281
2499
(4)(162)(166)
2333
Feb Mar Apr
2162 2125 2423
2740
274
2690
269
3070
307
2436 2394 2730
(3) (3) (4)(159) (156) (177)(162) (159) (181)
2274 2235 2549
May
3001
3800
380
3381
(5)(220)(225)
3156
Jun
3579
4530
453
4032
(6)(262)(268)
3764
l3709
l4op
47p
j4179
(6)(272)(278)
3901t
Aug Sep
3728 36'6
4720
472
4580
458
4200 4074
(6) (6)(273) (265)(279) (271)
3921 3803
Oct
2759
3490
349
3108
(4)(202)(206)
2902
Nov Dec
2255 2274
2860
286
2880
288
2541 2562
(4) (4)(165) (166)(169) (170)
2372 2392
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 15 of 56)
ARIZONA PUBLIC SERVICE
Page 7 of 8
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
1379
242
(2)
1255 1336 1327
220 235 233
(2) (2) (2)
1531
269
(3)
1771 i2041 2091 1697
311
(3) (4) (4) (3)
358 367 298
1407
246
(2)
1248 1403 18485
219 246 3244
(2) (2) (32)
Monthly energy requirement(CME+FES-FEP)
1619 1473 1569 1558 " 1797 2079 2395 2454 1992 1651 1465 1647 216'97
1.1-57/58 Blank
l,
PVNGS ER-OL
ARIZONA PUBLIC SERVICE COMPANY
Year 1988
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1 .1.1 Load characteristics, energy (GWh)
Jan
2323
2910
291
2614
(4)(168)(172)
2442
2265
2840
284
2549
(3)(166)(169)
2380
Mar Apr May
2226 2538 3144
2790
279
3180
318
3930
393
2505 2856 3537
(3) (4) (5)(163) (184) (228)(166) (188) (233)
2339 2668 3304
urn
'(749
14„
14„
!
4Z18
(6)(272)(278)
3940 (
Jul
3885
4870
487
4372
(6)(283)(289)
4083
Aug Sep
3905 3788
4890
489
4740
474
4394 4262
(6) (6)(284) (275)(290) (281)
4104 3981
Oct
2890
3620
362
3252
(4)(211)(215)
3037
Nov Dec
2363 2382
2950
295
2980
298
2483 2503
2658 2680
(4) (4)(171) (173)(175) (177)
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 16 of 56)
ARIZONA PUBLIC SERVICE
Page 8 of 8
Company monthly energy
Firm. energy sales ou ts idePVNGS 1, 263
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
1454
252
(2)
1704
1323
230
(2)
1551
1409 1399 1614
244 243 280
(2) (2) (3)
1651 1640 1891
1867
324tt
! (3)
2188
2152
373
(4)
2521
2204 1789
383 310
(4) (3)
2583 2096
1483
257
(2)
1738
1316 1479 19490
227 256 3379
(2) (2) (32)
1541 1733 22837
1.1-59/60 Blank
l I I
l
PVNGS ER-OL
LOS ANGELES DEPARTMENT OF WATER AND POWER (Sheet 1 of 8)NEED FOR POWER
Table 1.1-2Year 1981
1.1.1 Load characteristics, demand (MW)
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov DecTotalEnergy LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 17 of 56)LOS ANGELES DEPARTMENT
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS lg263
— Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
3206 3098 3067
000
3206 3098 3067
3206 3098 3067
1707 1535 1695
61 61 30
0
1768 1596 1725
3055
3055
3055
1630
27
1657
3336
1702
*'
00
i3770
[1747
63 59
1765
01
, 1806
3336 3650
1200
120
3336,3770
4100 4259
1200
120
1200
120
4220 4379
4220 4379
1922 1975
65 65
1987 2040
4003
4003
4003
1806
61
1867
3530 3282 3369
3530 3282 3369
000
3530 3282 3369
1793 1693 1762
62 69 69
1855 1762 1831
20967
692
21659
OF WATER AND POWER
Page 1 of 8
1.1-61/62 Blank
4 ~W
PVNGS ER-OL
LOS ANGELES DEPARTMENT OF WATER AND POWER (Sheet 2 of 8)NEED FOR POWER
Year 1982
1.1.1 Load characteristics, demand (MW)
Jan Feb Mar Apr May jJun Ju 3. Aug Sep Oct, Nov Dec
TotalEnergy
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 18 of 56)
LOS ANGELES DEPARTMENTCompany peak demand
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,2&3Total firm purchases (TFP)
3269 3160 3129
3269 3160 3129
3117
3117
3414
3414
~~3740
1200
i 120
;3860t
000
4194
1200
120
4314
4366 4095 3617
1200
120
4486 4095 3617
000
3348
3348
3435
3435
OF WATER AND POWER
Page 2 of 8
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,-263
Monthly energy requirement(CME+FES-FEP)
3269 3160 3129
1748 1572 1737
68 68 63
1816 1640 1800
3117
1671
60
1731
1745 1793
58 54
1803 1847
3414 3860 4314
1975
56
2031
4486 4095 3617
2030 1854 1837
62 69 67
2092 1923 1904
3348
1733
72
1805
3435
1804 21499
67 764
0
1871 22263
1.1-63/64 Blank
l
PVNGS ER-OL
OS ANGELES DEPARTMENT OF WATER AND POWER (Sheet 3 of 8)
NEED FOR POWER
Table 1.1-2
Year 1983
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 1,2&3Total firm purchases (TFP)
Jan Feb
3343 3234
3343 3234
Mar
3203
3203
Apr May
3191 3506
3191 3506
3S47
00
3847
000
Jul Aug
4305 4488
4305 4488
Sep
4203
4203
Oct Nov Dec
3720 3426 3513
3720 3426 3513
TotalEnergy LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 through 1988 (Sheet 19 of 56)
LOS ANGELES DEPARTMENT
OF WATER AND POWER
Page 3 of 8
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
3343 3234 3203 3191 3506 3847 4305 4488 4203 3720 3426 3513
Company monthly energy
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
1797 1616
52 51
1849 1667
1786
1786
1719 1797 1849 2039 2095
1719 1797 1849 2039 2095
1910
1910
1890 1782 1855
1890 1782 1855
22134
103
22237
1.1-65/66 Blank
!
(
I
!
1
a
PVNGS ER-OL
LOS ANGELES DEPARTMENT OF WATER AND POWER (Sheet 4 of 8)NEED FOR POWER
Year 1984
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1.263Firm sales within PVNGS 1<263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Jan Feb Mar
3426 3315 3286
3426 3315 3286
3426 3315 3286
Apr
3272
3272
3272
May Jun
3609!
396~
!0
'0
!
3609 3966
3609 3966
! 4429
!
