HomeMy WebLinkAboutSCE COMMON FORECASTING METHODOLOGY VII SUPPLY FORMS I IIIIII� IIII III ItlU IVIIII IIIII IIIIII lAI Nl llll
*NEW FILE*
SCE COMMON FORECASTING '
METHODOLOGY VII SUPPLY
FORMS
I
COMMON FORECASTING METHODOLOGY VII
SUPPLY FORMS
Southern California Edison
September 1987
TABLE OF CONTENTS
Supply Forms
R-1 Summary of Loads and Resources
R-2 Summary of Energy Requirements and Resources
R-3A Existing and Planned Utility Owned Thermal Resources
R-3B Existing and Planned Utility Owned Hydro Resources
R-3C Existing and Planned Utility Owned Pumped Storage
R-31) Monthly and Annual Hydroelectric Variation Data
R-3E Existing and Planned Utility Owned Resources
R-4A Qualifying Facilities and Private Supply
R-4B Costs of Qualifying Facilities Purchases
R-5A Interutility Export Transactions
R-5B Interutility Import Transactions
R-6A Existing and Proposed Bulk Transmission Facilities
R-6B Regional Transfer Capabilities
R-7 Environmental Pollutants, Fuel Storage, Land and
Water Use
R-8 Operations and Reliability Data
R-9A Off System Losses
R-9B Reserve Requirements
R-10A Historical and Projected Fuel Consumption
R-10B Projected Capacity Factors
R-11 Fixed Charge Rates
R-12 Construction Outlays for Individual Utility Electric
Plant Additions
R-13 Aggregate Construction Outlays for Total
Utility Electric Plant Additions
R-14 Nuclear Fuel Investment
R-15A Total Variable Expenses
R-15B Heat Content and Cost of Fuel Resources
R-16 Fixed Operation and Maintenance Expenses
R-17A Key Financial Variables
R-17B Financial Variables on Life of Plant by Asset Type
R-18 Inflation, Discount, and Escalation Rates
R-19P Financial Analysis for Investor Owned Utilities
,
September 1987
Southern California Edison Company
CFM VII Supply Plan Filing
Edison' s Resource Strateay--Overview
Resource planning at Southern California Edison Company has
traditionally been dominated by a single load forecast which
determined the resource requirements necessary to meet the load
with an adequate safety margin. This process worked quite well
during decades of steady growth and few surprises.
As the business environment began to change starting in the late
1960 ' s, the process of load forecasting and resource planning
became more complicated. The increasing complexity of
anticipating future demand growth and frequent surprise events
made long-term planning a hazardous profession with many
pitfalls. The initial response to this more complicated
planning environment was more sophisticated forecasting
approaches, more extensive databases, and more emphasis on
optimized resource planning.
As simple as this sounds, it took some time to realize that more
sophisticated forecasting methods were not the problem's cure.
Planning had become more complicated, not because the
forecasting models were inadequate, but because frequent
surprise events made their underlying assumptions inappropriate.
This simple observation led to Edison's new resource planning
philosophy: "Planning for Uncertainty" . As part of this
planning process, Edison developed 12 scenarios of potential
futures . For each of the 12 scenarios, a set of supply- and
demand-side options were developed to meet the load and energy
requirements. Edison' s CFM VII supply plan submittal focuses on
the "No Surprise" scenario with a demand forecast which assumes
the only bypass cogeneration will be economic and is estimated
to be 5, 000 GWh by 1992. It should be noted that if efforts to
constrain the development of uneconomic bypass don't occur, then
bypass (including uneconomic bypass) could be as large as even
14, 000 GWh by 1992. In responsing to bypasl in excess of the
planned 5,000 GWh by 1992, Edison would alter its resource plan
appropriately.
• Increase the oil/gas capacity held in standby reserves.
• Reduce planned spot market capacity purchases from the
Pacific Northwest.
• Delay the Big Creek Expansion Project.
i d
-2-
• Reduce Conditional Demand Side Management.
A more detailed description of Edison's Scenario Planning is
provided in CFM VII, Volume I, Resource Planning Approach. The
"No Surprise" scenario for load growth has been evaluated in
this Volume III report.
The following supply alternatives were used to balance supply'y
with demand:
• Load Management/Conservation
• Independent Power Production/QFs
• Standby Reserve Program for Oil/Gas Units
• Purchases from Neighboring Utilities
• Conventional Resource Additions
Highlighted below are the building blocks for supply used in the
of he la for this submittal:
developmentt p n
• Edison's load management goal for 1999 is 1,810 MW.
• Edison expects to receive over 3,000 MW from independent
Power Producers by 1999. A project-by-project review of
these arrangements produced a projected success rate of
about 60 percent. As a result, further baseload additions
are not foreseen before 19'99.
• 1,596 MW of oil and gas units are scheduled for Edison' s
standby reserve program between 1985 and 1989. Of this,,,
710 MW are due to be returned to service between 1994 and
1997.
• Edison is participating in two transmission projects
between California and the Pacific Northwest, which are k'
planned to provide Edison with an additional 500 MW of,
peaking capacity. These projects are a 1,100 MW expansion
of the Pacific DC Intertie, scheduled for operation in late
1988, and the 1,600 MW California-Oregon transmission line,
scheduled for operation in 1991.
• The Palo Verde-Devers No. 2 line, scheduled for operation
in 1990, will add 1,200 MW of transmission capacity between
Arizona and California. This *merchant* line will be used
by numerous California utilities, including Edison, for
increased capacity and economy energy purchases from the
Southwest, as well as providing other power pooling,
interconnection support and strategic benefits,
• 386 of Edison's 579 MW share of nuclear capacity from the
three 1,222 MW Palo Verde units is in service. The
remaining 193 MW is planned to be in service in 1988.
-3-
• The 200 MW Balsam Meadow Hydroelectric Project, which
commenced construction in late 19830 is planned for
completion in early 1988. The inclusion of pump storage
capability is planned in 1989 .
• To provide needed dibpatchable peaking capacity in the mid
1990 ' s, additions to five existing powerhouses at Edison' s
Big Creek Project are planned. These additions total
505 MW, raising the entire Big Creek Project rating to
approximately 1, 500 MW. These additions will further
enhance the dispatchable peaking capability of the project
by shifting production from off-peak hours to on-peak.
In concert with Edison's "Planning for Uncertainty" approach to
Demand and Supply planning, Edison reviewed the reliability
criteria in light of our current operating environment and
expanded transmission system, and modified its planning reserve
margin criteria to 16 percent.
GAS:yh
SP&R/95
09/24/87
I
U01y Servk a Area: Soudwn Callomla Edlsoo Form R-1
Dale~. Sap-87 CEC contact Pat McAuNk
U" Contact Ron Schmader SUMMARY OF CAPACITY LOADS AND RESOURCES Phom: (916) 324-3602
MW
1984 1905 1956 1907 lose 1989 1990 1991 1992 1993 1994 1995 1996 1997 1999 1999
Awat Ackmd Actual
1.PEAK LOADS'
i
la Grocc Total Load 15189 14587 14599 14891 15243 15576 16050 16496 16928 17324 17759 18202 18645 19071 1950t 19920
lb. Fkm Exports 0 0 0 0 O 0 0 0 0 O O 0 0 0 0 0
te.CondBord DSM 0 0 0 0 63 126 ISO 266 298 371 449 502 555 631 701 760
Tolal Peak Demad 15189 14587 14599 14891 15180 15450 15860 16230 16630 16950 17310 17700 18090 18440 18800 19160
2GENERATM
Nuc$m 1962 1962 2155 2348 2541 2541 2541 2541 2541 2541 2541 2541 2541 2541 2541 2541
Coat— Convenional 1621 1615 leis 1615 leis 1615 1615 1s15 16I5 Isis 1615 leis lets le15 1616 lets
—Advanced 0 0 0 0 0 0 100 100 too 100 too 100 too 100 100 100
2fd Decade Genak: 123 823 '
C6andGmSban 8672 8672 8380 Bits 7076 7076 7076 7076 7076 7076 7202 7522 7622 7786 7786 7786
Combusdon Turbkw Soo Soo 580 580 Soo Soo Sao 580 5a0 580 580 Sao 580 Soo Sao Sao
Cw*knd Cyde 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042
Feed Copawadon 86 266 411 467 1242 /BS7 1664 1742 1742 1742 1742 1742 1742 1742 1742 1742
Name" 12 19 45 91 175 204 290 307 307 318 318 318 318 316 318 318
Geoawmal 6 13 100 134 222 332 479 483 483 Soo 5l6 541 541 541 641 ' 541
VAW 19 46 84 93 98 ill 117 117 117 117 117 117 117 117 117 117
Solar 1 15 45 105 159 lei 195 202 205 205 205 205 205 205 205 203
As Ava6aMe 0 0 26 37 48 63 64 64 64 64 64 64 64 64 64 64
Hydro 982 986 1012 999 1053 1082 1062 1062 1062 1062 1062 1084 1230 1296 1570 1570
Ballary Stnraos 0 0 0 0 0 0 10 10 10 10 to 10 10 10 10 10
IMPORTS-NW 667 667 667 221 736 736 Sao 773 773 773 961 1055 1313 1456 1456 1456
-SW 402 622 622 339 339 ISO 0 0 O 0 0 0 0 0 0 0
-CaMorrie 456 456 456 601 538 538 536 538 538- 538 S38 538 538 538 538 538-
-Olhw 377 377 431 347 347 347 347 347 347 347 347 347 347 277 277 277
Resale Was Am 487 487 659 1018 1065 1097 1104 1180 Ilse lies 1199 1180 IIa0 1160 1180 11a0
PRNATESUPPLY 152 201 225 304 367 447 S39 635 735 836 925 998 1054 1084 1-114 1139
TOTALCAPACDY' 17352 17825 18330 18152 ISM 19372 19412 1977E 19790 19828 20158 20601 21005 21408 21805 22305
3._ dadM*ftnaroe 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0
A-?M-Clpacity 17352 17a25 ta330 18152 18875 19372 19412 19779 19790 19828 20158 20601 21005 21408 21805 22305
15,Reserve Moron 14.24% 22.20% 25.56% 21.90% 24.35% 25.39% 22.40% 21.97% 19.00% 16.98% 16.45% 16.39% 16.14% 16.10% 15.98-A 16.41%
G.EUE NIA N/A NIA N/A 1.97 0.80 1.24 1.38 2.54 6.88 7.40 6.88 10.00 17.46 17.69 17.96
D0e6 not k"We Pdvale Supply
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Utility Service Area: Southern California Edison Form R-2
Date Fled: Sep-87 CEC contact:Pat McAuliffe
Utility Contact: Hon Schroeder SUMMARY OF ENERGY LOADS AND RESOURCES Phone: (916) 324-3602
G Ai
1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1.996 1997 1998 1999
Actual Actual Actual
1.ENERGY LOAD(GWh) _
Ia.Total EnergyCons. 66841 68268 70016 72992 75267 77187 79571 81839 84006 86016 87996 89895 91718 93635 96422 97387
1 b.Pumped Storage 0 0 0 0 0 0 -3.5 -2.1 -1.7 -1.2 -1.3 -1.8 -1.8 -1.8 -1.6 -1.4
1c.System Losses 5322 4748 4597 5206 5363 547% 5600 5690 5805 5878 5956 6036 6120 6218 6322 6435
Id. Contract. Exports 5035 6543 6867 7177 7300 6656s 6618 6684 6718 7142 7130 6806 6959 6785 6909 6972
Ia.Conditional DSM 0 0 0 0 241 4821 723 964 1205 1 445 1686 1927 2168 2409 2650 2891
Company Use 119 113 127 129 132 135 137 140 143 146 149 152 155 158 161 164
MWD Pump Req. 2594 2613 2682 2346 2068 1723 1458 1458 1100 1100 1100 1100 1100 1100 1100 1100
MAN ENERGY REDS. 77024 79313 81342 85173 87489 88630 90864 93048 95121 97388 99193 100607 102426 103926 105801 107700
2.ENERGY PRODUCTION
Nuclear 7239 8421 11939 12556 14071 15487 14837 14136 14310 14271 14270 14272 14315 14265 14272 14276
Coal - Conventional 9842 5909 10057 10201 9995 9325 9215 9719 9533 9540 9618 9613 9598 9443 9689 9604
-Advanced 0 0 0 0 0 0 598 562 501 570 503 564 541 564 503 563
2nd Decade Generic
1631
Oil and Gas Sham 20945 27188 17423 24980 15817 8921 8542 7887 9220 11181 12460 14269 14901 17299 1686E 17463
Combustion Turbine 21 40 50 30 31 0.1 0 0.1 0.1 0.3 0.4 0.6 0.6 0.6 0.8 2.3
Combined Cycle 948 1667 1119 1121 994 475 482 362 502 320 956 532 822 204 843 876
Fossil Cogeneration 593 1857 3278 3506 8082 11280 11868 12479 12642 12607 12607 12607 12642 12607 12607 12607
Biomass 68 146 229 599 1037 lies 1599 1789 1804 1826 1845 1845 1849 1845 1845 1845
Geothermal 44 148 548 1095 1672 2456 3370 3433 3442 3482 3566 3701 3782 3774 3774 3774
Wind 64 284 672 611 644 705 756 757 759 757 757 757 759 757 757 757
Solar 2 18 48 235 327 387 419 438 449 450 450 450 451 450 450 450
As Available 0 0 677 914 1117 1490 1566 1561 1578 1576 1581 1585 1594 1585 1585 1585
Hydro 5589 4611 5888 3593 4693 5046 5046 6046 5046 5046 5046 5046 5087 5169 5179 5179
Pumped Storage 0 0 0 0 0 0 -3.5 -2.1 -1.7 -1.2 .1.3 -1.8 -1.8 -1.8 -1.6 -1.4
IMPORTS-Firm NW 0 0 1213 1821 2580 3100 2577 2549 2555 2549 3043 3686 4120 4234 4342 4342
-Nonflan NW 11109 10053 7139 6218 5346 5296 6187 6962 6549 6033 5059 4007 3464 a438 3481 3412
-Firm SW 2778 4058 4193 2010 2008 1483 414 0 0 0 0 0 0 0 0 0
-Nonfirm SW 5644 5485 2926 3253 5060 8200 9040 9979 10419 9873 9488 8671 9576 9217 9988 9522
-Firm CAL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
-Nonfirm CAL 3717 652 2575 734 632 1027 1018 979 1037 ilia 1212 1233 1247 1288 1312 1306
-Firm Otter 2697 1802 1838 1365 882 767 796 813 775 776 781 781 685 251 251 254
Resale Cites Res. 828 1035 2580 4300 4436 4557 4693 4922 5093 5257 5429 5611 5786 5953 6129 6307
PRNATESUPPLY 1054 1378 1597 1940 2388 2971 3636 4328 5031 5732 6342 6839 7211 7413 7600 7761
Inadvertant -23 4 - 5
Interchange 3865 4555 5358 4090 5549 3891 3902 3938 3905 3909 3897 3891 3909 3892 3892 3896
.Modeling Adjustment' 1 228 577 317 411 -28 615 284 648 88 280 435 289
MAN SYSTEM ENERGY 77024 79313 81342 85173 87489 88630 90864 93048 95121 97388 99193 100607 102426 103928 105801 107700
Adjustment resulting from combining model output with data from outside the model.