\
44291
', 4429
Aug
4618
4618
4618
Sep Oct Nov
4324 3834 3512
4324 3834 3512
000
4324 3834 3512
Dec
3599
3599
3599
TotalEnergy
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 through 1988 (Sheet 20 of 56)LOS ANGELES DEPARTMENT
OF WATER AND POWER
Page 4 of 8
Company monthly energy
Firm energy sales outsidePVNGS 1 263
Firm energy purchases outsidePVNGS 1,263
1851 1725 1841 1772 1855 1910
!0I
!0
;2110 2168 1974 1948 1835 1911 22902
Monthly energy requirement(CME+FES-FEP)
1851 1725 1841 1772 1855 1910 '2110 2168 1974 1948 1835 1911 22902
1. 1-67/68 Blank
~a yw
I
PVNGS ER-OL
LOS ANGELES DEPARTMENT OF WATER AND POWER (Sheet 5 of 8)NEED FOR POWER
Year 1985
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,2&3Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1.,263Firm purchases within PVNGS 1.,-253Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,253
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
Jan
3528
3528
3528
1919
1919
Feb Mar Apr
3417 3388 3374
3417 3388 3374
000
3417 3388 3374
1728 1911 1839
0
1728 1911 1839
May
3737
3737
3737
1928
1928
4116
0,0
0
41a6
0I
0
0
4lil6 '
1988
0I
1988
Jul
4584
4584
4584
2200
2200
Aug
4772
4772
4772
2260
0
2260
Sep Oct Nov
4475 3978 3619
4475 3978 3619
4475 3978 3619
2053 2022 1903
0
2053 2022 1903
Dec
3707
000
3707
3707
1982
1982
TotalEnergy
23733
23 733
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 21 of 56)
LOS ANGELES DEPARTMENT
OF WATER AND POWER
Page 5 of 8
1.1-69/70 Blank
W 'W
PVNGS ER-OL
Year 1986 Jan Feb Mar
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
3627 3515 3487
LOS ANGELES DEPARTMENT OF WATER AND POWER (Sheet 6 of 8)
3471
000
May Jun Jul
3861 4261 4733
Aug
4923
Sep Oct Nov
4622 4117 3722
Dec
3811
TotalEnergy
/NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 22 of 56)LOS ANGELES DEPARTMENT
OF WATER AND POWER
Page 6 of 8
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1.2&3Firm purchases within PVNGS lI2&3Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
l.l.l Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1 2&3
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
3627 3515 3487
3627 3515 3487
1985 1788 1978
1985 1788 1978
3471
3471
1905
1905
3861 4261 4733
000
3861 4261 4733
1999 2064 2287
1999 2064 2287
4923
4923
2349
2349
4622 4117 3722
4622 4117 3722
2130 2094 1968
-0
2130 2094 1968
3811
000
3811
2051 24596
2051 24596
-~4
1.1-71/72 Blank
Jy
PVNGS ER-OL
LOS ANGELES DEPARTMENT OF WATER AND POWER (Sheet 7 of 8)NEED FOR POWER
Year 1987
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 3.,2&3Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Zan Feb Mar
3727 3614 3588
3727 3614 3588
3727 3614 3588
Apr
3571
3571
3571
May
3988
3988
3988
Jun
4409
i 000
4409I
, 0~ 04 0
44,09
Jul
4886
4886
4886
Aug Sep Oct
5077 4771 4259
5077 4771 4259
5077 4771 4259
Nov
3827
3827
3827
Dec
3917
3917
3917
Total,Energy
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 23 of 56)LOS ANGELES DEPARTMENT
OF WATER AND POWER
Page 7 of 8
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
2052 1849 2047
2052 1849 2047
1971
1971
2071
2071
2141
0
21'41
2377
2377
2441 2210 2167
2441 2210 2167
2035
2035
2121 25481I
0.i
0
2121 25481
1.1-73/74 Blank
PVNGS ER-OL
LOS ANGELES DEPARTMENT OF WATER AND POWER (Sheet 8 of 8)
NEED FOR POWER
Year 1988
1.1.1 Load characteristics, demand (MW)
Jan Feb Mar Apr May JuO IJul Aug Sep Oct Nov Dec
TotalEnergy
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 24 of 56)LOS ANGELES DEPARTMENT
Company peak demand
Firm sales outside PVNGS 1,2S3Fixm sales within PVNGS li2&3Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1.2&3Firm purchases within PVNGS 1'263Total firm purchases (TFP)
3827 3713 3688
3827 3713 3688
3670 4115 45
3670 4115 45
58 5039 5230
pl)
p)
58
pt0'
5039 5230
4920
4920
4402 3931 4022
4402 3931 4022
OF WATER AND POWER
Page 8 of 8
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
3827 3713 3688 3670 4115 58 5039 5230 4920 4402 3931 4022
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
2120 1979 2115 2038 . 2144
0
2219
0
i p
2467 2533 2289 2240 2102 2191 26436
0
Monthly energy requirement(CME+FES-FEP)
2120 1979 2115 2038 2144t
2219 2467 2533 2289 2240 2102 2191 26436
1.1-75/76 Blank
I
t~ w 'c
PVNGS ER-OL
EL PASO ELECTRIC COMPANY
Year 1981
1.1.1 Load characteristics, demand (MW)
Company peak demand
Jan
586
Feb Mar Apr
556 553 584
May
681
Jun Jul
, 803 767
Aug
772
Sep
727
Oct Nov Dec
644 593 610
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 25 of 56)EL PASO ELECTRIC COMPANY
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
280
28
300
30
320
32
340
34
390
39
420
42
450
45
420
42
390
39
330
33
290
29
310
31
Page 1 of 8
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 1,2&3Total firm purchases (TFP)
614 586 585 618 720 '45
I
,0
812 814 766 677 622 641
Adjusted monthly peak demand(MPD-TFP-XD)
1.1.1 Load characteristics, energy (GWh)
614 586 585 618 720 ', 845 812 766 677 622 641
Company monthly energy
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
327
345
294 33 5 316
16 18 18
310 333 334
353
20
373
401 399
23 22
424 421
418
23
441
375
21
396
346 324 339 4, 206
19 18 19 236
365 342 358 4 442
1.1-77/78 Blank
E ~
PVNGS ER-OL
EL PASO ELECTRIC COMPANY
Year 1982
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,283Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
638 606
300
30
320
32
668 638
668 638
Jan Feb Mar
603
340
34
637
637
Apr
637
360
36
673
673
May
743
410
41
784
784
Jun
864
,45
~4S
909
909
f
836 841
480
48
450
45
884 886
884 886
Jul Aug Sep
792
420
42
834
834
Oct Nov Dec
692 647 665
350
35
310
31
330
33
727 678 698
727 678 698
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 26 of 56)
EL PASO ELECTRIC COMPANY
Page 2 of 8
Company monthly energy
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchases outsidePVNGS 1,2S3
Monthly energy requirement(CME+FES-FEP)
356 320
20 18
0
.376 338
344
19
0
363
346
19
365
386
21
407
438 435 456
24 24
0
25
462 459 481
409
23
432
377 354 370
21 20 20
398 374 390
4,591 "
254
4,845
1.1-79/80 Blank
f
I
I
PVNGS ER-OL
EL PASO ELECTRIC COMPANY
Year 1983
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3-Firm purchases within PVNGS 1,2&3Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
684 648
320
32
350
35
716 683
716 683
Jan Feb Mar
645
370
37
682
682
682 795
390
39
450
45
721 840
721 840
Apr May Jull
935
Io49
984
0
984
I Jul Aug Sep
896
520
'52
901 848
490
49
450
45
948 950 893
0
948 950 893
Oct
741
380
38
779
779
693 713
330
33
350
35
726 748
726 748
Nov DecTotalEnergy
NEED FOR POWER
Table 1.1-2
LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 27 of 56)
EL PASO ELECTRIC COMPANY
Page 3 of 8
Company monthly energy
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
383 343
21 19
404 362
369
21
390
371 414 4(0
21 23 26
0
392 437 496
466 489 439
26 27 25
492 516 464
404
23
427
380 398 4,924
21 22 276
401 4 l9 5, 200
1.1-81/82 Blank
C
%0
PVNGS ER-OL
EL PASO ELECTRIC COMPANY
Year 1984
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside -PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 1,2&3Total firm purchases ('TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
l.l.l, Load characteristics, energy (GWh)
Jan
731
330
33
764
764
692 689 728
360
36
380
38
410
41
728 727 769
728 727 769
Feb Mar Apr May
849
460
46
895
895
Jun
9871
I510
'51
110381
1,038
Jul Aug Sep
956 962 905
540
54
500
50
470
47
1,010 1,012 952
1,010 1,012 952
Oct
791
390
39
830
830
740 761
340
34
370
37
774 798
774 798
Nov DecTotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 28 of 56)
EL PASO ELECTRIC COMPANY
Page 4 of 8
Company monthly energy
Firm energy sales outsidePVNGS 1, 2&3
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
410
22
432
20 21 21
387 417 418
367 396 397 443
24
467
503
27
530
499 523 471
27 28 25
526 551 496
434
23
'57
406 424 5,274
22 23 283
428 447 5,557
1.1-83/84 Blank
PVNGS ER-OLpl~
EL PASO ELECTRIC COMPANY
Year 1985
1.1.1 Load characteristics, demand (MW)
Jan- Feb Mar Apr May JUn1
Jul Aug Sep OctC
Nov DecTotalEnergy„
NEED FOR POWER
Table 1 ~ 1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 29 of 56)EL PASO ELECTRIC COMPANY
Company'eak demand 776 737 734 7759031~0601/017I
1,024 963 841 786 810 Page 5 of 8
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS',2&3Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 1,2&3Total firm purchases (TFP)
350
35
370
37
811 774
390
39
773
420
42
480
48
817 951
530
'53
1, 113
560
56
1,073
520
52
1,076
490
49
410
41
360
36
0\
1,012 - 882 822
380
38
848
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchases outsidePVNGS 1,2&3
811 774
23 21
436 391
773
421
22
817 951
22 25
423 471
13 lg 073
35 531
28 28
1,076
557
29
501 461 432
26 24 23
0
1,012 882 822 848
451
24
0
5,610
296,
0
Monthly energy requirement(CME+FES-FEP)
459 412 443 445 496 563 559 ,586 527 485 455 475 5,906
1.1-85/86 Blank
~~A
l
e
PVNGS ER-OL
EL PASO ELECTRIC COMPANY
Year 1986
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
823 782
360
36
380
38
859 820
Jan Feb Mar
778
410
41
83.9
821 957
440
44
500
50
865 1,007
Apr May JunI
1, 112
54I0
54
1, 166
Jul
1,079
580
58
1, 137
Aug
1,085
540
54
1,139
Sep Oct Nov
1,022 892 834
500
50
420
42
370
37
1,072 934 871
Dec
858
400
40
898
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 30 of 56)EL PASO ELECTRIC COMPANY
Page 6 of 8
Adjusted monthly peak demand(MPD-TFP-ID)
l.l.l Load characteristics, energy (GWh)
859 820 819 865 1,007 1,166 1,137!
lil39 1,072 934 871 898
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
462 414
24 22
445
24 23 26 29
,0
448 500 568 564
29
590
31
0
28 25 24
530 490 459 479
= 25
6,350
310
Monthly energy requirement(CME+FES-FEP)
486 436 469 471 526 597 593 621 558 515 483 504 6,660
1. 1-87/88 Blank
1
l ,L
l
PVNGS ER-OL
EL PASO ELECTRIC COMPANY
Year 1987
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
Jan
864
370
37
820 817
400
40
420
42
Feb Mar Apr
862
450
45
May
1,005 1 Il67
560
56
Jul
1, 132
600
60
Aug
1,139
560
56
Sep Oct Nov
520
52
440
44
380
38
1,072 936 876
Dec
901
410
41
TotalEnergy
NEED OF POWER
Table 1 ~ 1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 31 of 56)
EL PASO ELECTRIC COMPANY
Page 7 of 8
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 1,2&3Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
901
901
860 859
860 859
907
907
1,057
1,057
223 1, 192
223 1,192
1,195
1,195
1, 124 980 914
1,124 980 914
942
942
Company monthly energy
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchases outsidePVNGS 1,2&3
486
25
435 468
23 25
470
25
525 j596
311
0,'
591
31
620
32
557 513 482
29 27 25
503
26
6, 617
327
Monthly energy requirement(CME+FES-FEP)
511 458 493 495 552,'27 622 652 586 540 507 529 6,944
1.1-89/90 Blank
'l
~ J
PVNGS ER-OL
EL PASO ELECTRIC COMPANY
Year 1988
1.1.1 Load characteristics, demand (MW)
Jan Feb Mar Apr May Jolll
Jul Aug Sep Oct Nov DecTotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 32 of 56)EL PASO ELECTRIC COMPANY
Company peak demand 901 854 851 899 1,048 1, Z16 180 1,187 1,117 975 912 939 Page 8 of 8
Firm sales outside PVNGS 1,2s3Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly- peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total f~.rm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-'KD)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
390
39
940
940
26
534
420
42
896
896
455
24
479
440
44
470
47
540
54
89'5 946 1,102
491, 493 549
25 25 28
516 518 577
895 946 1,102
590
59
1,275
1,275
'624
'2
'656
630
63
590
59
550
55
1,243 1,246 1,172
619 648 583
32 34 30
651 682 613
1,243 1,246 1,172
460
46
1,021
1,021
537
28
565
400
40
430
43
952 982
952 982
26 27 338
530 553 6,874
504 526 6 I 536
1.1-91/92 Blank
!