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Utility Service Area: Southern California Edison
Date Filed: September, 1987 Form R-3A p. 1 of 4
Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone: (818) 302-9514 Phone: (916) 324-3602
Unit Installed Dependable Average Net Location
Date Percent Unit Loading Fuel Capacity Capacity Annual Energy Air Water
Plant Name and Unit Number Install/Modified Ownership Type Code Type (MW) (MW) (GWH) County Basin Region
ALAMITOS 1 Sep, 56 100.00 ST 2 G 163.20 175.00 344.63 19 SC SC
ALAMITOS 1 Sep, 56 100.00 ST 2 0 163.20 175.00 344.63 19 SC SC
ALAMITOS 2 Feb, 57 100.00 ST 2 G 163.20 175.00 390.36 19 SC Sc
ALAMITOS 2 Feb, 57 100.00 ST 2 0 163.20 175.00 390.36 19 SC SC
ALAMITOS 3 Dec, 61 100.00 ST 2 G 333.00 320.00 782.33 19 SC SC
ALAMITOS 3 Dec, 61 100.00 ST 2 0 333.00 320.00 782.33 ,19 SC SC
ALAMITOS 4 Jun, 62 100.00 ST 2 G 333.00 320.00 1,043.37 19 SC SC
ALAMITOS 4 Jun, 62 100.00 ST 2 0 333.00 320.00 1,043.37 19 SC SC
ALAMITOS 5 Mar, 66 100.00 ST 2 G 495.00 480.00 1,831.67 19 SC SC
ALAMITOS 5 Mar, 66 100.00 ST 2 0 495.00 480.00 1,831.67 19 SC SC
ALAMITOS 6 Sep, 66 100.00 ST 2 G 495.00 480.00 1,785.08 19 SC Be
ALAMITOS 6 Sep, 66 100.00 ST 2 0 495.00 480.00 1,785.08 19 SC SC
ALAMITOS 7 Jul, 69 100.00 CT 5 D 138.13 133.00 15.56 19 SC SC
ALAMITOS 7 Jul, 69 100.00 CT 5 G 138.13 133.00 15.56 19 SC SC
COOL WATER 1 Jun, 61 100.00 ST 2 G 65.28 65.00 108.91 36 YAP cc
COOL WATER 1 Jun, 61 100.00 ST 2 0 65.28 65.00 108.91 36 VAP CC
COOL WATER 2 May, 64 _ 100.00 ST 2 G 81.60 81.00 63.78 36 VAP CC
COOL WATER 2 May, 64 100.00 ST 2 0 81.60 81.00 63.78 36 VAP cc
COOL WATER 3 May, 78 100.00 CT 3 D 163.65 136.00 212.92 36 VAP CC
COOL WATER 3 May, 78 100.00 CT 3 G 163.65 136.00 212.92 36 VAP Cc
COOL WATER 3 May, 78 100.00 ST 3 D 126.35 105.00 36 VAP CC
COOL WATER 3 May, 78 100.00 ST 3 G 126.35 105.00 36 VAP CC
COOL WATER 4 Aug, 78 100.00 CT 3 D 163.65 136.00 194.18 36 YAP CC
COOL WATER 4 Aug, 78 100.00 CT 3 G 163.65 136.00 194.18 36 VAP cc
COOL WATER 4 Aug, 78 100.00 ST 3 D 126.35 105.00 36 VAP CC
COOL WATER 4 Aug, 78 100.00 ST 3 G 126.35 105.00 36 YAP Cc
EL SEGUNDO 1 May, 55 100.00 ST 2 G 156.25 175.00 339.98 19 SC Sc
EL SEGUNDO 1 May, 55 100.00 ST 2 0 156.25 175.00 339.98 19 SC SC
Note: A Unit Loading Code of 6 indicates these units have been retired and will not be operated without a 6 month advance notice.
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Utility Service Area: Southern California Edison
Date filed: September, 1967 Fors 1-3A p. 1 of 4
Utility Contact: Ron Schroeder EXISTING AM PLANNED UTILITY OWED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone: (413) 302-9514 Phone: (916) 324-3602
Unit installed Dependable Average Met location
Date Percent Unit Loading Fuel Capacity Capacity Aenuat Energy Air Water
Plant Name and Unit Number Install/Modified Ownership Type Code Typo (MN) (Nw) (GUM) Canty Nsin Region
.......................... ................ ......... .... ....... -.. ......... ---------- ------------- ......................
EL SEGUNDO 2 Aug, 56 100.00 ST 2 G 156.25 175.00 328.04 19 SC SC
EL SEGUNDO 2 Aug, 56 100.00 ST 2 0 156.25 175.00 328.84 19 SC SC
EL SEGUNDO 3 Aug, K 100.00 ST 2 G 342.00 335.00 736.06 /9 SC SC
EL SEGUNDO 3 AUg, 64 100.00 ST 2 O 342.00 335.00 736.06 19 SC SC
EL SEGUNDO 4 Apr, 65 100.00 ST 2 C 34Z.00 335.00 1,066.22 19 SC SC
EL SEGUNDO 4 Apr, 65 100.00 ST 2 0 342.00 335.00 1,066.22 19 SC Sc
ELLWOOD 1 Aug, 74 100.00 CT 5 0 56.70 48.00 1.97 42 S" cc
ELLW70D 1 Aug, 74 100.00 CT 5 G 56.70 46.00 1.97 42 S8A Cc
ETt1MNDil 1 Jul, 53 100.00 ST 2 G 1ZZ.50 132-00 150.09 36 SC SC
ETIMAM 1 Jul. 53 100.00 ST 2 0 122.56 132.00 150.OP 36 SC K
ETIWItlA 2 Nev, 33 100.00 ST 2 G 122.50 132.00 165.51 36 SC SC
ETIVANDA 2 Mov, 53 100.06 ST 2 0 122.50 132.00 /65.S1 36 se st
ETIWAMDA 3 May, 63 100.00 ST 2 8 333.00 320.00 "1.28 36 SC 5C
ETIWANM 3 May, 63 100.00 ST 2 0 333.00 320.00 "1.26 36 SC SC
ETIMANDA 4 Oct, 63 100.00 ST 2 G 333.00 320.00 009.30 36 fC EC
ETIIMNDA 4 Oct, 63 100.00 ST 2 O 333.00 320.00 80.30 36 SC sc
ETIMAMDA 5 Jon, 69 100.00 CT 5 0 138.13 126.00 5.85 36 SC SC
ETItMMDA 5 Jan, 69 100.00 CT 5 G 139.13 MAO 5.85 36 Sc SC
PoRR CONMERs 4 JUL. 69 48.00 ST 1 DO 392.69 376.32 2.309.00 64
FOUR CORNERS 5 Jut, 70 48.00 ST 1 CO 392.69 376.32 2.272.00 64
MIGMGROYE 1 Aug, 52 100.00 ST 2 G 34.50 32.50 3.73 36 SC SC
NIGNG OK 1 Aug, 32 100.06 ST 2 O 34.50 32.50 3.73 36 sC SC
NIGMGOVE 2 Jul, 52 100.00 ST 2 G 34.50 32.50 3.42 36 SC SC
NIGNGOVE 2 Jul, 52 100.00 ST 2 0 34.50 32.50 3.42 36 SC SC
MIGMGROVE 3 Nov, 53 100.00 ST 2 G 50.00 44.50 7.48 36 SC SC
MIGMGROVE 3 Nov, 53 100.00 ST 2 O MOD 44.50 7.48 36 SC SC
MIGMGROVE 4 Oct, 55 100.00 ST 2 G 50.00 44.50 9.19 36 SC se
N1416M 4 Oct, 55 100.00 ST 2 O 50.00 44.50 9.19 36 SC SC
Note: A Unit loading Code of 6 iadicataa these units have been retired and wilt not be operated without a 6 month advance notice.
R �
Utility Service Area: Southern California Edison
Date Filed: September, 1987 A Form R-3A p. 1 of 4
Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone: (818) 302-9514 Phone: (916) 324-3602
Unit Installed Dependable Average Net Location
Date Percent Unit Loading Fuel Capacity Capacity Annual Energy Air Water
Plant Name and Unit Number Install/Modified Ownership Type Code Type (MW) (MW) (GWH) Canty Basin Region
________________ _________ ____ ------- _.__ --------- .......... ............. ------------ .........
HUNTINGTON 1 Jun, 58 100.00 ST 2 G 217.60 215.00 640.42 30 SC SC
HUNTINGTON 1 Jun, 58 100.00 ST 2 0 217.60 215.00 640.42 30 SC SC
HUNTINGTON 2 Dec, 58 100.00 ST 2 G 217.60 215.00 673.88 30 SC SC
HUNTINGTON 2 Dec, 58 100.00 ST 2 0 217.60 215.00 673.88 30 SC SC
HUNTINGTON 3 May, 61 100.00 ST 2 G 217.60 215.00 594.82 30 SC SC
HUNTINGTON 3 May, 61 100.00 ST 2 0 217.60 I 215.00 594.82 30 SC SC
HUNTINGTON 4 Jul, 61 100.00 ST 2 G 217.60 225.00 505.52 30 SC SC
HUNTINGTON 4 Jul, 61 100.00 ST 2 0 217.60 225.00 505.52 30 SC SC
HUNTINGTON 5 Apr, 69 100.00 CT 5 D 138.13 133.00 6.80 30 SC SC
HUNTINGTON 5 Apr, 69 100.00 CT 5 G 138.13 133.00 6.80 30 SC SC
LONG BEACH 8 Dec, 76 100.00 CT 3 D 249.50 226.00 909.50 19 SC SC
LONG BEACH 8 Dec, 76 100.00 CT 3 G 249.50 226.00 909.50 19 SC SC
LONG BEACH 8 Dec, 76 100.00 ST 3 D 85.00 77.00 19 SC SC
LONG BEACH 8 Dec, 76 100.00 ST 3 G 85.00 77.00 19 SC SC
LONG BEACH 9 Apr, 77 100.00 CT 3 D 188.72 170.00 19 SC SC
LONG BEACH 9 Apr, 77 100.00 CT 3 G 188.72 170.00 19 SC SC
LONG BEACH 9 Apr, 77 100.00 ST 3 D 63.28 57.00 19 SC SC
LONG BEACH 9 Apr, 77 100.00 ST 3 G 63.28 57.00 19 SC SC
MANDALAY 1 May, 59 100.00 ST 2 G 217.60 215.00 658.45 56 YAP CC
MANDALAY 1 May, 59 100.00 ST 2 0 217.60 215.00 658.45 56 VAP CC
MANDALAY 2 Aug, 59 100.00 ST 2 G 217.60 215.00 686.63 56 VAP CC
MANDALAY 2 Aug, 59 100.00 ST 2 0 217.60 215.00 686.63 56 VAP cc
MANDALAY 3 Apr, 70 100.00 CT 5 D 138.13 140.00 4.62 56 VAP cc
MOHAVE 1 Apr, 71 56.00 ST 1 CO 458.14 442.40 i 2,504.00 60
MOHAVE 2 Oct, 71 56.00 ST 1 CO 458.14 442.40 2,688.00 60
ORMOND BEACH 1 Dec, 71 100.00 ST 2 G 806.40 750.00 1,949.80 56 VAP CC
ORMOND BEACH 1 Dec, 71 100.00 ST 2 0 806.40 750.00 1,949.80 56 VAP cc
ORMOND BEACH 2 Jun, 73 100.00 ST 2 G 806.40 750.00 1,812.27 56 YAP cc
Note: A Unit Loading Code of 6 indicates these units have been retired and will not be operated without a 6 month advance notice.
Utility Service Arts: Southern California Edison
Date Filed: September, 1987 Fora R-3A p• 1 of 4
Utility Contact: Ron Schroeder EXISTING AND PUNNED UTILITY OWNED TMERYIL RESOURCES CEC Contact: Pat NNwliffe
Phone: (aim) 302.9514 Phone: (916) 324.3602
Unit Installed Dependable Average Met Location
Date Percent Unit Loading Fuel Capacity Capacity Annual Energy Air Water
Plant Name and Unit Number Inatotl/Modified Ownership Type Code Type (NW) (MW) (GUN) County gain Region
...........-•............. ................ ......... .... ---•--- .... ......... .........• ...... ......................
aRllowo KACM 2 Jun, 73 100.00 ST 2 a 806.40 750.00 1,812.27 56 YAP CC
PALO VERGE 1 Feb, a6 15.80 NU 1 MU 217.25 193.05 1,300.00 97
PALO VERGE 2 Sap, 36 15.110 MU i MU 217_25 193.05 1,300.00 97
PALO VERGE 3 Sap, a6 15.80 MU 1 NU 217.25 193.08 1,300.00 97 !
REDONDO 1 Her, 48 100.00 ST 6 6 66.00 74.00 113.73 19 SC SC
REDONDO 1 Her, 43 100.00 ST 6 0 66.00 74.00 83.73 19 SC SC
REDONDO 2 Apr, 48 100.00 ST 6 G 69.00 74.00 60.62 19 SC SC !,
REDONDO 2 Apr, 4a 100.00 ST 6 0 69.00 74.00 60.62 19 SC SC
REDONDO 3 Aug, 49 100.00 ST 6 6 66.00 70.00 64.50 19 SC SC
REDONDO 3 AM, 49 100.00 ST 6 0 ".D0 70.00 64.50 19 SC SC
REDONDO 4 Oct, 49 100.00 ST 6 G 69.00 74.00 73.K 19 SC SC
REDONDO 4 Oct, 49 100.00 ST 6 0 . 69.00 74.00 73.44 19 SC SC '.
REDONDO 5 Oct, 54 100.00 ST 2 G 156.25 175.00 291.24 19 SC SCI,
REDONDO 5 Oct, 54 100.00 ST 2 0 156.25 175.00 291.24 19 SC SC !�
REDONDO 6 JUL, 57 100.00 $T 2 6 163.20 175.00 243.00 19 SC SC
REDONDO 6 Jut, 57 100.00 ST 2 0 163.20 175.OD 243.00 19 SC SC
,REDONDO 7 Feb, 67 100.09 ST 2 6 495-00 480.00 1."2.70 19 SC SC
REDONDO 7 Feb, 67 100.00 ST 2 0 495.00 400.00 1,442.70 19 SC SC
ROMMO a Jut, 67 100.00 ST 2 6 493.00 40.00 1,56a.06 H gC MC
REDONDO a Jul, 67 100.00 ST 2 0 , 495.00 480.00 1,56a.06 19 SC SC
SAN MERIMMIND 1 Jun, 57 100.00 ST 2 6 65.28 63.00 100.13 36 S E SA
SAN OERMARDINO 1 Jun, 57 100.00 ST 2 0 45.29 63.00 105.13 36 SK SA
SAN MERVA DINO 2 Jul, 55 100.00 ST 2 G 65.28 63.00 92.24 36 SBE SA
so DEMANDING 2 Jul, Sa 100.00 ST 2 O 65.28 63.00 92.24 36 SK SA
SAN OMOFRE 1 Jan, 63 80.00 NU 1 NU 364.80 348.80 2,050.00 37 SO so
SAN ONOFRE 2 Aug, a3 75.05 NU 1 NU 845.al 1103.03 5,300.00 37 s0 SO
SAN ONDFRE 3 Apr, 84 75-05 NU 1 MU 2145.51 1110.54 5,300.00 37' so SO
TOTAL Y
25491.38 24627.02 73,382.54 -
Note: A Unit Loading Coda of 6 indicates these units have been retired and will not be operated without a 6 month advance notice. �'
h
Utility Service Area: Southern California Edision
Date Filed: September, 1987 Form R-3A p. 2 of 4
Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone:(818)302-9514 Phone: (916) 324-3602
LEVEL 1 LEVEL 2 LEVEL 3 LEVEL,4
Minimum Generation 25% of Dependable Cap 50% of Dependable Cap 80% of Dependable Cap
-------------------- ------------------'-- --------------------- -----------------------
Capacity Heat Rate Capacity Heat Rate Capacity Heat Rate Capacity Heat Rate
Plant Name and Unit Number (HU) (Btu/kWh) (HU) (Btu/kWh) (HW) (Btu/kWh) (HW) (Btu/kWh)
.......................... ........ ......... ........ --------- ........ ......... -------- ---------
ALAMITOS 1 10 25473 44 12997 87 11250 139 10751
ALAMITOS 1 15 21011 44 12461 87 10576 139 10146
ALAMITOS 2 10 25473 44 12997 87 11250 139 10751
ALAMITOS 2 15 21011 44 12461 87 10576 139 10146
ALAMITOS 3 20 22048 80 12066 160 10456 255 9972
ALAMITOS 3 40 15136 80 11601 160 10290 255 9921
ALAMITOS 4 20 22048 80 12066 160 10456 255 9972
ALAMITOS 4 40 15136 80 11601 160 10290 255 9921
ALAMITOS 5 70 14177 120 11973 240 10489 383 10038
ALAMITOS 5 150 10904 120 11486 240 10065 383 9632
ALAMITOS 6 70 14177 120 11973 240 10489 383 10038
ALAMITOS 6 150 10904 120 11486 240 10065 383 9632
ALAMITOS 7 1 33 66 106
ALAMITOS 7 1 33 66 106
COOL WATER 1 1 73442 16 13040 32 11120 51 10519
COOL WATER 1 21 12159 16 13368 32 10916 51 10189
COOL WATER 2 17 13165 20 12537 40 10830 64 10337
COOL WATER 2 25 11530 20 12224 40 10518 64 9990
COOL WATER 3 6 34 68 IOB
COOL WATER 3 6 34 68 108
COOL WATER 3 50 26 52 83
COOL WATER 3 50 26 52 83
COOL WATER 4 6 34 68 108
COOL WATER 4 6 34 68 108
COOL WATER 4 50 26 52 83
COOL WATER 4 50 26 52 83
EL SEGUNDO 1 10 25725 44 13125 87 11361 139 10857
EL SEGUNDO 1 20 16482 44 12399 87 11010 139 10707
Utility service Area: Southern California Edision
Date Filed: September, 1967 Font R-3A P. 2 of 4
Utility Contact:Rom Schroeder EXISTING AND PLANNED UTILITY OWED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone:(81a)302.9514 Phone: (916) 324-3602
LEVEL I LEVEL 2 LEVEL 3 LEVEL 4
Ninimum�Generation 25% of Dependable Cap 50%of Dependable Cap BOX of Dependablc Cap
.................... ..................... -..-..--._... ....... .......................
Capacity Heat Rate Capacity Neat Rate Capacity Neat Rate Capacity most Rate
Plant Mmw and Unit Number (MY) (RtulkYh) MIA) (RtWkwh) (NM) (Btu/kWh) (HU) (Btu/kWh)
.......................... ........ ......... ........ •------- ......... ........ .........
EL SEGUNDO 2 10 25725 44 13125 a7 11361 139 IMT
EL SEGUNOO 2 20 16452 44 12399 87, 11010 139 MOT
EL SEGUMDO 3 20 222" 84 12027 167 10495 26T t005O
EL SEGUMDO 3 70 13494 84 12521 167 10374 267 9699
EL SEGUNDO 4 20 22266 a4 12027 167 10495 267 10050
EL SEGUMW 4 70 13494 34 12521 16T 10374 267 9699
ELLWXX! 1 1 12 24 38
ELLUM 1 1 12 24 38
ET)WNOA 1 10 22145 33 13139 66 11348 105 10aa9
ETIWNDA 1 20 15966 33 13061 66 11046 105 10621
ETIW MA 2 10 22145 33 13139 66 1134a 105 100"
ETIMAMA 2 20 15966 33 13061 66 11046 105 10621
ETIININDA 3 20 22057 a0 12509 160 10a40 255 10339
ETIW MDA 3 75 11795 80 115" 160 10279 255 9910
ETIWMDA 4 20 22859 a0 12509 160 10640 255 10339
ETIWMIDA 4 75 11795 a0 1-1509 160 10279 255 9910
ETIWNDA 5 1 32 63 100
ETIWMOA 5 1 32 63 100
FOWL CORNERS 4 132 94 IDS 301
FOUR CORNERS 5 132 94 188 301
NIGNGROVE 1 4 35270 a 22569 16 16313 25 14175
MIGNGROVE 1 7 23662 a 21883 16 15714 25 13586
MIGNGROVE 2 4 35270 a 22569 tb 16313 25 14175
NiGNMOVE 2 7 23662 a 21a" 16 15714 25 13586
NIGMGRM 3 5 32671 11 20013 22 14798 35 12945
HIGNGROVE 3 12 23960 11 25103 22 law 35 1"81
NIGmam 4 5 32671 11 2W13 22 14798 35 12945
NIGEGROVE 4 12 23960 11 25103 22 - 1a509 35 16691
Y
K
Utility Service Area: Southern California Edision
Date Filed: September, 1987 Form R-3A p. 2 of 4
Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone:(818)302-9514 Phone: (916) 324-3602
LEVEL 1 LEVEL 2 LEVEL 3 LEVEL 4
Minimum Generation 25% of Dependable Cap 50% of Dependable Cap SOX of Dependable Cap
.................... ..................... -----------------------
Capacity Heat Rate Capacity Heat Rate Capacity Heat Rate Capacity Heat Rate
Plant Name and Unit Number (MW) (Btu/kWh) (MW) (Btu/kWh) (MW) (Btu/kWh) (HW) (Btu/kWh)
________________ ------ ......... ........ --------- -------- --------- ........ .........
HUNTINGTON 1 20 16094 54 11759 107 10570 171 10218
HUNTINGTON 1 30 12599 54 10624 107 9649 171 9359
HUNTINGTON 2 20 16094 54 11759 107 10570 171 10218
HUNTINGTON 2 30 14707 54 118M 107 10240 171 9679
HUNTINGTON 3 90 10681 54 11813 107 10428 171 10029
HUNTINGTON 3 90 10153 54 11211 107 9907 171 9469
HUNTINGTON 4 90 10750 56 11997 112 10424 179 10060
HUNTINGTON 4 90 10153 56 11116 112 9850 179 9446
HUNTINGTON 5 1 33 66 106
HUNTINGTON 5 1 33 66 106
LONG BEACH 8 3 57 113 180
LONG BEACH 8 3 57 113 180
LONG BEACH 8 55 19 38 61
LONG BEACH 8 55 19 38 61
LONG BEACH 9 3 43 85 135
LONG BEACH 9 3 _ 43 85 135
LONG BEACH 9 55 14 28 45
LONG BEACH 9 55 14 28 45
MANDALAY 1 20 16404 54 11528 107 10155 171 9763
MANDALAY 1 24 12589 54 10185 107 9266 171 8977
MANDALAY 2 20 16404 54 11528 107 10155 171 9763
MANDALAY 2 24 12589 54 10185 107 9266 171 8977
MANDALAY 3 1 35 70 ill
MOHAVE 1 140 111 221 353
MOHAVE 2 140 ill 221 353
ORMOND BEACH 1 250 11180 lab 11938 375 10452 599 1OD99
ORMOND BEACH 1 250 10219 lab 10872 375 9669 599 9443
ORMOND BEACH 2 50 20560 188 11938 375 10452 599 10099
f
I
i
Utility Service Area: Southern California Edision
Date Filed: September, 1987 Fong R-3A p. 2 of 4
Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone:(818)302-9514 Phone: (916) 324-3602
LEVEL 1 LEVEL 2 LEVEL 3 LEVEL 4
Miniaaw Generation 25% of Dependable Cap 50% of Dependable Cap 80% of Dependable Cap
-^----------------- --------------------- ..................... -----------------------
Capsefty Hest Rate Capacity Neat Rate Capacity Neat Rate Capacity Meat Rate
Plant Name and Unit Reber (MN) (Btu/kA) (MW) (Btulkwk) (MU) (Btu/kWh) (MM) (StulkWh)
--•....................... ........ ......... ........
ORMONOI KACN 2 250 10219 188 10672 375 9669 599 9K3
PALO VERDE 1 0 48 96 154
PALO VERDE 2 0 48 96 154
PALO VERDE 3 0 48 96 154
REDONDO 1 3 39828 19 16604 37 14518 59 13971
REDONDO 1 8 21302 19 15659 37 13690 59 13173
REDONDO 2 3 37267 19 16335 37 14433 59 13711
REDONDO 2 8 20569 19 15474 3T 13738 59 13300
REDONDO 3 3 39628 18 16646 35 14639 5S 13967
REDONDO 3 8 21302 18 15886 35 13804 55 13169
REDONDO 4 3 37267 19 16335 37 14433 59 Ml
REDONDO 4 8 20569 19 15474 37 13M 59 13300
REDONDO 5 16 25473 K 12997' B7 11250 139 10751
REDONDO 5 15 21011 K 12"1 87 10576 139 10146
REDONDO 6 10 25473 K 12997 87 11250 139 10751
REDONDO 6 15 21011 K 12461 87 10576 139 101"
REDONDO 7 70 13639 120 11517 240 10090 383 96%
REDONDO 7 150 10310 120 10805 240 9570 383 9130
REDONDO 8 7 59960 120 11517 240 10090 ?a 96%
REDONDO 9 15 29135 120 10805 240 9570 383 9130
SAN SERNAROINO 1 7 17856 16 12808 31 10980 50 103"
SAN BERNARDINO 1 17 125% 16 12793 31 10515 5o 97M
SO BERNARDINO 2 7 17856 16 12MG, 31 10980 50 10348
SAX BERNARDINO 2 17 12504 16 12793 31 10515 50 9T70
SAN ONOFNE 1 50 87 174 279
SAN ONOFRE�2 3Dp 201 401 642
SAX OMOFRE 3 _ 300 a 203 _ _ 405 648
4 `�
y
Utility Service Area: Southern California Edison
Date Filed: September, 1987 Form R-3A p. 3 of 4
Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone: (818) 302-9514 Phone: (916) 324-3602
LEVEL 5
Maximum Generation
Start-up Fuel Characteristics
Capacity Heat Rate Fuel Heat content Percent Percent
Plant Name and Unit Number (MW) (Btu/kWh) (MMBtu/start) (Btu/Unit) Grade Ash Sulfur
.......................... -------- --------- .............
ALAMITOS 1 175 10809 2527.10
ALAMITOS 1 175 10143 2527.10 6.00
ALAMITOS 2 175 10809 2527.10
ALAMITOS 2 175 10143 2527.10 6.00
ALAMITOS 3 320 9941 4518.10
ALAMITOS 3 320 9806 4518.10 6.00
ALAMITOS 4 320 9941 4518.10
ALAMITOS 4 320 9806 4518.10 6.00 6 .040 .25
ALAMITOS 5 480 9964 6181.50
ALAMITOS 5 480 9556 6181.50 6.00
ALAMITOS 6 480 9964 6181.50
ALAMITOS 6 480 9556 6181.50 6.00
ALAMITOS 7 147 130.00 5.40 .001 .10
ALAMITOS 7 147 130.00 2
COOL WATER 1 65 10391 748.00
COOL WATER 1 65 10011 748.00 6.00 6 .040 .25
COOL WATER 2 81 10289 923.20
COOL WATER 2 81 9938 923.20 6.00
COOL WATER 3 73 1900.00 5.40 2 .001 .10
COOL WATER 3 73 1900.00
COOL WATER 3 110 20.00
COOL WATER 3 110 20.00 1050.00 1
COOL WATER 4 73 1900.00 5.40
COOL WATER 4 73 1900.00
COOL WATER 4 110 20.00
COOL WATER 4 110 20.00 1050.00
EL SEGUNDO 1 175 1D916 2527.10
EL SEGUNDO 1 175 10683 2527.10 6.00
i
Utility Service Area: Southern Catifornie Edison
Date filed: September, 1967 Form R-3A p. 3 of 4
Utility Contect:Ron Schroeder ENISTING AND PLANNED UTILITY OWNS) TNERNAL RESOURCES CEC Contact: Pat McAuliffe
Phone: (515) 302-9514 Phone: (916) 324-3602
LEVEL 5
Maximum Generation
Start-Up Fuel Characteristics
Capacity Neat Rate Fuel Neat content Percent Percent
Plant Nam and Unit Number (MN) (Btu/kWh) (NIRtu/start) (MAIM grade Ash Sulfur
.......................... ........ ......... ........._.. ............... ..................................
EL SEGUNDO 2 175 10916 252T.10
EL SEGUNDO 2 175 10653 2527.10 6.00 6 .040 .25
EL SEGUNDO 3 335 10059 4518.10
EL SEGUNDO 3 335 9456 4518.10 6.00
EL SEGUNDO 4 335 10059 4518.10
EL SEGIRIDO 4 335 9456 4518.10 6.00
ELLW70D 1 53 5.40
ELLWOOD 1 53
ETIWNDA 1 132 10567 1834.40
ETIWWDA 1 132 10671 1834.40 6.00
ETIWNDA 2 132 10567' 1534.40
ETIMA DA 2 132 10671 1834.40 6.00 6 .004 .25
ETIWNDA 3 320 10306 4518-10
ETIW MDA 3 320 9795 4519-10 6.00
ETIWNDA 4 320 10306 4518.10
ETIVA DA 4 320 9795 4518.10 6.06
ETIt1AN8A 5 142 130.00 5.40 2 .001 .10
EMMA 5 142 130.00
FOUR CORNERS 4 376 5275-00 17.60 22.000 .60
FOUR CORNERS 5 376 5275.00 17.60
NIGNGROVE 1 32 13423 239.90
NIGNGROVE 1 32 12526 239.90 6.00
NIGNGROVE 2 32 13423 239.90
NIGNGROVE 2 32 12526 239.90 6.00 6 .040 .25
N1 3 45 12315 326.90
4GN¢ROVE 3 45 16525 326.90 6.00
NIGNGROVE 4 _ 45 12315 326.90
NiGNGRM 4 45 16525 326.90 6.00
M
Utility Service Area: Southern California Edison
Date Filed: September, 1987 Form R-3A p. 3 of 4
Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone: (818) 302-9514 Phone: (916) 324-3602
LEVEL 5
Maximum Generation
Start-Up Fuel Characteristics
Capacity Heat Rate Fuel Heat content Percent Percent
Plant New and Unit Number (MW) (Btu/kWh) (MMBtu/start) (Btu/Unit) Grade Ash Sulfur
.......................... ........ ......... ............. ----_-......__--__-- .............................
HUNTINGTON 1 215 10169 2989.10
HUNTINGTON 1 215 9268 2989.10 6.00
HUNTINGTON 2 215 10169 2989.10
HUNTINGTON 2 215 9505 2989.10 6.00
HUNTINGTON 3 215 10021 3022.00
HUNTINGTON 3 215 9406 3022.00 6.00 6 .040 .25
HUNTINGTON 4 225 9986 3022.00
HUNTINGTON 4 225 9415 3022.00 6.00
HUNTINGTON 5 147 130.00 5.40 2 .001 .10
HUNTINGTON 5 147 130.00
LONG BEACH 8 60 20.00 5.40
LONG BEACH 8 60 20.00
LONG BEACH 8 80 1000.00
LONG BEACH 8 80 1000.00 1050.00
LONG BEACH 9 60 20.00 5.40
LONG BEACH 9 60 20.00
LONG BEACH 9 60 1000.00
LONG BEACH 9 60 1000.00 1050.00 2 .001 .10
MANDALAY 1 215 9805 Z989.10
MANDALAY 1 215 8936 2989.10 6.00 6 .040 .25
MANDALAY 2 215 9805 2989.10
MANDALAY 2 215 8936 2989.10 6.00
MANDALAY 3 215 130.00 5.40 2 .001 .25
MOHAVE 1 442 6077.00 21.90 10.500 .39
MOHAVE 2 442 6077.00 21.90
ORMOND BEACH 1 750 10279 10302.00
ORMOND BEACH 1 750 9451 10302.00 6.00 6 .040 .25
ORMOND BEACH 2 750 10279 10302.00
Utility Service Area: Southern California Edison
Date filed: September, 1967 Farm R-3A p. 3 of 4
Utility Contect:Ron Schroeder EXISTING AND PLANNED UTILITY OWED TRERNAL RESOURCES CEC Contact: Pat McAutiffo
Phone: (813) 302-9514 Phone: (916) 324-3602
LEVEL 5
Maximum Generation
Start-Up Fuel Characteristics
Capacity meet Rate Fuel Meat content Percent Percent
Plant Name and Unit Number (NY) (Stu/kWh) 0001tu/start) (Rtv/Unit) Grade Ash Sulfur
-------------------------- ........ ......... ............. ..................................................