PVNGS ER-OL']
PUBLIC SERVICE COMPANY OF NEW MEXICO
Year 1981
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 1,2&3Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchases outsidePVNGS 1,2&3
762 728
214
214
976
214
214
942D
000
976 942
437 379
145 130
Jan Feb
684 692 740
214
214
223
223
223
223
898 915 963
898 915 963
403 383 407
145 146 151
0
Mar Apr May
I 864
t
I252
r
I
', 252
1 ll6000
1, 116
rI
442
I165
'0
Jul Aug
883 861
252
252
252
252
1,135 1,113
469 .464
170 170
1,135 1,113
Sep
818
252
252
1,070
1,070
409
165
Oct Nov Dec
752 787 828
253
253
253
253
253
253
1,005 1,040 1,081
426 430 466
174 167 172
1,005 1,040 1,081
TotalEnergy
5, 118
1,905
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 33 of 56)PUBLIC SERVICE COMPANY OF NEW MEXICO
Page 1 of 8
Monthly energy requirement(CME+FES-FEP)
582 509 548 529 558 I 607 639 634l
574 600 597 638 7,023
1.1-93/94 Blank
t
j
PVNGS ER-OL
PUBLIC SERVICE COMPANY OF NEW MEXICO
Year 1982
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 1,2&3Total firm purchases (TFP) 0
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Jan
845
253
253
1,098
1, 098
Feb
807
253
253
1,060
1, 060
Mar Apr May
758 767 821
253
253
256
256
256
256
1,011 1,023 1,077
1/011 lg 023 1 077
Junl
9 58
275
275
1. 233
1,233
Aug Sep
955 907
275
275
275
275
275
275
1,254 1,230 1,182
1 254 1 230 1 182
Oct
834
275
275
1,109
1,109
Nov Dec
872 918
275
275
1,147
275
275
1,193
1,147 1,193
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 34 of 56)
PUBLIC SERVICE COMPANY OF NEW MEXICO
Page 2 of 8
Company monthly energy
Firm energy sales outside'PVNGS 1,2&3
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
485
179
664
421
577
449 426 453
173 169 175
622 595 628
492
181
lp
67,3
522 517 455
'87 187 181
709 704 636
474
188
662
478 518 5,690
181 188 2,145
659 706 7,835
1.1-95/96 Blank
I
4
PVNGS ER-OL
PUBLIC SERVICE COMPANY OF NEW MEXICO
Year 1983
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,2a3Total firm purchases (TFP)
Jan
929
275
275
1, 204
Feb
887
275
275
1,162
Mar Apr May
833 843 902
275
275
278
278
278
278
1,108 1,121 1,180
Jun Ju]
>,053
241
241
1,076
241
241
1, 294 l., 317
Aug
1,049
241
241
1;290
Sep Oct Nov
996 916 959
241
241
242
242*
242
242
1,237 1,158 1,201
Dec
1,009
242
242
1,251
TotalEnergy
NEED FOR POWER
Table 1 ~ 1-2
LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 35 of 56)
PUBLIC SERVICE COMPANY OF NEW MEXICO
Page 3 of 8
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy Purchases outsidePVNGS 1,263
1, 204
539
188
1, 162
466
170
1,108 1,121 1,180
499 473 503
188 184 190
1,294
546
155
0
1,317
579
160
1,290
574
160
1,237 1,158 1,201
505 526 531
155 161 156
1,251
580
161
6,321
2,038
Monthly energy requirement(CME+FES-FEP)
727 636 687 657 693 701 739 734 660 687 687 741 8,359
C
], ].-97/98 Blank,~
I
, bv
PVNGS ER-OL
PUBLIC SERVICE COMPANY OF NEW MEXICO
Year 1984
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2a3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases w'ithin PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
Jan
1,006
242
242
1,248
1,248
587
160
747
Feb
960
242
242
1,202
1, 20'2
509
150
659
Mar Apr
902 913
242
242
246
246
1,144 1,159
542 514
160 157
702 671
1,144 1,159
May
977
246
246
1.223
1,223
546
163
709
(
1~,14'0
<205
1--'205
I
1;345
000
1',3451
I
', 594
127
0
721
Jul Aug Sep
205
205
205
205
205
205
1,370 1,341 1,284
1,370 1,341 1,284
630 624 549
131 131 127
761 755 676
1,165 1,136 1,079
Oct
992
206
206
1,198
1,198
572
132
704
Nov DecTotalEnergy
1,038 1,093
206
206
206
206
1,244 1,299
1,244 1,299
706 758 8,577
578 626 6,871
128 132 1,706
NEED FOR POWER
Table 1.1-2C
LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 36 of 56)PUBLIC SERVICE COMPANY OF NEW MEXICO
Page 4 of 8
1. 1-99/100 Blank
1
l,
PVNGS ER-OL
PUBLIC SERVICE COMPANY OF NEW MEXICO
Year 1985
1.1.1 Load characteristics, demand (MW)
Jan Feb Mar Apr MayI
)Jun Jul Aug Sep Oct Nov Dec
TotalEnergy
NEED FOR POWER
Table 1.1-2" LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 37 of 56)PUBLIC SERVICE COMPANY OF NEW MEXICO
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
206
206
206
206
206
206
1,093 1,043 980 992
209
209
1,061
209
209
221
221
221
221
221
221
il,237 1,265 1,234 -1, 172
221
221 222 222 222
1,078 1,128 1,187
222 222 222
Page 5 of 8
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,2&3
1,299 1,249 1,186
1,299 1,249 1,186
637 555 588
134 121 134
1,201
1,201
558
131
1,270
1,270
593
136
~1, 458
o
00
3.,458
f
644l
137
0
1,486 1,455
1,486 1,455
683 677
142 142
1,393
1,393
596
137
1,300 1,350 1,409
0-00
1,300 1,350 1,409
621 627 680
143 138 143
7,459
1,642
Monthly energy requirement(CME+FES-FEP)
771 676 722 689 729 781 825 819 733 764 765 823 9,101
1.1-101/102 Blank
PVNGS ER-OL
PUBLIC SERVICE COMPANY OF NEW MEXICO
Year 1986
1.1.1 Load characteristics, demand (MW)
Company peak demand
Jan
1,168
Feb Mar Apr
1,114 1;047 1,060
May
1.133
Jun
].,323
Jul
1,352
Aug Sep Oct
1,318 1,252 1,152
Nov
1,205
Dec
1,268
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 38 of 56)
PUBLIC SERVICE COMPANY OF NEW MEXICO
Page 6 of 8
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
222
222 222 222
222 222 226
226
226
226
237
237
237
237
237
237
237
237
238
238
238
238
238
238
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 1,2&3Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
l.l.l Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
1,390
1,390
683
143
826
1,336 1,269 1,286
1 I 336 1 269 1 286
591 631 599
129 143 141
720 774 740
1,359
1,359
636
145
781
1,560
000
1,560Q
691
147
838
1,589
1,589
733
151
884
1,555 1,489 1,390
1,555 1,489 1,390
726 639 666
151 147 153
877 786 819
1,.443
1,443
672
148
820
1,506
1,506
729 7,996
153 1,760
882 9,756
l. 1-103/104 Blank
CV
r
PVNGS ER-OL
PUBLIC SERVICE COMPANY OF NEW MEXICO
Year 1987
1.1.1 Load characteristics, demand (MW)
Company peak demand
Jan Feb
1,248 1,191
Mar
1,119
Apr May
1,133 1,211 3,414
Jul
1,445
Aug Sep Oct
1,409 1,338 1,231
Nov
1,288
Dec
1,355
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 39 of 56)PUBLIC SERVICE COMPANY OF NEW MEXICO
Page 7 of 8
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
238
238
238
238
238
238
242
242
242 , 256
242 256
256
256
256
256
256
256
257
257
257
257
257
257
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 1,2&3Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
1,486 1,429
1,486 1,429
1,357
1,357
1,375 1,453
1,375 1,453
1,670
000
1
1,670
1,701
1,701
1,665 1,594 1,488
1,665 1,594 1,488
1,545
1,545
1,612
1,612
Company monthly energy
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
733 634
153 138
885 772
676
153
829
642 682 ~ 741
151 155 157
0
793 837 898
786
163
949
779 686 714
163 157 164
942 843 878
721
159
0
880
781 8,575
164 1,883
945 10,458
105/106 Blank
t
f
1
f
j
J
PVNGS ER-OLli
PUBLIC SERVICE COMPANY OF NEW MEXICO
Year 1988
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Firm purchases outside PVNGS 1,283Firm purchases within PVNGS 1,283Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1, 2'
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
Jan Feb Mar
1 352 1/290 lg212
257
257
257
257
257
257
1,609 1,547 1,469
792 685 731
164 152 164
956 837 895
1,609 1,547 1,469
000
Apr
1.227
260
260
1,487
1,487
694
160
854'ay
Jun
260
260
274
274
274
274
1,572 1,805 1,839
1,572 1,805 1,839
737 801 850
166 168 174
0 . 0
903 969 1,024
1,312 1,531 1,565
Aug
1,526
274
274
1,800
1,800
842
174
1,016
Sep Oct Nov
1-,449 1,333 1,395
274
274
275
275
275
275
1,723 1,608 1,670
000
000
741 772 779
168 176 170.