ORMOND MEACM 2 750 9451 10302.00 6.00
PALO VERDE 1 193
PALO VERDE 2 193
PALO VERDE 3 0
REDONDO 1 74 148" 277.20 -
REDONDO 1 74 13905 277.20 6.00 ,.,
REDONDO 2 74 13510 277.20
REDONDO 2 74 13573 277.20 6.00
REDON0O 3 70 14404 277.20
REDONDO 3 70 13582 277.20 6.00
REDONDO 4 74 13510 277.20
REDOND0 4 74 13573 277.20 6.00
REDONDO 5 175 10009 2527.10
REDONDO i 175 10143 2527.10 6.00 6 .040 .25
REDONDO 6 175 10909 2527.10
REDONDO 6 175 10143 2527.10 6.00
REDONDO 7 4w 93M 6191-50
REDONDO 7 4M 9045 6191.50 6.00
REDOND0 8 480 9m 6181-50
REDONDO 8 4E0 9045 6191.50 6.00
SAN BERNARDINO 1 63 10215 723.10
SAIL BERNARDINO 1 63 9596 723.10 6.00 6 .040 .25
SAN RERNAROINO 2 63 10215 723.10
SAN RERMARDINO 2 63 95% 723.10 6.00
".00A E 1 349 2.55
.04 Own:j 803 2.55
FAN QIl "i 3 _ ;11 2.55
4
{
Utility Service Area: Southern California Edison
Date Filed: September, 1987 Form R-3A p. 3 of 4
Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone: (818) 302-9514 Phone: (916) 324-3602
Fixed Variable Instant
0 & M costs 0 & M Costs Capital Costs Expenditures
Plant Name and Unit Nuiber (1986f/MWh) (1986$/MWh) (1985S) As of 12/31/85 Status
.......................... ............ ........... ------
ALAMITOS 1 11000.00 .10
ALAMITOS 2 11000.00 .10
ALAMITOS 3 11000.00 .10
ALAMITOS 4 11000.00 .10
ALAMITOS 5 11000.00 .10
ALAMITOS 6 11000.00 .10
ALAMITOS 7 11000.00 .10
AXIS (COMB. TURBINE) 2CT .00
AXIS (STEAM) 1 .00
COOL WATER 1 9000.00 .60
COOL WATER 2 9000.00 .60
COOL WATER 3 6200.00 .90
COOL WATER 3 6200.00 .90
COOL WATER 4 6200.00 .90
COOL WATER 4 6200.00 .90
COOL WATER COAL GAS 1 .00
EL SEGUNDO 1 11000.00 .10
EL SEGUNDO 2 11000.00 _ .10
EL SEGUNDO 3 11000.00 .10
EL SEGUNDO 4 11000.00 .10
ELLWOOD 1 4400.00 .10
ETIWANDA 1 9000.00 .60
ETIWANDA 2 9000.00 .60
ETIWANDA 3 9000.00 .60
ETIWANDA 4 9000.00 .60
ETIWANDA 5 4400.00 .10
FOUR CORNERS 4 25300.00 1.70
FOUR CORNERS 5 25300.00 1.70
HIGHGROVE 1 9000.00 .60
HIGHGROVE 2 9000.00 .60
Utility Service Area: Southern Catifornia Edison
Date filed: September, 1967 Fong R-3A p. 3 of 4
Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY 00" THERMAL RESOURCES CEC Contact: Pat McAutiffe•
Phone: (818) 302-9514 Phone: (916) 324-3602
Fixed Variable Instant
O t If Costs 0 It M Costs Capital Costs Expenditures
Plant Name and Unit Kober (19865/HUh) (196"MA) 0965S) As of 12/31/85 Statue
.......................... ------------ ........... ------------- .............. ......
NIGNGROVE 3 9DO0.00 .60
MIGMGROVE 4 90DO.00 .60
HUNTINGTON 1 11000.00 .10
HUNTINGTON 2 11000.00 .10
HUNTINGTON 3 11000.00 .10
HUNTINGTON 4 11000.00 .10
HUNTINGTON 5 11000.00 .10
LONG REACH 8 9000.00 .30
LONG REACH 8 9000.00 .30
LONG REACH 9 9000.00 .30
LONG BEACH 9 9000.00 .30
MANDALAY 1 11000.00 .10
NANDALAY 2 11000.00 ./0
NANDALAY 3 4400.00 .10
MOHAVE 1 25300.00 1.70
MOOAVE 2 25300.00 1.70
ORIION11 REACH 1 11000.00 .10
OHM REACH 2 11000.00 .10
PALO VERDE 1 .00
PALO VERDE 2 .00
PALO VERGE 3 .00
PEBBLY BEACH-DIESEL. 7 .00 I
PEBBLY BEACH-DIESEL a .OD
PEBBLY BEACH-DIESEL 10 .00
PEBBLY BEACN-DIESEL it .00
PEBBLY BEACH-DIESEL 12 .OD
REDONDO 1 11OD0.00 .10
REDONDO 2 11000.00 .10
REDONDO 3 11000.00 .10
REDONDO 4 .10
i
Utility Service Area. southern California Edison
Date Filed: September, 1987 Form R-3A p. 3 of 4
Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES CEC Contact: Pat McAuliffe
Phone: (818) 302-9514 Phone: (916) 324-3602
Fixed Variable Instant
a & M costs 0 & M Costs Capital Costs Expenditures
Plant Name and Unit Number (1986S/MWh) (1986$/MWh) (1985S) As of 12/31/85 Status
-------------------------- ------------ .......---- --"'-------- -------------- ......
REDONDO 5 11000.00 .10
REDONDO 6 11000.00 .10
REDONDO 7 11000.00 .10
REDONDO 8 11000.00 .10
SAN BERNARDINO 1 9000.00 .60
SAN BERNARDINO 2 9000.00 .60 i
SAN ONOFRE 1 61500.00 .OD
SAN ONOFRE 2 61500.00 .00
SAN ONOFRE 3 61500.00 .00
Utility Service Area: Southern California Edison
Date Filed: September, 1987 Form R-38 p. 1 of 2
Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED MYDRS RESOURCES CEC Contact: Pat McAuliffe
Phone: (918) 302-9514 Phone: (916) 324-3602
instetted Dependable Average Met Location
Date Percent Capacity Capacity Amuat Energy Air Water
Ptant Name and Unit Huber Install/Hodified Ownership (NW) (MU) (GUM) County Basin Region
-------------------------- ---------------- --------- --------- .......... ............. --- ------------------
BIG CREEK 1 1 Nov, 13 100.00 14.00 17.50 10 SJV Si
BIG CREEK 1 2 Mow, 13 100.00 14.00 17.00 575.00 10 SJV SJ
BIG CREEK 1 3 Jut, 23 100.00 14.00 17.20 10 SJV SJ
BIG CREEK 1 4 Jun, 25 100.00 28.00 31.20 10 SJV SJ
BIG CREEK 2 3 Dec, 13 100.00 14.00 15.80 10 SJV SJ
BIG CREEK 2 4 Jan, 14 100.00 14.00 15.60 505.00 10 SJV Si
BIG CREEK 2 5 Feb, 21 100.00 17.50 16.90 .10 SJV SJ
BI6 CREEK 2 6 Her, 25 100.00 17.50 15.30 10 SJV SJ
BIG CREEK 2A 1 Aug, 28 MOO 40.00 46.30 370.00 10 SJV SJ
BIG CREEK 2A 2 Dec, 28 100.00 55.00 49.20 10 SJV SJ
9I6 CREEK 3 1 Oct, 23 100.00 25.00 34.50 ill SJV Si
BIG CREEK 3 2 Sep, 23 100.00 25.D0 34.50 850.00 Ill SJV SJ
BIG CREEK 3 3 Oct, 23 100.00 25.00 34.30 ill SJV Si
BIG CREEK 3 4 Apr, 48 100.00 36.00 40.50 ill SJV Si
3I6 CREEK 3 5 Feb, 80 100.00 36.45 38.10 ill SJV SJ
BIG CREEK 4 1 Jun, 51 100.00 50.00 50.10 465.00 Ill SJV Si
BIG CREEK 4 2 Jul, 51 100.00 42.00 50.10 ill SJV Si
BIG'CREEK 8 1 Aug, 21 100.00 27.00 25.30 350.00 10
BIG CREEK 8 2 Jun, 29 100.00 31.50 38.70 10
BISHOP CREEK 2 1 Nov, 08 MOO 2.50 2.50 14
BISHOP CREEK 2 2 Nov, 08 100.00 2.50 2.50 40.00 14
BISHOP CREEK 2 3 Jun, 11 100.00 2.32 2.50 14
BISHOP CREEK 3 1 Jury 13 100.00 2.75 2.60 14
BISHOP CREEK 3 2 Jun, 13 100.00 2.20 2.60 40.00 14
BISHOP CREEK 3 3 Jun, 13 100.00 2.20 2.70 14
BISHOP CREEK 4 1 Sep, 05 100.00 1.00 1.00 14
BISHOP CREEK 4 2 Sep, 05 100.00 1.00 1.00 51.00 14
BISHOP CREEK 4 3 Jun, 06 100.00 1.75 2.00 14
BISHOP CREEK 4 4 Oct, 07 _100.00 1.75 2.00 14
BISHOP CREEK 4 5 Jun, 09 100.00 - 1.75 2.00 14
V
1 µ
Utility Service Area: Southern California Edison
Date Filed: September, 1987 Form R-38 p. 1 of 2
Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED HYDRO RESOURCES CEC Contact: Pat McAuliffe
Phone: (818) 302-9514 Phone: (916) 324-3602
Installed Dependable Average Net Location
Date Percent Capacity Capacity Annual Energy Air Water
Plant Name and Unit Number Install/Modified Ownership (MW) (MW) (GWH) County Basin Region
.....................----- ---------------- ......... ......... .......... ...-....----- ......................
BISHOP CREEK 5 1 May, 43 100.00 2.00 2.00 23.00 14
BISHOP CREEK 5 2 Jun, 19 100.00 1.50 1.80 14
BISHOP CREEK 6 1 Mar, 13 100.00 1.60 2.00 11.00 14
SOREL 1 Dec, 04 100.00 3.00 2.10 15
SOREL 2 Dec, 04 100.00 3.00 2.50 65.00 15
SOREL 3 Jan, 32 100.00 6.00 6.40 15
FONTANA 1 Dec, 17 100.00 1.47 .90 8.00 36
FONTANA 2 Dec, 17 100.00 1.47 .98 36
KAWEAH 1 1 May, 29 100.OD 2.25 2.25 13.00 54 TB
KAWEAH 2 2 Sep, 29 100.00 1.80 2.05 13.00 54
KAWEAH 3 1 May, 13 100.00 1.40 2.40 25.00 54
KAWEAH 3 2 May, 13 100.00 1.40 2.10 54
KERN RIVER 1 1 May, 07 100.00 6.20 6.20 15 '
KERN RIVER 1 2 Jun, 07 100.00 6.20 6.20 180.00 15
KERN RIVER 1 3 Jul, 07 100.00 6.20 6.20 15
KERN RIVER 1 4 Jun, 07 100.00 6.20 6.20 15
KERN RIVER 3 1 May, 21 100.00 16.00 18.40 180.00 15
KERN RIVER 3 2 Mar, 21 1DO.00 16.00 18.40 15
LUNDY 1 Dec, 11 100.00 1.50 1.50 9.00 26 SC
LUNDY 2 Feb, 12 100.00 1.50 1.50 26 Sc
LYTLE CREEK 1 Oct, 04 100.00 .20 .34 4.00 36 SC SC
LYTLE CREEK 2 Sep, 04 100.00 .25 .34 36 SC SC
MAMMOTH POOL 1 Mar, 60 100.00 84.28 93.50 610.00 20
MAMMOTH POOL 2 Mar, 60 100.00 64.68 93.50 20
MILL CREEK 1 1 Sep, 93 100.00 .80 .94 5.00 36
MILL CREEK 2 1 Aug, 04 100.00 i .25 .32 36
MILL CREEK 3 3 Mar, 03 100.00 1.00 .89 16.00 36
MILL CREEK 3 4 Jan, 04 100.00 1.00 .89 36
MILL CREEK 3 5 Mar, 04 100.00 1.00 .89 36
ONTARIO 1 1 Dec, 02 100.00 .20 .30 19
Utility Service Area: Southern California Edison
Date Filed: September, 1967 Fora R-39 p. 1 of 2
Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY CUM HYDRO RESOURCES CEC Contact: Pat McAuliffe
Phone: (818) 302-9514 Phone: (916) 324.3602
Instalted Dependable Average Net Location
Date Percent Capacity Capacity Amumt Energy Air Pater
Plant Name and Unit Number Install/Modified Ownership (MN) iMH) (GWH) County Basin Region
-'------------------------ ................ --------. --------- ---------- ............. ---,..._-------------- I
ONTARIO 1 2 Dec, 02 100.00 .20 .30 4.00 19
ONTARIO 1 3 Dec, 02 100.00 .20 .30 19
ONTARIO 2 1 Jun, 63 100.00 .32 .33 2.00 19
POOLE 1 Jun, 24 100.00 10.00 10.00 29.00 26 !
PORTAL 1 Dec, 56 100.00 10.00 10.42 55.00 10 !i
RUSH CREEK 1 Oct, 16 100.00 4.40 4.50 49.00 26
RUSH CREEK 2 Dec, 17 100.00 4.00 5.50 26
SAN GORGOIIO 1 1 Dec, 23 100.00 1.50 1.50 3.00 33
SAN GORGOIIO 2 1 Dec, 23 100.00 .94 .70 33
SANTA AMA 1 1 Feb, 99 100.00 .80 1.00 36
SANTA AMA 1 2 Feb, 99 100.00 .80 1.00 12.00 36
SANTA ANA 1 3 Jan, 99 100.00 .80 .92 36
SANTA ANA 1 4 Jan, 99 1OO.OD .80 .92 36
SANTA AMA 2 1 Jun, 05 IOO.00 .40 .70 5.00 36
SANTA ANA 2 2 May, 05 IOD.00 .40 .69 36
SANTA AMA 3 1 Apr, 47 100.00 1_20 1-73 5.00 36
SHAVER MICRO t Aug, 83 100.00 .02 10
SIERRA 1 Jan, 22 100.00 .24 .37 4.00 19
SIERRA 2 Feb, 22 100.00 .24 .37 19
TILE RIVER 1 Sep, 09 100.00 1.00 1.25 54 SJY TB
TULE RIVER 2 Sep, 09 100.00 1.00 1.25 54 SJY In
TOTAL
827.28 943.24 4,576.00
e
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h
Utility Service Area: Southern California Edison
Date Filed: September, 1987 form R-30 p. 2 of 2
Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED HYDRO RESOURCES CEC Contact: Pat McAuliffe
Phone: (818) 302-9514 Phone: (916) 324-3602
Fixed Variable Instant
O&.M Costs O&.M Costs Capital Costs Expenditures
Plant Name and Unit Number (1986$/Mh) (1986$/MWh) (1985$) As of 12/31/85 Status
......".................. ........... ...... --------•---•- ------
BIG CREEK 1 1 15100.00 .00
BIG CREEK 1 2 15100.00 .00
BIG CREEK 1 3 15100.00 .00
BIG CREEK 1 4 15100.00 .00
BIG CREEK 2 3 15100.00 .00
BIG CREEK 2 4 15100.00 .00
BIG CREEK 2 5 15100.00 .00
BIG CREEK 2 6 15100.00 .00
BIG CREEK 2A 1 15100.00 .00
BIG CREEK 2A 2 15100.00 .00
BIG CREEK 3 1 15100.00 .00
BIG CREEK 3 2 15100.00 .00
BIG CREEK 3 3 15100.00 .00
BIG CREEK 3 4 15100.00 .00
BIG CREEK 3 5 15100.00 .00
BIG CREEK 4 1 15100.00 .00
BIG CREEK 4 2 15100.00 .00
BIG CREEK 8 1 15100.00 .. .00
BIG CREEK 8 2 15100.00 .00
BISHOP CREEK 2 1 15100.00 .00
BISHOP CREEK 2 2 15100.00 .00
BISHOP CREEK 2 3 15100.00 .00
BISHOP CREEK 3 1 15100.00 .00
BISHOP CREEK 3 2 15100.00 .00
BISHOP CREEK 3 3 15100.00 .00
BISHOP CREEK 4 1 15100.00 .00
BISHOP CREEK 4 2 15100.00 .00
BISHOP CREEK 4 3 15100.00 .00
BISHOP CREEK 4 4 15100.00 .00
BISHOP CREEK 4 5 15100.00 .00
.q
Utility Service Area: Southern California Edison
Date Filed: September, 1987 Form R-31 p. 2 of 2
Utility Contact-Ron Schroeder EXISTING AND PLANNED UTILITY OWNED WORD RESOURCES CEC Contact: Pat McAutiffe
Phone: (815) 302-9514 Phone: (916) 324-3602
Fixed Variable Instant
OR.N Costs OZ." Costs Capital Costs Expenditures
Plant Name and unit Number (19865/)RNh) (19US/Mh) (1985S) As of 12/31/85 Status i
..- ----------- ----------- ----"------- -------------- ------
BISHOP CREEK 5 1 15100.00 .00
BISHOP CREEK 5 2 15100.00 .00
BISHOP CREEK 6 1 15100.00 .00
MOREL 1 15100.00 .00
BOREL 2 15100.00 .00
BOREL 3 15100.00 .00
FONTANA 1 15100.00 .00
FONTANA 2 15100.00 .00
KAWEAN 1 1 15100.00 .00
KAWEAB 2 2 15100.00 .00
XANEAN 3 1 15100.00 .00
KA{EAN 3 2 15100.00 .00
KERN RIVER 1 1 15100.00 .00
KERN RIVER 1 2 15100.00 .00
KERN RIVER 1 3 15100.00 .00
KERN RIVER 1 4 15100.00 .00
KERN RIVER 3 1 15100.00 .00
KERN RIVER 3 2 15100.00 .00
LUNDY 1 15100.00 .00
LUNDY 2 15100.00 .00
LYTLE CREEK 1 15100.00 .00
LYTLE CREEK 2 15100.00 .00 N
HAHNOTH POOL 1 15100.00 .00
• NAMWN POOL 2 151OO.OD .00
HILL CREEK 1 1 .00
MILL CREEK 2 1 15700.00 .00
MILL CREEK 3 3 15100.00 .00
MILL CREEK 3 4 15100.00 .00
MILL CREEK 3 5 15100.00 .00
ONTARIO 1 1 15106.00 .00
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Utility Service Area: Southern California Edison
Date Filed: September, 1987 Form R-38 p. 2 of 2
Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED HYDRO RESOURCES CEC Contact: Pat McAuliffe
Phone: (818) 302-9514 Phone: (916) 324-3602
Fixed Variable Instant
09.M Costs O&.M Costs Capital Costs Expenditures
Plant Name and Unit Number (1986$/MWh) (1986$/MWh) (1985S) As of 12/31/85 Status
.......................... ........... ........... ............. -------------- ......