0 .
909 948 949
1,723 1,608 1,670
Dec
1,468
275
275
1,743
000
1,743
845
176
1,021
TotalEnergy
9,269
2,015
11,284
I
NEED FOR POWER
Table 1,1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 40 of 56)
PUBLIC SERVICE COMPANY OF NEW MEXICO
Page 8 of 8
cyf
1.1-107/108 Blank
f
ji
i
r ~
PVNGS ER-OL
SALT RIVER PROJECT
Year 1981
Load characteristics,demand (MW)
Company peak demand (a)
Firm sales outsidePVNGS 1,2&3
Firm sales withinPVNGS 1,2&3
Total firm sales (TFS)
Monthly peak demand(CPD+TFS)
Firm purchases outsidePVNGS 1,2&3
Firm purchases withinPVNGS j,2&3
Total firm purchases (TFP)
Adjusted monthly peakdemand (MPD-TFP-ID)
Load characteristics,energy (GWh)
Jan
1,423
150
201
351
1,774
(63)
(63)
1, 711
Feb
1,335
150
201
351
1,686
(62)
(62)
1, 624
Mar Apr May
1,371 1,452 1,960
50 50 50
201 201 201
251 251 251
1622 lg7032g211
(71) (123) (143)
(71) (123) (143)
1,551 1,580 2,068
Jun
2,265
50
210
260
2,525
(160)
(160)
2,365
2,312
50
210
260
2,572
'160)'
(160)
2,412
Aug
2,269
50
210
260
2,529
(160)
(160)
2,369
Sep Oct Nov
2,208 1,733 1,372
50 50 50
210 210
260 260
210
260
2,468 1,993 1,632
(160) (64) (59)
(160) (64) (59)
2g 308 1 929 1 573
Dec
1,463
50
210
260
1,723
(64)
(64)
1,659
TotalEnergy
NEED FOR PO~R
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 41 of 56)
SALT RIVER PROJECT
Page 1 of 8
Company monthly energy(includes interruptibleenergy)
900 783 787 . 756 825 999 1, 164 1,232 1,230 1,021 798 780 11,275
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchasesoutside PVNGS 1,2&3
64
(26)
48
(27)
33 19 24
(34) (57) '63)26
(74)
31
(84)
31
(78)
22 19 15
(68) (26) (23)
25
(26)
357
(586)
Monthly energy requirement(CME+FES-FEP)
938 804 786 718 786 951 1,185 1,184 1,014 790 779 11,046
(a) Interruptible demand is not included in the peak load forecast, and no generationis planned to supply interruptible demand.
l. 1-109/110 Blank
l
4
PVNGS ER-OL
SALT RIVER PROJECT
Year 1982
Load characteristics,demand (MW)
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov DecTotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 42 of 56)
SALT RIVER PROJECT
Company peak demand (a)
Firm sales outsidePVNGS 1,2&3
Firm sales withinPVNGS 1,2&3
Total firm sales (TFS)
Monthly peak demand(CPD+TFS)
1,481
55
210
265
1,746
55 55 55
210 210 210
265 265 265
1 /655 1 / 698 1 785
1,390 1,433 1,520 2,058
55
210
265
2/323
2,379
55
220
275
2,654
2,429
,55
t 220
275
2,704
2,384 2,318
55 55
220 220
275 275
2,659 2,593
1,821
55
220
275
2,096
55
220
275
220
275
1.,716 1,810
1/441 1 /535Page 2 of 8
Firm purchases outsidePVNGS 1,2&3
Firm purchases withinPVNGS 1,2&3
Total firm purchases (TFP)
Adjusted monthly peakdemand (MPD-TFP-ID)
Load characteristics,energy (GWh)
(63)
(63)
1,683
(62) (71) (123)
(62) (71) (123)
1,593 1,627 1,662
(143)
(143)
2,180
(160) (160) (160) (160)
(160) (160) (160) (160)
2/494 2/544 2/499 2 433
(64)
0,
(64)
2,032
(59) (64)
(59) (64)
1,657 1,746
Company monthly energy(includes interruptibleenergy)
938 813 821 787 860 1 043 1,217 1,289 1,288 1,075 840 821 11/792
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchasesoutside PVNGS 1,2&3
33
(26)
31 35 19
(27) (34) (57)
25
(63)
27 32 33 24
(74) (84) (78) (68)
19
(26)
16 26 320
(23) - (26) (586)
Monthly energy requirement(CME+FES-FEP)
945 817 822 749 822 996 1, 165 1 244 1 244 1,068 833 821 11,526
(a) Interruptible demand is not included in the peak demand, and no generationis planned to supply interruptible demand.
l.1-111/112 Blank
l
i
)
PVNGS ER-OLrr,
~
'ALT
RIVER PROJECT
Year 1983
l. 1. 1 Load characteristics,demand (MW)
Company peak demand (a)
Firm sales outsidePVNGS 1,2&3
Firm sales withinPVNGS 1,2&3
Total firm sales (TFS)
Monthly peak demand(CPD+TFS)
Firm purchases outsidePVNGS 1,2&3
Firm purchases withinPVNGS 1,2&3
Total firm purchases (TFP)
Adjusted monthly peakdemand (MPD-TFP-ID)
Load characteristics,energy (GWh)
Jan
1,560
60
220
280
1,840
(63)
(63)
1,777
Feb
1, 464.
60
220
280
1,744
(62)
(62)
1, 682
Mar Apr May
1 503 lg'592 2g154
60 60 60
220 220 220
(71) (123) (143)
(71)
0F
(123)
lI712 1 749 2 291
280 280 280
lI783 1 872 2 434
Jun
2,489
60
229
289
2,778
(160)
(160)
2,618
Jul Aug
2;541/
60
)229
289
2,'830
2,494
60
229
289
2,783
(160) (160)
(160) (160)
2,670 2,623
Sep
2,426
60
229
289
2,715
(160)
(160)
2,555
Oct Nov Dec
1,904 1,510 1,611
60
229
289
60
229
289
60
229
289
2,193 1,799 1,900
(64) (59) (64)
(64) (59) (64)
2,129 1,740 1,836
TotaljEner
N'EED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 43 of 56)
SALT RIVER PROJECT
Page 3 of 8
Company monthly energy(includes interruptibleenergy)
995 862 866 830 907 1,101 1,285 1,362 1,360 1, 129 882 862 12,441
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchasesoutside PVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
35
(26)
1,004
33.
(27)
868
36 20 26
868 793 870
(34) (57) (63)
28
(74)
1,055
34 34
(84) (78)
1,235 1,318
26
(68)
1,318
20 16 27
1,123 875 863
(26) (23) (26)
335
(586)
12,l.9P
(a) Interruptible demand is not included in the peak load forecast, and no generationis planned to supply interruptible demand.
1. l-ll3/114 Blank
/
I
1
I
lo
PVNGS ER-OL
SALT RIVER PROJECT
Year 1984
Load characteristics,demand (MW)
Company peak demand (a)
Firm sales outsidePVNGS 1,2&3
Firm sales withinPVNGS 1,2&3
Total firm sales (TFS)
Monthly peak demand(CPD+TFS)
Firm purchases outsidePVNGS 1,2&3
Firm purchases withinPVNGS 1,2&3
Total firm purchases (TFP)
Adjusted monthly peakdemand (MPD-TFP-ID)
Load characteristics,energy (GWh)
Jan
1,622
60
229
289
1,911
(63)
(63)
1,848
Feb Mar Apr
1,521 1,563 1,656
60 60 60
229 229 229
289 289 289
1,810 1,852 1,945
(62) (71) (123)
(62) (71) (123)
1,748 1,781 1,822
May
2,245
60
229
289
2,534
(143)
(143)
2,391
Jun
2 598 2 6 2
60
239
299
,60
239
299
2,897 2,951
(160)
(160)
(160)
0
(160)
2,737 i,791
Aug Sep Oct
2 I 603 2 530 1 g 980
60 60 60
239 239 239
299 299 299
2,902 2,829 2,279
(160) (160) (64)
(160) (160) (64)
2,742 2,669 2,215
Nov
1,563
60
239
299
li862
(59)
(59)
1,803
Dec
1,666
60
239
299
1,965
(64)
(64)
1,901
TotalEnerg
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 44 of 56)
SALT RIVER PROJECT
Page 4 of 8
Company monthly energy(includes interruptibleenergy)
1,046 904 907 867 948 1,154 ,3S1 1,433 1,430 1,186 922 902 13,050
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchasesoutside PVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
35
(26)
1,055
33 37 20
910 910 830
(27) (34) (57)
26
(63)
911
28
(74)
1, 108
34I
f
(84)1
I
ll,301
34 25 20
(78) (68) (26)
] I3891I387 lg180
16
(23)
915
27 335
903 12,799
(26) (586)
(a) Xnterruptible demand is not included in the peak load forecast, and no generationis planned to supply interruptible demand.
l.1-lls/116 Blank
'r
PVNGS ER-OL
SALT RIVER PROJECT
Year 1985
Load characteristics,demand (MW)
Company peak demand (a)
Firm sales outsidePVNGS 1,2&3
Firm sales withinPVNGS 1,2&3
Total firm sales (TFS)
Monthly pe'ak demand(CPD+TFS)
Firm purchases outsidePVNGS 1,2&3
Firm purchases withinPVNGS 1,2&3
Total firm purchases (TFP)
Ad)usted monthly peakdemand (MPD-TFP-ID)
Load characteristics,energy (GWh)
Jan Feb
60 60
239 239
299 299
2,003 1,926
(63) (62)
(63) (62)
1,940 1,864
1,704 1,627
Mar Apr May
1,641 1,739 2,360
60
239
60
239
60
239
299 299 299
1,940 2,038 2,659
(71) (123) (143)
(71) (123) (143)
1,869 1,915 2,516
Jun
2/733
60
251
311
',044,
I
(160)',
0
(160)
2,884
'ul
Aug Sep
2,738 2,661
60 60 60
251 251 251
311 311 311
3/101 3/049 2/972
(160) (160) (160)
(160) (160) (160)
2,941 2,889 2,812
Oct
2,081
60
251
311
2,392
(64)
(64)
2,328
Nov Dec
1,641 1,750
60 60
(59) (64)
(59) (64)
1 893 1 997
251 251
311 311
1,952 2,061
TotalEnergy
$/
NEED FOR POWER
Table 1.1-2lOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 45 of 56)SALT RIVER PROJECT
Page 5 of 8
Company monthly energy(includes interruptibleenergy)
1,113 960 9.61 917 1,004 1,223 1,436 1,524 1,520 1,259 979 957 13,853
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchasesoutside PVNGS 1,2&3
35 33
(26) (27)
37 20
(34) (57) (63)
28
(74)
34 34 26
(84) (78) (68)
20
(26)
27 ,336
(23) (26) (586)
Monthly energy requirement(CME+FES-FEP)
1/122 966 964 880 967 1,177 1,386 1 480 1,478 1, 253 972 958 13,603
(a) Interruptible demand is not included in the peak load forecast, and no generationis planned to supply interruptible demand.
l. 1-117/118 Blank
r~
3 j,l
1
l1
I
I
"P
PVNGS ER-OL
SALT RIVER PROJECT
Year 1988
Load characteristics,demand (MW)
Company peak demand (a)
Firm sales outsidePVNGS 1,2&3
Firm sales withinPVNGS 1,2&3
Total firm sales (TFS)
Monthly peak demand(CPD+TFS)
Firm purchases outsidePVNGS 1,2&3
Firm purchases withinPVNGS 1,2&3
Total firm purchases (TFP)
Adjus ted monthly peakdemand (MPD-TFP-ID)
Load characteristics,energy (GWh)
Jan Feb
1,893 1,774
60 60
271 271
331 331
2,224 2,105
(63) (62)
(63) (62)
2, 161 2,043
Mar
1, 822
60
271
331
2, 153
(71)
(71)
2,082
Apr May Jun
1,932 2,624 3,039
60 60 60
271 271 282
331 331 342
2,263 2,955 3,381
(123) (143) (160)
0
(123) (143) (160)
2,140 2,812 3,221
Jul
3, 103
60
282
342
3,445
(160)
(160)
3, 285
Aug Sep Oct
3/045 2~960 2g313
60 60 60
282 282 282
342 342 342
3 387 3 302 2g 655
(160) (160) (64)
(160) (160) (64)
3,227 3,142 2,591
Nov
1,822
60
282
342
2, 164
(59)
(59)
2, 105
Dec
1,944
60
282
342
2,286
(64)
(64)
2,222
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 48 of 56)SALT RIVER PROJECT
Page 8 of 8
Company monthly energy(includes interruptibleenergy)
Firm energy sales outsidePVNGS 1,2&3
Firm energy purchasesoutside PVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
35 33
(26) (27)
1,285 1, 104
1,276 1,098 1,095
37
(34)
1,098
20 26 28
(57) (63) (74)
1,007 1,107 1,352
1,044 1,144 1,398 1,645
34
(84)
1,595
34 26 20
(78) (68) (26)
1 704 1 702 1 g 436
1,748 1,744 1,442 1, 121
16
(23)
1,114
27 '336
(26) (586)
1 096 15 600
1,095 15,850
(a) Interruptible demand is not included in the peak load forecast, and no generationis planned to supply interruptible demand.