ONTARIO 1 2 15100.00 .00
ONTARIO 1 3 15100.00 .00
ONTARIO 2 1 15100.00 .00
POOLE 1 15100.00 .00
PORTAL 1 15100.00 .00
RUSH CREEK 1 15100.00 .00
RUSH CREEK 2 15100.00 .00
SAN GORGONIO 1 1 15100.00 .00
SAN GORGONIO 2 1 15100.00 .00
SANTA ANA 1 1 15100.00 .00
SANTA ANA 1 2 15100.00 .00 '
SANTA ANA 1 3 15100.00 .00
SANTA ANA 1 4 15100.00 .00
SANTA ANA 2 1 15100.00 .00
SANTA ANA 2 2 15100.00 .00
SANTA ANA 3 1 15100.00 .00
SHAVER MICRO 1 15100.00 .00
SIERRA 1 15100.00 .00
SIERRA 2 15100.00 .00
TULE RIVER 1 15100.00 .00
TULE RIVER 2 15100.00 .00
i
f
Udly Service Area: Scutwn Callonris Edson Form R-30
Dale Fled: Sep-87 CEC ca tact Pat MwAuWfe
Utility Coofact Ron Schroeder MONTHLY AND ATRMIAL HYDRO VAWAY M Phone: (916) 324-3602
Big Creels Syslem
I` 1977 . Dry Year Average Year' 1980 - Wet Year
li
l Total TOW Total
Capacity (MW)* Energy Capacity (MIN) Energy Capacity (MW) Energy
Monde R-of- R Maximum (GWh) R-of- R Maximum (GWh) R-of- R Maximum (GWh)
January 53 111 976 230 480 699 403
February 44 so 978 208 460 657 426
t March 22 291 980 349 620 732 495
April 18 300 989 366 625 653 464
May 28 466 1003 483 626 730 486
June 709 460 1009 480 680 734 617
July 228 382 1009 463 690 736 538
Au" 197 249 1006 397 620 734 486
Sapbnrnber 87 217 994 374 400 732 353
Oclaber 44 84 978 246 250 713 259
November 51 112 973 195 210 610 231
December 121 107 974 214 too 686 212
Antral Tod 1072 4005 4870
AMnough historical Words are not avalable so desemlrte the R-of-R and Pondage Capadyy,
it fs reesarraEfe b assume that In R-of-R capacity was haigndlcard
"Asswnse EisMood Ponerlrasee(Befeare Meadow)aline.Bawd an 6year aplYrnkaBon nnodeL
Also assumes addliond upgrades and improvarranls since 1930.
r
'U811ty Service Area: Southern California Edison Form R-3D
Date Flied: Sep-87 CEC contact:Pat MaeAultffe
Utility Contact: Ron Schroeder MONTHLY AND ANNUAL HYDRO VARIATION Phone: (916) 324-3602
Big Creek System
Average Year'
Total Total Total
Capadty (MIN) Energy Capacity (MW) Energy Capacity (MW) Energy
Month R-of- R Maximum (GWh) R - of- R Maximum (GWh) R - of- R Maximum (GWh)
January 8 f476 183.
February 9 1481 142
March 183 1482 346
April 232 1484 398
May 372 1502 479
June 327 1'520 545
July 197 ' 1623 534
August 31 1518 445
September 114 1511 432
October 9 1492 273
November 8 1473 190
December 5 1472 172
Annual Total 4138
Assumes Eastwood Powerhouse(Balsam Meadow)and Big Creek Expansion Project online.Based on 6 year optimization model.
II
Udit Service Area: Southern CWkrnfa Edson Form R•30 '
Dab Fled: Sep•67 CEC contact Pat MeeAift
UYrity C~. Ron Schroeder �N/
a MONTHLY AND ANA� ION VARIAT Phone: (916) 324.3602
Southern p
Average Year Average Year
Tod Total
cap" (MW) Energy Capacity (MW) Energy
Month R - of- R' Maximum (GWh) R - of- R' Maximum (GWh)
January 102 47 53 17
February 102 48 53 15
March 102 57 53 18
April 102 60 S3 20
May 102 65 53 29
June 102 61 S3 33
July 102 56 53 33
August 102 56 53 29
September 102 38 53 24
COAM 102 35 53 19
November 102 35 53 17
December 102 39 53 17
Muni Total 597 271
'A11 energy is R-of- R.
r
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Utility Service Area: Southern California Edison Form R-3E p. 1 of 2
Date Filed: Sep-87 CEC contact.Pat McAuliffe
Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED RESOURCES Phone: (916) 324-3602
1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
Actual Actual Actual'
Capacity (MW)
Nuclear 1962 1962 2155 2348 2541 2641 2541 2541 2541 2541 2541 2541 2541 2541 2541 2541
Coal — Conventional 1621 1615 1615 1615 1 61 5 1615 1615 1615 1615 1615 1615 1616 1616 1615 1615 1615
—Advanced 100 100 100 100 100 100 100 100 100 100
01 and Gas Steam 8672 8672 8380 8116 7076 7076 7076 7076 7076 7076 7202 7522 7522 7786 7786 7786
Combustion Turbine 580 580 680 580 580 580 580 580 580 580 580 580 580 580 580 580
Combined Cycle 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042 1042
Hydro 941 942 948 949 1150 1159 1159 1159 1159 1159 1159 1181 1327 1393 1667 1667
Battery Storage 0 0 0 0 0 0 10 10 10 10 10 10 10 10 10 10
Pumped Storage 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL. 14818 14813 14720 14650 14004 14013 14123 14123 14123 14123 14249 14591 14737 15067 15341 16341
'1984 - 1986 data from Peak Day reports
thMlty Service Area: Sou*wn Ca1bNa Edison Foie R-3E p.2 of 2
Daft Food: Sep-87 CEC oeneat Pat&kA ulm
Umy cmtw: RolSdwooder EXISTIFW AND "WED UTILITY OWNED RESOURCES Phone: (916) 324.3602
1984 1965 lose 1987 too$ 1959 logo 1991 1992 1993 1994 1995 1096 1997 1998 toss
Actual Actual Actual'
Gerwallon(GWh)
I Nuclei 7239 8421 11939 12556 14071 15487 14937 14136 14310 14271 14270 14272 14315 14265 14272 14276
Coal- Conventional 9642 5909 10057 10201 9995 9325 92tS 9719 9533 9540 gels 9613 959a 9443 9689 9604
-Advanood $98 662 501 570 503 564 541 $64 503 563
O9adGMSOM 20945 27t88 17423 24980 16317 9921 8542 7887 9220 11181 12460 14269 14901 17299 15865 17483
Combseon Turtles 21.0 40.0 50.0 30.0 3t.0 0.1 0.0 0.1 0.1 0.3 0.4 0.6 0.6 0.6 0.6 2.3
CM*WadCycle 945 1667 1119 1121 994 475 482 352 502 320 956 532 822 204 843 076
NY" 5459 4417 5784 3418 4520 4874 4874 4974 4674 4874 4874 4874 4915 4997 5007 8007
so"SW"v 0.0 0.0 0.0 0.0 0.0 0.0 -3.5 -2.1 -1.7 -1.2 -1.3 -1.0 -1.8 -1.8 -1.6 -1.4
Puergatism aye 0.0 0.0 0.0 0.0 00 0.0 0 O 00 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0
MIAL 44454 47642 46372 52306 45428 39052 38545 37538 38938 40755 42680 44123 45091 46771 47181 47790
• 1964- 19M Oda from ADS7 Report
•1967 and 1909 Dots tom Fuel 1 Purchased Power Budget Report
. 1
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Utility Service Area: Southern California Edison Form R-4A p. 1 of 2
Date Fled: Sep-87 CEO contact Pat McAuliffe
Utility Contact: Ron Schroeder QUALIFYING FACILITIES AND PRIVATE SUPPLY Phone: (916) 324-3602
Qualifying 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
Facilities (MW) Actual Actual Actual
Fossil Cogeneration 66 266 411 467 1242 1657 1664 1742 1742 1742 1742 1742 1742 1742 1742 1742
Nonfossil Cogen
Biomass 12 19 45 91 175 204 290 307 307 318 318 318 318 318 318 318
Geothermal 6 13 100 134 222 332 479 483 483 500 516 541 541 541 541 541
Wind 19 46 84 93 98 111 117 117 117 117 1-17 117 117 117 117 117
Solar 1 15 45 105 169 181 195 202 205 1205 205 205 205 265 205 205
As Available 0 0 26 37 48 63 64 64 64 64 64 64 '64 64 64 64
Hydro 41 44 64 49 49 49 49 49 49 49 49 49 49 49 49 49
Total 145 403 775 976 1993 2597 2858 2964 2967 2995 3011 3036 3036 3036 3036 3036
UWy Sewfco Ama: Sousrm California Edlsan Form R-4A P. 2 of 2
Dab Find: SOP-87 CEO ox4ect Pat McAuMNa
U"Y Contact Ran Sdsoedx 0UALWYNG FACUMES APO PRNATE SUPPLY Pfrom: (916) 324-3602
Qualifying 1984 toss 1986 1987 lose 1989 1990 1991 1292 1993 1994 4995 1996 1A97 1998, 1999
Facilises (GWh) Acbai Adual Ac
Foul Cogumation 593 1857 3278 3508 8032 11280 11868 12479 12642 12607 12607 12807 12642 12607 t2607 12607
Blarms as 146 229 S99 1037 1186 1599 t789 1804 1826 1845 1345 1849 1845 1545 1845
Geosbmal 44 1,48 548 toss 1672 2456 3370 3433 3442 3492 3566 3701 3782 3774 3774 3774
I
wind 64 204 672 ell 644 705 756 757 759 757 757 757 759 757 757 757
Saar 2 is 48 235 327 387 419 438 449 460 450 450 451 450 450 450
F%w Case 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Hydro 130 194 104 17S 173 172 172 172 172 172 172 172 172 172 172 172
As AvasadN 0 0 677 914 1117 1490 1556 1561 1573 1576 1551 1585 1394 15s5 15eS less
Tool 901 2649 5556 7135 12952 1767E 19740 20629 20846 20870 20978 21117 21249 21190 21190 21190
Utility Service Area: Southern Cal 1folnia Ediam Fares R-40
Date Filed: Septeeber 1987 COST OF OIIALIFYING FACILITIES PURCHASES CEC contact: Pat McAuliffe
Utility Contact: Ran Schroeder CAPACITY Phone: (916)324-3602
Phone: (E18) 302-9514 (NOMi.t S - adlliorn)
1984 19115 1936 1987 198E 1989 1990 1991 1992 1993 1994 1995 1996 1997 19M 1999
COR LIFTING FACILITIES Actual Actual Actual
....................................... .....................................................................................................................
Ca9eneration 5.05 30.7E 64.5E 78 159 262 273 m3 287 235 289 292 297 293 299 300
Rotas 1.26 1.77 4.7a 13 20 24 34 39 40 42 42 43 45 44 43 44
Ceothersrl 0.61 1.62 12.35 20 31 51 73 75 75 76 79 82 a5 85 a5 a5
Wind 0.43 2.79 6.08 7 1 2 2 2 3 3 4 6 9 9 ID 10
Soler 0.04 0.55 2.02 5 7 9 10 10 11 11 11 11 11 11 11 11
Hydro 1.43 2.22 2.a0 3 1 2 2 2 2 2 2 3 5 5 5 5
....................................... .....................................................................................................................
TOTAL 11.82 39.73 94.61 126 249 350 394 411 413 422 427 437 452 452 453 455
ENERGY
(N.Imi S - Nitlians)
19" 1985 1956 1967 19W 1989 1990 1991 1992 1993 1994 1995 1996 1997 19M 1999
Actual Actual Actual
Co9aKratien 31.53 82.89 126.10 139 297 450 537 619 684 725 792 ua 913 900 1,062 1.122
8i.ss 3.64 3.50 14.99 47 85 103 141 165 178 192 206 221 228 217 205 2w
Geothe.t 2.20 9.99 37.93 68 106 194 281 304 330 362 396 444 449 4" 466 416
wind 4.53 19.54 42.00 39 44 52 59 62 67 71 72 66 59 60 64 64
sater 0.09 1.45 2.53 14 24 31 33 35 37 33 40 40 Q 35 34 36
Hydro 7.30 10.31 12.04 14 16 23 25 27 29 30 33 34 37 38 39 37
..................................... ......--.............--........