1.1-123/124 Blank
I
I
t
PVNGS ER-OL
SOUTHERN CALIFORNIA EDISON COMPANY
Year 1981
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2&3Firm sales within PVNGS 1,2&3Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Jan Feb
l73
173
173
173
10592 10378
10419 10205
Mar
10081
173
173
10254
Apr May
9988 10898
79
79
79
79
10067 10977
Jlln
11971
79
79
12050
Jul
12861
79
79
12940
Aug Sep
79
79
79
79
13180 12874
13101 12795
Oct
11039
79
79
11118
Nov Dec
10779 10919
173
173
173
173
10952 11092
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 49 of 56)
SOUTHERN CALIFORNIA EDISON
Page 1 of 8
Firm purchases outside PVNGS 1,2&3Firm purchases within PVNGS 1,2&3Total firm purchases (TFP)
517
517
517
517
517
517
517
517
517
5l7
823
823
823
823
823
823
823
823
611
611
517
517
517
517
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
,.Firm energy sales outsidePVNGS
Firm energy purchases outsidePVNGS 1,2&3
Monthly energy requirement(CME+FES-FEP)
10075 9861
5463 4865
272 259
5735 '5124
9737
5489
196
5685
9550 10460
5371 5541
188 276
5559 5817
11227
5719
263
5982
12117
6179
281
6460
12357 12051
6215 5764
281 269
6496 5033
10507
5674
264
,5938
10435 10575
5366 5564 67210
286 291 3136
5652 5855 70346
1. 1-125/126 Blank;
n
f
l
PVNGS ER-OL
SOUTHERN CALIFORNIA EDISON COMPANY
Year 1982
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1,2S3Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Jan Feb
10799 10585
229
229
229
229
11028 10814
Mar
10441
229
229
10670
Apr May Jun
135 135
135 135
135
135
10483 11433 12546
10348 11298 12411
Jul
13331
135
.135
13466
Aug Sep Oct
135
135
135
135
135
135
13716 13400 11574
13581 13265 11439
Nov Dec
11169 11319
229
229
229
229
11398 11548
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 50 of 56)
SOUTHERN CALIFORNIA EDISON
Page 2 of 8
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
517
517
517
517
517
517
517
517
517
517
611
611
611
611
611
611
611
611
611
611
517
517
517
517
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,2&3
10511 10297
5673 5045
296 285
10153
5699
283
9966 10916 11935
5561 5751 5929
274 273 261
12855
6409
267
13105 12789 10963
6445 5974 5884
281 294 295
10881 11031
5576 5774
302 294
69720I
3405
Monthly energy requirement(CME+FES-FEP)
5969 5330 5982 5835 6024 6190 6676 6726 6268 6179 5878 6068 73125
l.l-127/128 Blank
1
l
PVNGS ER-OL
SOUTHERN CALIFORNIA EDISON
Year 1983
1.1.1 Load characteristics, demand (MW)
Company peak demand
Jan
11209
Feb Mar Apr
10975 10831 10728
May
11718
Jun Jul Aug
12871 13831 14091
Sep
13765
Oct Nov Dec
11869 11589 11749
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 51 of 56)
SOUTHERN CALIFORNIA EDISON
Page 3 of 8
Firm s ales outs ide PVNGS 1, 2 G3Firm sales within PVNGS 1,263Total firm sales (TFS)
94
94
94
94
94
94
94
94
94
94
Monthly peak demand (CPD+TFS) 11303 11069 10925 10728 11718 12871 13831 14091 13765 11869 11683 11843
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
517
517
517
517
517
517
517
517
517
517
611
611
611
611
611
611
611
611
611
611
517
517
517
517
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
10786
5893
259
6152
10552 10408 10211
5245 5919 5783.
244 247 202
5489 6166 5983
11201
5981
155
6136
12260 13220 13480
6169 6659 6705
161 148 166
6330 6807 6871
13154
6224
179
6403
11258 11166 11326
6124 5796 6004
233 250 236
6357 6046 6240
72500
2480
74980
1.1-129/130 Blank
I
f
iJ,'
l
PVNGS ER-OL
SOUTHERN CALIFORNIA EDISON
Year 1984
1.1.1 Load characteristics, demand (MW)
Company peak demand
Jan Feb
11629 11395
Mar
11241
Apr May Jun Aug Sep
11128 12158 1335l 14351 14621 14285
Oct
12319
Nov Dec
12029 12189
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 52 of 56)
SOUTHERN CALIFORNIA EDISON
Page 4 of 8
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
94
94
94
94
94
94
353353353
353353353
Monthly peak demand (CPD+TFS) 11723 11489 11335 11128 12158 13351 14351 14621 14285 12319 12382 12542
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
517
517
517
517
11206 10972
517
517
10818
517
517
776
776
10611 11382
870I
870
12481
870
870
870
870
870
870
13481 13751 13415
870
870
11449
517
517
517
517
11865 12025
Company monthly energy
Firm energy sales outsidePVNGS l,263
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
6143 5585
236 191
6379 5776
61 69
205
6374
6021 6231 6429 6939 6975 6474
202 141 143 135 145 174
6223 6372 6572 7074 7120 6648
6374
215
6689
6036 6254 75630,
223 244 2254
6259 6498
77884'.1-131/132
Blank
lt
v
PVNGS ER-OL
SOUTHERN CALIFORNIA EDISON
Year 1985
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 1, 263Firm sales within PVNGS 1,263Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Jan
11989
353
353
12342
Feb Mar Apr
353
353
353
353
259
259
12098 11934 11727
11745 11581 11468
May
12528
12528
Jun Jul
13761 14791
137'61 14791
Aug
15071
15071
Sep Oct Nov
14725 12699 12399
353
353
14725 12699 12752
Dec
12569
353
353
12922
Total;Energy,
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 53 of 56)
SOUTHERN CALIFORNIA EDISON
Page 5 of 8
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
517
517
517
517
517
, 517
517
517
776
776
870 870
870 870
870
870
870
870
870
870
517
517
517
517
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
11825
6353
224
6577
11581 11417 11210
5655 6379 6231
188 192 202
5'843 6571 6433
11752
6451
122
6573
I
12891 13921
6649 7179
124 132
6773 7311
14201
7225
135
7360
13855 11829 12235
6704 6604 6256
144 205 215
6848 6809 6471
12405
6474
229
6703
78160.