TOTAL 49-29 132.68 235.54 321 572 8E3 1.076 1,212 1.325 1,418 1.539 1,653 1.727 1,794 1,870 1,aa3
U"Service Area: Southern CaMorria Eisen Forth R-SA p. 1 of 3
Dale Filed: Sap-87 CEC oattact At Alwaado
UMity Contact: Pon Schroeder INTERUTILITY EXPORT TRANSACTIONS Phone: (016) 324-3152
t984 1985 toss 1987 1988 1989 1990 1091 1992 1993 1994 1995 1096 1997 1998 1990
Actual Actual Actual
Firm Export
A. Capacity (MW)
Na6awst- 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Southwest 0 0 0 0 a 0 O 0 O 0 a 0 0 a 0 a
CaMon"- 2 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 0
Other-3 0 0 0 0 0 0 0 0 0 0 0 0 0 6 0 0
- - - - - - - - - - - - - - - -
Total Finn Export 0 0 0 0 a 0 0 a 0 0 0 0 0 0 0 0
B.Energy(GWh)
Northwest- t 2S 8s5 955 803 74 73 132 198 231 229 229 229 3E4 538 662 719
Southwest 0 O 0 0 0 0 a a 0 0 0 0 0 0 0 0
Cailornia- 2 4189 4075 sate 4758 5189 4552 4455 4455 4455 4882 4870 4546 4573 4216 4216 4222
Other-3 809 1569 983 Isis 2037 2031 2031 2031 2032 2031 2031 2031 2032 2031 2031 2031
Total Firm Export 5023 6529 6954 7177 7300 6666 Gets 6684 6718 7142 7130 6806 6959 6785 6909 6972
C.Total Cost in 4aa0
Nor6wreat- 1 0 0 0 0 O a 0 0 0 0 0 0 0 0 0 0
Sodwut 0 0 a 0 0 0 0 0 0 0 0 0 0 0 0 a
CaMlornia- 2 0 0 0 O O 0 0 0 0 0 0 0 0 0 0 0
ON W-3 23283 50820 22206 31530 59186 65529 71057 76748 84459 89757 99189 106667 116253 125366 136586 147606
- - - - - - - - -- - - - - - - -
Told Cost;00D 23283 50820 22206 31530 59186 65529 71057 76748 84459 89757 99188 106667 116253 125366 136586 147806
I-NW Contact Return o61lgaMorns a Capadg for Energy Exha get,
2-CDWR a MIND
3-MAisceKansous Interchange i Sales to Others
Utility Service Area: Southern California Edison Form R-SA p. 2 Of 3
Date Filed: Sep-87 CEC contact:AI Alvarado
Utility Contact: Ron Schroeder INTERUTILITY EXPORT TRANSACTIONS Phone: (916) 324-3152
1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
Actual Actual Actual
Nonfirm Exports
A. Energy (GWh)
Northwest 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0
Southwest 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
California 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Total Nonfirm Export 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Costs (A) in $rMWh
Northwest 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Southwest 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
California 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0:00 0.00 0.00
Total Cost$000 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0
i
UWy Sendw Area: SOUfwn CaMmin Edam
Dab Fied: Sep-87 Form R3A p.3 Of 3
CEO contact At A 2
Utlity Contact Ron Schroeder DITERUTILITY EXPORT TRANSACTIONS Phan: (916) 34-152
1984 1985 1986 1247 1983 1969 1990 1991 1992 1993 1994 1995 1996 1997 1995 1999
Actual AcWI Aclwl
Firm Exports
A. Capa ft (MM
Northwest- 1 0 0 0 O O 0 0 0 0 0 0 O 0 0 0 0
SouBnrest 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0
CaYbda- 2 0 0 0 0 0 0 0 0 0 0 0 0 O 0 O 0
Other-3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Total Firm Export 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
8.Eneryy(GWh)
Nor88wat- 1 25 885 956 803 74 73 t32 t96 231 229 229 229 354 53S 662 719
Soutweet 0 0 0 0 0 0 0 O 0 O 0 0 0 0 O 0
Camornia- 2 4139 4075 5016 4758 St89 4552 4455 4455 4455 4882 4870 4546 4573 4216 4216 4222
01wr-3 809 1565 982 tots 2037 2031 2031 203T 2032 2031 2031 2031 2032 2031 2031 2031
Tad Firm Export 5023 6529 6954 7177 7300 $656 Gets 5684 6718 7142 7130 6806 6959 6736 6909 6972
Non)&m Exports
A.EnwW(GWh)
NMBwest 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0
SoUrwut O 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0
CaYtgrda 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0
r Tod NMr6rm Export 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
1-NW Contract RaUm Oh8pa8orra o Capacly for Energy Exha ges
2-CDWRA MWD
3-Miscoftneont)nkrthargs i Saba b OMMs I
t
ARIZONA PUBLIC SERVICE COMPANY (APS) - EDISON
CHOLLA NO 4 LAYOFF AGREEMENT
REFERENCE: Cholla Firm Power Purchase Agreement
DATE
EXECUTED: February 7, 1980, and amended on October 27, 1983
TERM: Terminates on May 31, 1990
DATE
DELIVERIES
BEGAN: June 1, 1984
AGREEMENT: Edison purchases the entire capacity of APS '
Cholla coal-fired steam electric generating Unit
No. 4 (350 megawatts) through May 31, 1989, and
56 percent of that amount, or 196 megawatts, from
June 1, 1989 through May 31, 1990 .
Edison schedules energy from Cholla No . 4, as
required by the Edison system, up to Edison' s
share of the unit ' s full capability.
CHARGES: Edison pays APS monthly charges to compensate APS
for a proportionate share of its fixed charges
(return on investment, depreciation, income
taxes, property taxes, and working capital) , fuel
expenses, and costs of operation and maintenance
for that unit .
DELIVERY
POINT: Palo Verde 500 kV Switchyard.
TRANSMISSION
BETWEEN APS
AND EDISON
SYSTEMS: APS provides Edison with firm transmission
service by separate agreement from Cholla No. 4
to the Palo Verde Switchyard.
RESERVE
SUPPORT: Reserves for the electrical output from Cholla
No . 4 are provided by Edison.
RRS:smc
2153/AES: 1
09/08/87
WASHINGTON WATER POWER "(WWP) - EDISON
CAPACITY EXCHANGE AGREEMENT
REFERENCE: WWP Exchange Agreement
DATE
EXECUTED: June 1, 1980
TERM: Terminates on March 1, 1990 pursuant to a
four-year notice given by WWP on January 6, 1986.
DATE
DELIVERIES
BEGAN: June 11 1980
AGREEMENT: WWP to make available to Edison 60 megawatts of
firm capacity and associated energy during June
through September of each year (240
megawatt-months) . Edison to make available to
WWP 80 megawatts of firm capacity and associated
energy during December through February of each
year (240 megawatt-months) .
Associated energy delivered up to 10 hours each
day (42 percent daily capacity factor) , or more
if agreed upon. Energy accounts to be balanced
out by May 31 of each year.
DELIVERY
POINTS: California-Oregon border, Nevada-Oregon border,
other points as may be agreed upon, or at
Edison' s interconnection points with SDG&E if
requested by WWP.
TRANSMISSION
BETWEEN WWP
AND EDISON
SYSTEMS: Provided by Edison's firm entitlements in and
ownership of the Pacific Intertie, and WWP's
purchase of firm transmission service from the
Bonneville Power Administration.
RESERVE
SUPPORT: Reserves are provided by system (Edison or WWP)
making available or furnishing the commodity.
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09/08/87
_J
f
COMISION FEDERAL DE ELECTRICIDAD (CFE) - EDISON
CONTRACT FOR THE PURCHASE AND SALE
OF
ELECTRIC CAPACITY AND ENERGY
REFERENCE: Mexico Firm Power Purchase Agreement
DATE
EXECUTED: November 12, 1980
TERM: Terminates August 31, 1996, unless extended by
mutual agreement.
DATE
DELIVERIES
BEGAN: February 1, 1986
AGREEMENT: Edison purchases 70 megawatts of firm capacity
and associated energy (up to 100 percent capacity
factor) from units at Cerro Prieto II and III
geothermal plants .
CHARGES: Edison pays CFE: (1) a demand charge based on a
contractual capital investment with a rate of
return; and (2) an energy charge based on the
price of Maya crude oil, CFE labor and material
costs, and a controlled market exchange rate.
DELIVERY
POINT: San Onofre 230 kV Switchyard
TRANSMISSION
FROM CFE TO
EDISON
SYSTEM: CFE delivers to San Diego Gas & Electric Company
at the Tijuana I-Miguel and La Rosita-Imperial
Valley points of interconnection along the
Mexico/USA border. SDG&E provides Edison with
firm transmission service by separate agreement
from, the points of interconnection to the
delivery point.
RESERVE
SUPPORT: Reserve support is provided by CFE's Northern
Baja California electric system.
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09/08/87
k
PORTLAND GENERAL ELECTRIC - EDISON
TONG-T9RM POWER SALE AND EXCHANGE AGREEMENT
REFERENCE: PGE Firm Power Purchase and Exchange Agreement
DATE
EXECUTED: July 31, 1986
TERM: December 310 2010
DATE
DELIVERIES
BEGAN: July 31, 1986
AGREEMENT: PGE to sell to Edison 75 megawatts of firm
capacity and associated energy (up to 100 percent
capacity factor) . Edison also has priority to
purchase 75 Mwh/hr, of economy energy as
available from PGE system.
From November 1, 1990 to September 300 2010, PGE
and Edison to exchange 225 megawatts of seasonal
peaking capacity and associated energy. Exchange
energy not to exceed 300,000 MWh/year.
Agreement also provides for modification of
existing PGE exchange agreement.
Edison has option to receive from PGE up to
100 MWh/hr. of firm energy during five certain
hours of each day during the May 16 through
October 15 period in any year (up to but not
beyond 1990) . Edison also has option to receive
from PGE up to 100 MWh/hr. of firm energy (up to
20 hours/day) during the additional two month
period April 16 to May 15 and from October 16 to
November 15 of each year (up to but not beyond
1990) ,
CHARGES: Monthly contract fee fixed at 1/12 of $15,72
million from July 1, 1987 through June 30, 1990
($16.9 million thereafter) .
Energy prices are based on PGE' s actual cost of
production or acquisition, with a sliding adder.
-2-
DELIVERY
POINTS: California-Oregon border, unless otherwise agreed.
TRANSMISSION
BETWEEN PGE
AND EDISON
SYSTEMS: Provided by Edison's and PGE's firm entitlements
in and ownership of the Pacific Intertie.
RESERVE
SUPPORT: Reserves are provided by the system (Edison or
PGE) making available or furnishing the commodity.
RRS:smc 1
2153/AES:4
09/08/87
BOULDER CANYON PROJECT
CONTRACT BETWEEN THE UNITED STATES DEPARTMENT OF ENERGY
WESTERN AREA POWER ADMINISTRATION (WESTERN) ,
AND
EDISON FOR ELECTRIC SZRVICE
REFERENCE: Hoover Power Purchase Agreement
DATE
EFFECTIVE: January 11 1987
TERM: September 30, 2017
DATE
DELIVERIES
BEGAN: June 11 1987
AGREEMENT: This agreement renews the 1941 contract between
the United States and Edison for the sale of
electrical energy from the Boulder Canyon
Project, which contract expired on May 31, 1987.
Under the terms of this new agreement, Edison
will purchase 277.5 megawatts of capacity and
approximately 251 million kilowatthours of energy
each year from Western.
CHARGES: Based on the United States ' cost of generation,
and presently estimated to be about 16 mills per
kilowatthour.
DELIVERY
POINT: Initially, at the 138 kV and 230 kV busses at
Hoover Powerplant. Ultimately, at the 230 kV bus
at Mead Substation.
TRANSMISSION
FROM WESTERN
TO EDISON
SYSTEM: Initially provided by Edison's transmission
facilities connected to the Hoover Powerplant
busses. Ultimately provided by Western
furnishing transmission service from Hoover to
Mead where Edison' s and Western's systems are
interconnected.
8
i
i
_2_
RESERVE
SUPPORT: Reserves are provided by Edison.
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09/08/87
DISTRICT - EDISON 1987 SERVICE AND INTERCHANGE
AGREEMENT
REFERENCE: Metropolitan Water District of Southern
California (MWD) interchange Agreement
DATE
EXECUTED: April 1, 1987
TERM: Coterminous with the MWD-United States Hoover
Contract (May 31, 2017) , or upon five years '
notice by either MWD or Edison.
DATE
SERVICES
BEGAN: June 1, 1987
AGREEMENT: MWD integrates its loads and resources (Hoover,
247.5 MW; Parker, 54.0 MW) with Edison's system:
MWD may purchase off-peak energy from Edison for
water supply purposes at Edison' s incremental
generating cost. Edison schedules MWD's
entitlement to Hoover power for the Control areta;
the amount of energy so scheduled will be
delivered to MWD as needed for MWD' s pump load..
MWD may bank energy as long as any costs incurred
by Edison are reimbursed by MWD. Edison has the
right to use MWD' s unused entitlement to Hoover
and Parker capacity. Edison may request MWD to
interrupt its pump load with certain
restrictions. MWD will interrupt its pump load
if its ability to make water deliveries is not
impaired. Edison may utilize the unused capacity
of MWD's transmission system. Edison will
provide 110 megawatts of transmission service
between Vincent and Hinds substations for MWD
deliveries to or from other water entities.
CHARGES: Edison pays "benefit energy" to MWD during r
off-peak hours to balance the benefits each party
receives . "benefit energy" varies according to
MWD's pump load; the more pumping the lower the
amount of "benefit energy" . "Benefit energy" is
determined by a formula in the agreement and will
vary from approximately 200 GWh per year for
maximum pumping to 450 GWh per year for minimum
pumping. Edison also reimburses MWD for Edison' s
proportionate share of losses for using MWD's
transmission system.
-2-
DELIVERY
POINTS: Not applicable; MWD's facilities are integrated
into Edison' s control area.
TRANSMISSION
BETWEEN MWD
AND EDISON
SYSTEMS: Provided by the integrated transmission systems
of MWD and Edison.
RESERVE
SUPPORT: Provided by the integrated MWD and Edison systems .
RRS: smc
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09/08/87
PACIFIC POWER & LIGHT (PP&L) - EDISON
LONG-TERM POWER SALES AGREEMENT
REFERENCE: Long-Term Power Sales Agreement (Agreement)
DATE EXECUTED: June 30, 1987
TERM: September,301 2006 except for continuation of
obligation to return energy associated with
seasonal capacity exchanges.
DATE
DELIVERIES
BEGAN: August 1, 1987
AGREEMENT: PP&L provides at least 200 MW of capacity to
Edison throughout the term of the Agreement:
298 MW from 8/1/87 through 12/31/89; 200 MW from
l/l/90 through the term of the Agreement.
Additionally, PP&L and Edison exchange at least
72 MW of seasonal capacity as soon as both
parties acquire sufficient rights to the COT
Project (COTP Capacity) . Upon mutual agreement,
capacity may be increased using similar terms. and
conditions.
Initially, PP&L delivers energy associated with
the capacity at an annual load factor of
54 percent. Edison schedules all deliveries of
energy and during any one day may schedule at a
load factor between 0 and 100 percent.
CHARGES: t$32. 6 MWh in 1987; $35. 6/MWh in 1988; and
$37.1/MWh in 1989 . During 1990 through 1995,
pricing is based upon PP&L' s fixed and variable
cost of production of a blend of Jim Bridger
(95%) and Colstrip (5%) . During 1996 through the
term of the Agreement, pricing is based on a
minimum 10000 MW resource pool. During 1990
through the term of the Agreement, Edison pays no
more than a price cap established within the
Agreement. The price Cap begins at $51/MWh in :.
1990 and increases to $206/MWh in 2006.
DELIVERY
POINTS: California-Oregon border, unless otherwise agreed.
. t
-2-
TRANSMISSION
BETWEEN PP&L
AND EDISON
SYSTEMS: Provided by i) Edison's firm entitlement in and
ownership of the Pacific Intertie and ii) PP&L' s
rights of firm access to the AC Intertie
independent of BPA' s Intertie Access Policy.
RESERVE
SUPPORT: Reserves are provided by the utility (PP&L or
Edison) making capacity available.
RRS:smc
2153/AES:7
09/08/87
PACIFIC-PORTLAND SALES AND EXCHANGE AGREEMENT
AND
PACIFIC. PORTLAND, AND EDISON ASSIGNMENT AGREEMENT
REFERENCE: Portland General Electric (POE) Assignment
Agreement
DATE
EXECUTED: August 25, 1972, as amended July 8, 1987 .
TERM: Terminates on October 15, 1990 unless extended by
Edison for one additional month.
DATE
DELIVERIES
BEGAN: November 1, 1973 (Edison to Portland) ;
May 16, 1974 (Portland to Edison)
AGREEMENT: In 1973, Pacific Gas and Electric Company
assigned Edison 100 megawatts of its POE annual
entitlement of firm capacity and associated
energy during May 16 through October 15 of each
summer. PGE was entitled to 100 megawatts of
firm capacity and associated energy from Edison
during November 11 through March 31 each winter.
As part of the new long-term firm purchase and
exchange agreement with PGE, and the amendment
entered into with PGE in 1987 (which was
effective on January 11 1986) , Edison is relieved
of its obligation to provide winter capacity to
POE.
Associated energy is delivered by Portland at a
capacity factor of up to 100 percent of the time
when Portland is making capacity available to
Edison. Edison has options to: (1) buy the
energy delivered during the summer months rather
than return such energy to PGE; and (2) buy
supplemental firm energy during five additional
hours per day and two additional months per year.
DELIVERY
POINTS: California-Oregon border, or other points as
mutually agreed.
1
-2-
TRANSMISSION
BETWEEN PGE
AND EDISON
SYSTEMS: Provided by Edison' s and PGE' s firm entitlements
in and ownership of the Pacific Intertie.
RESERVE
SUPPORT: Reserves are provided by PGE.
RRS:smc
2153/AES: 8
09/08/87
BONNEVILLE POWER ADMINISTRATION (BPA) - EDISON
LONG-TERM SALES AND EXCHANGE AGREEMENT
REFERENCE: BPA Long-Term Sales and Exchange Agreement
r
AGREEMENT: At this time (9/1/87) , Edison has no long-term
sales or exchange agreement with the BPA. The
previous 20-year agreement terminated on July 31,
1987. Edison continues to work with the BPA to
develop appropriate terms and conditions for a
long-term sales and exchange agreement similar to
those contained in principles discussed with the
BPA in 1986, but with much lower quantities of
power and prices to better reflect current market
conditions within the Edison system.
RRS:smc
2153/AES:9
09/08/87
_f
t
CAPACITY EXCHANGE AGREEMENT
BETWEEN
SOUTHERN CALIFORNIA EDISON COMPANY
AND
STATE OF CALIFORNIA
DEPARTMENT OF WATER RESOURCES (CDWR)
REFERENCE: CDWR-Edison Capacity Exchange Agreement
DATE
EXECUTED: September 17, 1981
TERM: Terminates December 31, 2004
DATE
DELIVERIES
BEGAN: April 2, 1987
AGREEMENT: Edison obtains from CDWR, primarily from
Oroville-Thermalito and secondarily from its
other power plants and from its entitlement to
energy from Pine Flat Power Plant, 412, 500 MWh
per year between the hours of 11:00 a.m. and
7:00 p.m. on Mondays through Fridays, upon demand
by Edison, at a maximum rate of delivery of
225 MW.
CHARGES: Edison makes available, during its off-peak
hours, an annual amount of non-firm energy equal
to approximately 453,750 MWh. In addition,
Edison waives 75% of certain firm transmission
service charges CDWR would otherwise pay to
Edison under the Power Contract and another firm
transmission service agreement that CDWR has with
Edison. Also, Edison reimburses CDWR for its
payments to Pacific Gas and Electric Company
(PGandE) for transmission service associated with
this agreement.
DELIVERY
POINT: Either Vincent or Midway
TRANSMISSION
FROM CDWR TO
EDISON SYSTEM: CDWR delivers to PGandE the electrical output of
Oroville-Thermalito and CDWR's other resources
located within the PGandE service territory.
Transmission service for such resources is made
available to CDWR by PGandE to Midway
substation. Edison accepts such output at Midway
Substation. The other CDWR resources are
delivered to Edison at Vincent Substation,
RESERVE
SUPPORT: Reserves for the purchases by Edison of
electrical output from CDWR' s resources are
provided by Edison.
RRS: smc
2153/AES: 10
09/08/87
,
POWER CONTRACT
BETWEEN
SOUTHERN CALIFORNIA EDISON COMPANY
AND
STATE OF CALIFORNIA
DEPARTMENT OF WATER RESOURCES (CMM
REFERENCE: CDWR-Edison Power Contract
DATE
EXECUTED: October 11, 1979
TERM: Terminates December 31, 2004
DATE
DELIVERIES
BEGAN: April 1, 1983
AGREEMENT: Edison obtains from CDWR 350 MW and 35-45% of the
annual amount of energy generated at
Oroville-Thermalito; 120 MW and 100% of the
annual amount of energy generated at Devil
Canyon; 5 MW and 100% of the annual amount of
energy generated at Cottonwood (Alamo) ; and,
24 MW and 100% of the annual amount of energy
generated by MWD Phase 1 Recovery Plants.
CHARGES: Except for the MWD Recovery Plants, CDWR obtains
from Edison, during its off-peak hours, an amount
of energy equal to the amount Edison has obtained
from CDWR; plus, an annual amount of energy in
exchange for the capacity Edison has obtained.
The annual amount of energy (MwH/MW-YR) exchange
for the capacity is determined as having a value
equal to Edison' s annual ownership costs
($/Mw-YR. ) of a combustion turbine. As payment
for the Recovery Plants, CDWR Obtains from
Edison, during its off-peak hours, an amount of
energy equal 120% and 90% of the amount of energy
Edison has obtained from MWD during Edison' s
on-peak and off-peak hours, 'respectively.
DELIVERY
POINT: Midway Substation
y y
-2-
TRANSMISSION
FROM CDWR TO
EDISON SYSTEM: CDWR delivers to Pacific Can and Electric Company
(PGandE) the electrical output of
Oroville-Thermalito. Transmission service for
Oroville-Thermalito output is made available to
CDWR by PGandE between Table Mountain and Midway
Substation. Edison accepts such output at Midway
Substation. The other CDWR resources are
delivered to Edison on its system.
RESERVE
SUPPORT: Reserves for the purchases by Edison of
electrical output from CDWR's resources are
provided by Edison.
RRS:smc
2153/AES:11
09/08/87
a
Utility Service Area: Southern California Edison Form R-56 p. 3 Of 3
Date Fled: Sep-87 CEC contact:At Alvarado
Utility Contact: Ron Schroeder INTERUTILITY IMPORT TRANSACTIONS Phone: (916) 324-3152
1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
Actual Actual Actual
Firm Imports
A. Capacity (MM
Northwest 667 667 667 221 736 736 588 773 773 773 961 1055 1313 1456 1456 1456
Southwest 622 622 339 339 190 0 0 0 0 0 0 0 0 0 0 0
California 456 456 601 538 538 538 538 538 538 538 538 538 538 538 538 671
Other-1 377 431 347 347 347 347 347 347 347 347 347 347 277 277 277 277
- - - - - - - - - - - - - - - -
Total Finn Import 2122 2176 1954 1445 1811 1621 1473 1658 1658 1 1658 1846 1940 2128 2271 2271 2404
B. Energy (GWh)
Northwest 0 0 1213 1821 2580 3100 2577 2549 2555 2549 3043 3686 4120 4234 4342 4342
Southwest 2778 4058 4193 2010 2008 1483 414 0 0 0 0 0 0 0 0 0
California 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Other-1 2697 1802 1838 1365 882 767 796 813 775 776 781 781 685 251 251 254
Total Firm import 5475 5860 7244 5196 5470 5350 3787 3362 3330 3325 3824 4467 4805 4485 4593 4596
Nonffrm Imports
A. Energy(GWh)
Northwest 11031 10053 7139 8321 4978 5296 6187 6962 6549 6033 5059 4007 3464 3438 3481 3412
Southwest 6169 5489 2926 3489 7286 8200 9040 9979 10419 9873 9488 8671 9576 9217 9989 9522
California 3435 652 2575 737 1787 1027 1018 979 1037 1118 1212 1233 1247 1288 1312 1306
Total Nonflrm Import 20636 16194 12640 12547 14051 14523 16245 17920 18005 17024 16759 13911 14287 13943 14782 14240
1-Includes SCE Hower and Mexico Geomimai
Udit Service Am& SouBwn CaRomia Edson-07 Farm R 5B µ 2 d 3
Data Filad: on Sd CECoar- -M Ahmvm&
UWNy Contact: R Ron roadar RlTERUTIUTT WORT TRANSACTIONS Phone: (016) 324.3152
1984 t965 1985 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
AcWai AcKW Acwal
Nonkm I nporta
A. Erwryy(GWh)
Noninsest t1031 10053 7t39 8321 4979 6296 6187 6962 6549 6033 5059 4007 3464 3438 3461 3412
Soutmrst 6169 5489 2928 3499 7286 8200 9040 9979 10419 9873 9488 8671 9576 9217 9969 9522
CaMbmia 3435 652 257S 737 1787 1027 1010 979 1037 Ills t212 1233 1247 1288 1312 1306
Taal Nmwm Ynpert 20635 16194 12640 12547 140SI 14523 16245 17920 t8005 17024 15 559 13911 14287 13 443 1,4782 14240
Casts(A) In SIMft
Nodhwast 18.63 24.55 13.54 18.11 19.06 20.99 22.82 24.45 26.79 28.50 31.20 33.34 36.21 39.20 42.95 45.33
Scuftmat 25.89 24.94 17.16 13.12 20.11 22.25 24.86 20.73 29.38 31.07 3406 36.68 39.80 42.86 46.60 50.44
catsornia 26.49 33.46 26.34 22.01 22.30 25.90 30.80 32.80 35.50 37.40 4070 43.40 46.70 50.00 54.00 58.00
Total Cast$000 4SO216 405607 212123 212690 28t252 320212 397276 460071 518371 520508 530330 SO4291 564791 594210 68629S 714116 '
i
i
I
Utility Service Area: Southern California Edison Form R-511 p. 1 Of 3
Date Fled: Sep-87 CEC contact:Al Alvarado
Utility Contact: Ron Schroeder INTERUTILITY IMPORT TRANSACTIONS Phone: (916) 324-3152
1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
Actual Actual Actual
Firm Imports
A. Capacity (MM
Northwest 667 667 667 221 736 736 588 773 773 773 961 1055 1313 1456 1456 1456
Southwest 622 622 339 339 190 0 0 0 0 0 0 0 0 0 0 0
California 456 456 601 538 538 538 538 538 538 538 538 538 538 538 538 671
Other- 1 377 431 347 347 347 347 347 347 347 347 347 347 277 277 277 277
- - - - - - - - - - - - - - - -
Total Firm Import 2122 2176 1954 1445 1811 1621 1473 1658 1658 1658 1846 1940 2128 2271 2271 2404
B. Energy (GWh)
Northwest 0 0 1213 1821 2580 3100 2577 2549 2555 2549 3043 3686 4120 4234 4342 4342
Southwest 2778 4058 4193 2010 2008 1483 414 0 0 0 0 0 0 0 0 0
California 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Other- 1 2697 1802 1838 1365 882 767 796 813 775 776 781 781 685 261 251 254
- - - - - - - - - - - - - - - -
Total Firm Import 5475 5860 7244 5196 5470 5350 3787 3362 3330 3325 3824 4467 4605 4485 4593 4596
C.Total Cost in$000
Northwest 0 0 27879 62656 118153 128826 121674 119742 132369 138341 180504 230685 261509 280176 300624 322139
Southwest 63374 132197 158247 109231 98381 55640 22223 0 0 0 0 0 0 0 0 0
California 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Other 8241 3956 4741 28830 34006 34012 35549 36724 36681 37171 38382 36955 28426 4295 4424 4607
- - - - - - - - - - - - - - - -
Total Cost$000 71615 136153 190867 200717 250540 218478 179446 156466 169050 175512 218886 267640 289934 284471 305048 326746
1-Includes SCE Hoover and Mexico Geothermal
EKISTINO AND PROPOSED DULK TRANSMISSION FACILITIES Page 2
Utility Service Area: Southern California Edison a R-6A
Date Filed: September, 1987 Far For Contact: Al Alvarado
CECr
Utility Contact: Ron Schroeder Phone: act. 32b-31
Phone: (818) 302-9514
Location From: To: Operating) tine Hating Len Ent. $ of Land (1) Est. Construction (1) California
gth Assoc. w/Pro ect $ of Project Counties
Voltage kV Mod. Date More. 4 Emerg. (Miles) (Book Cost (book Cost) Involved
220 kV Lines (Continued) on on
Amperes Line Another
4109 Chino-Various 220 2320-3070/ 88.54 86.74 8,068,067 35,067,437 San Bernardino-
2540-3360
4111 Big Creek /3-Big 220 820/900 Riverside-Orange
5.79 1,944 318,872 Fresno
Creek 1k
4113 Dig Creek 13-Springville 220 1160/L270 128.32 516.651 2,995,409, Fresno-Tulare-Kern-
L.A.
4114 Laguna Dell-Various 220 2320/2540 80.83 44.18 3,234,285 11.358,653 Los Angeles
4115 Hinson-Various 220 1106-3070/ 15.73 13.31 1,655,287 5,119.334 Los Angeles
1215-3380
4116 EI Nido-Various 220 2240-2320/ 57.34 34.02 3,020,030 14.337.584 Los Angeles
41I7 Yispah 01-2-Lugo 2460-2540
220 820/900 303.00 769,311 4,642,388 San Bernardino
4119 Mira Loaa-Various 220 820-2320/ 91.61 59.75 5,718,274 13,404,094 San Bernardino-
9D0-2540 Orange
4119 Center-Varioua 220 2320/2540 92.93 54.72 2,OOL,319 14,627,956 Los Angeles
4120 Al mitoa-Various 220 2320-3070/ 84.66 40.05 4,269,503 11,643,205 Los Angeles-
2540-3386 Orange
4121 Big Creed 14- 220 820/900 132.74 196,637 3,876,873 rresno-Tulare-Kern
Springville
4125 Moorpark-Various 220 1160-3070/ 221.69 194.29 10,973,961 42,489,558 Los Angeles
1270-3380
4127 Circa-Pisgah (MV) 220 820/900 84.46 0.63 19,842 1,015,629 San Bernardino
4133 Kramer-Various 115/220 (2) Various 103.93 102.24 1,250,420 17.807.145 San Bernardino-Kern
4144 Eldorado-Meade (NV) 220 2320/2540 30.64 9,993 903.913 Waved*
4153- PearbIossom-Vincent 220 820/900 13.14 310,659 890,388 Los Angeles
4156 Ellfa-Santiago 11-2 220 3070/3380 14.83 14.67 6,599966 7,366,672 Orange
4157 Rio Hondo-Vincent 12 220 2320-3600/ 22.41 106:504 6.135,204 Los Angeles
2540-3%0
4166 Big Creek 12-3- 220 Various 902 9,034 300.481 Fresno
big Creek 18
4168 big Creek /3- 220 820/900 6.50 4,331 472,834 Fresno
Mammoth Pool
4169 Dig Creek - Various 220 Various 290.35 7.27 213,456 7.981,176 Madera-rreano-Tulare-
4756 Devers-Various 220 800-1 80.56 39.7 Kern
9 -1 1,086,115 12,982.737 Riverside-San Bernardino
00-1270 270
Total 220 kV Lines 2,667.26 764.11 55,668,958 262,777,932
Notes: -
(1) The bulk power transmission lines on the Edison system range in age from current to 60 years. 1985 dollars costa for the large majority of these
lines are not extant,
(2) Operating Voltage/Design Voltage
PFM:ssc
2068
EXISTING AND PROPOSED BULK TRANSMISSION FACILITIES
Utility Service Area: Southern California Edison Form R-6A
pate Filed: September, 1987 CEC Contact: Al Alvarado
Utility Contact: Ron Schroeder Phone: (916) 324-3152
Phone: (818) 302-9514
Est. $ of Land (1) Est. Construction (1) California
Location From: To: Operating/ Line Rating Length Assoc. w/Pro�1act $ of Project Counties
Voltage kV Mod. Date Norm. 6 Emerg. (Miles) (Book Cost) (Book Coat) Involved
On n
800 kV Lines (DC) Amperes Line Another
4031 Sylmar - Celflo (CA) 800 3100 336.17 $0 $16 955 368 Los Angeles-Kern-Inyo
4034 Sylmar - Celilo (NV) 800 3100 289.73 0 13:999:446 Nevada
Total 800 kV Lines 625.90 0 30,954,814
500 kV Lines
4026 Midway-Vincent 11 6 2 500 3600/3960 225.50 2,897,750 41,259,158 Los Angeles-Kern
4059 Pardee-Vincent 12 220/500 (2) 2320-3600/ 2.75 13,002 556 959 Los Angeles ,
4147 2540-3960 27.48 3 915235 6 154:626 Los Angeles
4123 Lugo-Vincent 1 i 2 500 3600/3960 94.38 1:651:098 13:337,728 Los Angeles-
San Bernardino
4130 Lugo-Moheve (NV) 500 3600/3960 9.85 442 957,138 San Bernardino
4136 Eldorado-Lugo (CA) 500 3600/3960 150.67 1,320,126 22 287,630 San Bernardino
4137 Eldorado-Lugo (NV) 500 3600/3960 26.51 16,589 3:832,162 Nevada
4138 Lugo-Mire Loma /1-3 500 3600/3960 83.14 13.42 1,351,535 33,582,269 San Bernardino
4140 Lugo-Mohave (CA) 500 3600/3960 166.02 278,112 17 684,600 San Bernardino
4141 Eldorado-Mohave (NV) 500 3600/3960 59.39 26,294 2:462,813 Nevada
4143 Eldorado-Border (NV) 500 3600/3960 29.65 6,167 4613,865 Nevada
4148 Mira Loma-Serrano 500 360D/3960 25.70 0 26:391,854 San Bernardino
Orange
4154 Lugo-Victorville 500 3600/3960 7.57 769,025 1 917 202 San Bernardino
4155 Midway-Vincent 13 500 - 3600/3960 52.62 2,994,480 10:353:750 Los Angeles-Kern
4185 Devera-Palo Verde (CA) 500 3600/3960 126.45 2,249,552 47,851,474 Riverside
4186 Devera-Palo Verde (AZ) 500 3600/3960 112.05 0 40,644,696 Nevada
Devera-Palo Verde 12 500 3600/3960
California Oregon 500
Transmission Line
Total 500 kV Lines 1,199.73 13.42 17,489,407 273,887,874
220 kV Lines
4045 Pardee-Sylmar 01-2 220 3070/3380 6.53 6.47 179,131 1,192,805 Los Angeles
4046 Eagle Rock-Sylmar 220 3070/3380 0.04 1.75 186,657 276 517 Los Angeles
4051 Pardee-Vicent /1 220 2320/2540 7.34 0 666:551 Los Angeles
4070 Rio Hondo-Vincent 01 220 2320/2540 4.64 61,040 588,802 Los Angeles
4301 Pardee-Various 220 820-3600/
900-3960 324.88 30.63 1,624,435 28423 788 Los Angeles
4104 Devera-Various 220 820-1160/ 117.20 16.19 1,073,409 10:370:482 Riverside-San ,
900-1270 Bernardino
4107 Antelope-Various 220 820-1160/ 257.61 15.49 2,509,596 25,533,543 Los Angeles-Kern
900-1270
d
MOTES,
1, Transfer capability reported represents the maximum transfer
limit for the path in question. Actual transfer limit is dependent
on the generation on-line in the Southern PG&E system.