2112
80272
l. 1-133/134 Blank
PVNGS ER-OL
SOUTHERN CALIFORNIA EDISON
Year 1986
1.1.1 Load characteristics, demand (MW)
Company peak demand
Jan
12369
Feb Mar Apr
12115 11981 11838
May
12918
Jun Jul Aug
14201 15261 15551
Sep
15195
Oct Nov Dec
13109 12799 12969
TotalEnergy
NEED FOR PONDER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 54 of 56)
SOUTHERN CALIFORNIA EDISON
Page 6 of 8
Firm sales outside PVNGS 1,263Firm sales within PVNGS 1,263Total firm sales (TFS)
353
353
353
353
353
353
259
259
353
353
353
353
Monthly peak demand (CPD+TFS) 12722 12468 12304 12097 12918 14201 15261 15551 15195 13109 13152 13322
Firm purchases outside PVNGS 1,263Firm purchases within PVNGS 1,263Total firm purchases (TFP)
517
517
517
517
517
517
517
517
766
766
, 870
'70870
870
870
870
870
870
870
870
517
517
517
517
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 1,263
Firm energy purchases outsidePVNGS 1,263
Monthly energy requirement(CME+FES-FEP)
12205
6573
228
6801
11951 11787 11580
5855 6599 6451
200 205 199
6055 6804 6650
12152
6671
128
6799
13333, 14391 14681
6879 7419 7475
136 136 140
7015 7555 7615
14325
6944
161
7105
12239 12635 12805
6834 6476 6694
207 220 232
7041 6696 6926
80870
2192
83062
l. 1-135/136 Blank
I
j
PVNGS ER-OL
SOUTHERN CALIFORNIA EDISON
Year 1987
1.1 1 Load characteristics, demand (MW)
Company peak demand
Jan Feb Mar
12733 12469 12331
Apr
12171
May Jun Jul
13301 14661 15751
Aug Sep Oct
16051 15685 13529
Nov
13209
Dec
13353
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 55 of 56)SOUTHERN, CALIFORNIA EDISON
Page 7 of 8
Firm sales outside PVNGS 4&5Firm sales within PVNGS 4&5Total firm sales (TFS)
353
353
353
353
353
353
259
259
981
981
981
981
Monthly peak demand (CPD+TFS) 13086 12822 12684 12430 13301 14661 15751 16051 15685 13529 14190 14334
Firm purchases outside PVNGS 4&5Firm purchases within PVNGS 4&5Total firm purchases (TFP)
517
517
517
517
517
517
517
517
776
776
870
870
870
870
870
870
870
870
870
870
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 4&5
Firm energy purchases outsidePVNGS 4&5
Monthly energy requirement(CME+FES-FEP)
12569 12305 12167
6781 6027 6847
253 230 219
7034 6257 7066
11913
6647
220
6867
12525 13791 14681
6882 7109 7669
134 147 139
7016 7256 7808
15181 14815 12659
7715 7174 7063
47 57 94
7762 7231 7157
14190
6695
110
6805
14334
6961 83480
142 1802
7103 85282
1.1-137/138 Blank
l
I
i
PVNGS ER-OL
SOUTHERN CALIFORNIA EDISON
Year 1988
1.1.1 Load characteristics, demand (MW)
Company peak demand
Firm sales outside PVNGS 4&5Firm sales within PVNGS 4&5Total firm sales (TFS)
Monthly peak demand (CPD+TFS)
Jan Feb Mar
981
981
981
981
981
981
14114 13840 13666
13133 12859 12675
Apr
12515
981
981
13106
May Jun Jul
13675 15075 16205
13675 15075 16205
Aug
16515
16515
Sep Oct
16175 13913
16175 13913
Nov
13583
981
14564
Dec
13763
981
14744
TotalEnergy
NEED FOR POWER
Table 1.1-2LOAD AND ENERGY REQUIREMENTS BY MONTH
1981 THROUGH 1988 (Sheet 56 of 56)SOUTHERN CALIFORNIA EDISON
Page 8 of 8
Firm purchases outside PVNGS 4&5Firm purchases within PVNGS 4&5Total firm purchases (TFP)
870
870
870
870
870
870
870
870
870
870
870
870
Adjusted monthly peak demand(MPD-TFP-ID)
1.1.1 Load characteristics, energy (GWh)
Company monthly energy
Firm energy sales outsidePVNGS 4&5
Firm energy purchases outsidePVNGS 4&5
Monthly energy requirement(CME+FES-FEP)
14114 13840 13666
6991 6337 7005
154 126 126
7145 6463 7131
13106
6820
150
6970
12805 14205 15335
7065 7311 7885
62 73 63
7127 7384 7948
15645
7935
8013
15305 13043
7391 7261
73 139
7464 7400
14564
6878
149
7027
14744
7121 86000
162 1355
7283 87355
1.1-139/140 Blank
l
II „'
Table 1.1-5
COMPARISON OF ACTUAL PEAK DEMANDS AND ENERGY REQUIREMENTS IN 1973 THROUGH 1978
WITH FORECASTS MADE IN PRIOR YEARS FOR COMBINED
WSCC SOUTHERN CALIFORNIA-NEVADAAND ARIZONA-NEW MEXICO SYSTEM
Peak Demand (MW) Energy Requirements (GWH)
Year ActualForecast inPrior Year
Deviation(4) Actual
Forecast In,Prior Year
Deviation(4)
1973
1974
1975
1976
1977
1978
23,30523,31923,57425,53825,92527,.533
23, 824 (in 1972)
25,775 (in 1973)
25,229 (in 1974)
25,686 (in 1975)
26,921 (in 1976)
27,960 (in 1977)
2.210. 5
7.0 ~
0.63.81.6
124,295122,272121,107129,750132,453139,704
130,217139,870131,846131,277137,117143,060
4.814.4
8.91.23.52.4
Mean Deviation 4.3 5.9
U
0
0
Table 1.1-6ACTUAL 1978 DEMANDS AND ENERGY REQUIREMENTS COMPARED WITH WSCC
FORECASTS MADE IN 1972-1977 FOR COMBINED WSCC SOUTHERN
CALIFORNIA-NEVADAAND ARIZONA-NEW MEXICO SYSTEM
1978 Actual Peak Demand27,533 MW
1978 Actual Energy Requirements139,704 GWH
Forecast
1972
1973
1974
1975
1976
1977
1978 ForecastedPeak Demand
34,523
34,457
30,460
29,145
28,743
27,960
Overestimateof Forecast
(%)
25.4
25.1
10.6
5.9
4 '
1.6
ForecastedEnergy
Requirements
189, 269
185, 694
157, 084
147,764
145,842
143,060
Overestimateof Forecast
(%)
35.5
32.9
12.4
5.8
4.4
2.4
alij0
0