2. Transfer capability reported represents the maximum non -
simultaneous transfer capability from the area in question into
California. The simultaneous transfer capability may be lower.
3. IIC (Installed Interconnection Capability-transfer capability with
all lines in service) not known, Number shown represents the
maximum emergency transfer capability.
4. Transfer capability dependent on the system conditions in the
Southwest (i.e. series compensation level and number of Palo Verde
units on line).
5. Transfer capability is currently being re-evaluated.
6. Assumes that the 3rd AC Line and DC Upgrade Projects are In
service.
7. Assumes that the Palo Verde-Devers #2 and the Mead-Phoenix
Projects are in service.
8. Source for information Is WSCC reply to US DOE form IE 411.
9. Estimated capability.
IIIIIIII .I II II,1 I111111 n 1 Ill.rl•r11A1 IIIIU1.1111 1 111.1111M 1111'r o
111111 tlllll MY111
1111111Y C-MIM.1 SCbil will
RNINE all 302 p51 1
5. 1.M 4W IW W S.CNII _ _ MYI. W CNN. CMI 1.IsW SW 1e Colts CMI WSW
_-- 3w 111 ww 111 ales 17.31 391e 43.0) aces 12.3.4) 1w (2)
Etc 2sw (il ww Ill NN 131 Lis (0) t]W 12,41 lw In)
alas tic 31161, 11) anee PI 47W (7A) 391E 13,91 am (2.3.41 left, 131
ETC 3See Ill LW 41) aW (5) "is IH aW (7,4) lw P)
31e5 tic LW 11) LW (1) 47n 12,31 3910 /3,0) tsar 42,3,41 also PI
ETC isW (1) Ln 11) 47W IH nit (S) saw I7.411 lw PI
ales tic iw it) LW 11) on I2,3) ants 113.9) sale P,3.4) Saw (al
ETC Ties sal Mae 10 Aes (H "is (H sant a.•) /w PI
ales tic Les Ill lees (11 41n (7,3) 391e (2s) am 13.1.1) Is" 13)
ETC ayes (1) iw (1) aW IH Mu (H 43es 1a,4) Iw (IT
ens sac aces P) lass 11) on Ma) 391e 13.1) am 12,3,4) Islas (3)
ETC 75es IS1 3m (1) 47W (a) "to P) lee 17.4) INTO 151
?INS i1C LW Ill wW (1) on 42,3) 3516 13.9) am PA.H lw" (3)
Etc 7500 11) Mae (it 47" PI Lit 15) am 42.4) fw PI
else IIC iw (1) fees (1) a/W (2.3) 391e 43.9) Iles 42,3,41 Sw It)
ETC 33W 11) let (1) 47W (H esP P) aaW PM Iw P)
else tic iw Ill LW 11) ties 12.3) 3e16 (3.5) am 17,3,4) Iw P)
ETC lies 11) LW 11) aW IA LP PI aw Pral lees P)
lute sic 3w Ill nit, (1) oW 12.3) 391e 13.9) am 12.2.4) last la)
tic 35" (1) ales 11) 47" 131 Nis it) aw P.H Iw PI
Iles IIC not (1) not (1) aw 10.2) Tan 43.0) ales 42,3,4) low , If)
ETC ayes (t) Las 411 41W 131 LU (a) aw (2.a) lw (el
ltlee IIC LW It) Les 11) aes 13.31 Sets P,H am P,s.a) tw la)
ETC mW (1) Les 41) an PI "is PI aw (M) Iw PI
1192 tic LW IT.$) fett 11.5) 7w (aA,H sw P.H reel 12.3.4.11 Saes (37.9)
ETC me, I1,S) 3w (1.51 iw Ike) aces (s) tw 124.11 am 17.e1
1 3197 tic 39" IT'S) 3w 11.6) Few (aA.H am 42.4) teW 47.3.4.71 ttw P.itl
ETC me, IT.$) less (t.H Two (2.$) am (6) Stec PAT) LW P.H
31E2 tic aw 11,51 aces 11.51 7m I0.3,H am (3.4) sees 42.3.4.71 lees P.7d1
ETC mw IT'S) aw P.S) 7w PrH Sm la) sere (2.4,7) Les P.H
al s7 tic LW (I,H Lae It,H Tan 117,3,0) am P.H son 42.2,4.71 feet 13.7.11)
Etc Ines (S.$) mat IT'S) 7w its) Tan la) tw IZATI anet 0.11
vet tic Tan (IM aw 11,0 Test I7A.6) am PA the I2.3.4,7) iw 13,7,0)
ETC not, II,H aw It,H 711411 P.H SSW (a) sw P.4,71 Lit (7.9a
4,s3 Bic acne 11.3/ 3w 11.5) nW P,3,H 53" P.H nn (3.3.4.71 tree 0,7.e)
ETC Los IS.$) fw IT.$) 7w (7.H am Is) tnnt R.a,71 aw IT.H
7 n3 11C 7oea ISM lent it.$) Tw P,3.H am P,a) sass 12.2.4.71 3ne (3.7,H
ETC LW (I.$) Mis 11.H 7w RH fw It/ tw (2,4.7) 3aae P.H
Miss tic lilt Pr/) 3w 11.5) Tees (2.3r61 fan P.H tan 12,3.4.71 aw P.7d1
ETC ayes (trH ]ale it.%) 7w P,sl Sma to) Wes I2.4.7) LW 17.51
1
ens tic wall 11.51 well (1.$) 70es P.a.H am PAT ws P.3,a.7) less p,a.H
ETC Saes /I,SI Les Ilrs) ices 12.0) Im P) Wes P.a,1) lttt 17.H
ten a Ilc Les It.H aw IT.$) lees (a,a.H fLa P,q sale 42.2.4.71 leas is.7.H
ETC low (1,s1 3w MIT 1w P,H s75a lfl ew 12.4,1) me 17,91
11na IIc Les IL9 aw 11,5) 79" (2,3.4) iwn /a,q ew 17.3,4d) aw p,7,q
Ell mw Psl 3"ID P.$) 7w (7,H sill (H Now P.a.7) aw P.H
117e3 IIC law ILSI aw llsi 7w P,3,5) Two (7,a1 ease 17AA.71 3w 13,7•t)
ETC ]I1oa I S ]oes I S 7w 7 f Sloe a toot a a i 3w 7 t
IIILiti sF1.7I2 A1G:
A11t11AC CALIfOIM1A DISM 00M 1-1
DATA IIKI:S&TOC IM7 INC COY2KR CALON VIM
MRIT/CMARe M sC010DD MIMMI MAL M WARTS,M6 SINK[,LAW AW SAID,ISE MM. J9IA1 324-310
PM..O11-M-9514
KW Ott 1111, Dtt 1 UHL) 11111.2 It"L 3 L2111.4 U00.5 i VOL WnTI COOL VAM MI 10L.CO. WKS.INC. IK,a.
W[ N. TYPE CAI I I/mm 11M70N O/I2M 01m011 IROM1 1 SIN. (AS Am) fm 7m U1U um (ACTION. OMK.
amm I US 113 1 0.322 O.M 0,220 0.222 0.229 { ND 3 MT1 3 OT K IOOI UA,SOC 1.0D 1.440
MANIMS I OIL PS 1 6.20 0.191 SAM 0.186 0.2S9 1 LIOIIO 3.1"IIO'6 Of OC 1NN tSr.25t,W.STC Con 0.20
/OAMres 2 US IA t 0.m 0.2" 0.111 citz 4.M- [ nu K K 111I IIA,SK 1.M5 0.40
AIMOTIO 2 OIL 175 1 0.077 0.17S 0.220 0.234 0.73A I M K 10A[ 15I.232.[U,5IC $.OD cm
ALAMM 3 US D4 I 4.014 0.4% 0.011 1.ON 1.07Z [ at K M11 tM,M[ 11.410, 0.731
Almm 3 OIL 320 l 0.315 0.241 0.202 0.230 4.3/1 ( Or K )OK i5I.231,IL1,WC 0.0% UVA
AMISS 4 Hfi 320 1 0.022 0.OA5 O.OIO 1.0q 0.129 J at K 0NN UA,IOC 0.M7 0.750
KAMTOS 4 OIL 328 1 0.31E 9.228 0.178 0.I0 0.210 1 M K MK LA.231,W,KC 1.014 4.350
MA0110S S AAS 40 i 0.007 0.12, 0.0V 0.0% O.Fl4 1 0t K M01 LOA,SiC,7K O.MA 0.73A
ALAVAMS 3 OIL 40 1 0.2" 9.20 0.201 0.227 6.217 I Ot K MK IsI.=,LU SIC,IK 0.111 1.530
AONl10S A US No 1 0.02 OAAS 0.01E 0.116 0.156 1 M K IO1N iL1,SK,OK LOTS ►.)D
Al1MNs A OIL 480 t 0.264 Os7 0.207 U96 4.2S2 I OI K MK LS0.23L.tU SK,LK SAO SAW
ALWISS 7 US Ilk i MR I am I M0 t MR I 10m I ( K K NK NK owl M13
omm 7 NIST 126 J Mil i MCI M[i Mt I WK I I K K 0M NK on 31111 5
OK stal I US AS 1 0.I04 0.140 1.005 0.0N 1.101 1 UPI► 1.237110'A K M ASK W.sK 0."1 S.7IO
COL NTM I OIL AL J MR I MM 1 MR t WM t M0 11 OTLS K N IOK ISI.lSL,ID,SIC NMI 1.3%
UK am 2 US IO I 1.IU 0.10 1.115 0.9% 0.11% 1 K fI NK UA.SIC CON, 1.751
(IOL I01IO 2 OIL U I M I MK I MIN I MIN I IMt I ( K D 0ML 159 m,1114,sK on I O.SD
UK tiff 3 US 256 1 M1 I I111 I 0M1 I 00R 1 MR 11 K 4 OMtt Al m I C735
OIL 0011111 3 OIL 236 1 NO 1 00R 1 Mt t MR 1 DIN.I F K 4 IMN =002,91 MR 1 0.370
DIN.MIN 4 iA5 73A i MR I MR 1 MR l OM1 I not I 1 K OF MAIN 911 m I I.AO
OK OAIM 4 ML 25A i mm I MR 1 Mat MR I UK I I K M um L4.15xlm WWI 0.3010
•I.IOM t sK 32 1 NO I MR L owl Owl MM I J LNPD 1MW3 K K on$ MI MO 1 4.731
OLMM I OIL 33 [ MR 1 MM t MM 2 0M0 I OM1 I I IOU K K OW tM.05i,MN 1M11 C210 �
K O 1 94 IA ( 0.IA1 4.146 0.135 0.105 4.243 1 LR M AI21W3 OL s[ DK UA,11C 1.0M 6.1141
BL o t OIL 175 t 1.147 0.139 0.2" 1.211 0.311 t "Is K K 1K IsO.=,[L.sK Cm 4.14111
KM I 0K OS 1 1.731 O./M 6131 1.IN 1.10 1 or K MK N1A.MC SAN 6441
NL O 2 ML 03 1 1.IO1 1.311 1.299 "1 1.322 I O! Sc MM LW 24,t1f,110 Msl 4.30
K» 3 I46 335 1 0.144 0.073 0.175 RNA 0.091 1 of Sc MK ID,MC 1.07 0.731
c M10M 2 ME. 333 1 1.115 0.111 0.296 0.229 0.213 I K K UK Ll.2Q,ID,MC Lack 0.370
M.D 4 us 313 1 1.N1 0.062 0.071 0.07 0.125 1 M K MO UA,MC RMI Lm
IL5001M0 4 OIL 321 1 0.211 1.2TA 0.2" 4.25A 4.239 i K K MK IW=,tM,DC 1.I41 0.301
umm I US 132 t 0.276 cul 0.142 SAM 0.114 1 Lwm 1.16mrs K R NK WsK Lou 64411
ft101111 I 11L 132 ( 4.4" 0.354 CM 0.1N 9.I63 1 ONES K IS "K LY.=,U/ySIO 0.00 1.2M
Qtwm 2 G9 in I 1.I20 O.m 1.sm 0.017 1.109 i K is 10R ta.sK 1.000 SAN
viI 2 OIL IV 1 1.230 NMI 0.262 1.23A 1.2N 1 K IS Ml IA.23IjM UC 4.00 R3M '
UMAM 3 04 320 I 9.94A SAO 0.056 41,091 0.129 1 K IS NR L24.sK.MC 1.M2 1.730
M10AM 3 OIL 319 1 1.190 0.1% SAM 0.231 0.240 ( K Is MK L1I.2S,UA,9C.MC 1AIM Lm
Q101MA 4 US 334 1 O.NI OAU 0.076 1.W 1.13/ 1 >K Is UK W,SIC.MC 1.M1 LM
II107I1A 4 OR 330 I 0.271 0.272 0.237 0.232 0.248 { K 6 MK l3.231.UA,SK,MC 0.02 0-51
0I11ANA 5 US 126 I MR I us I MR i OK I MK 1 1 K K DR NM owl MM 3
01t17M1 3 IIST ix 1 DR I M1 L MR i M[I NM I 1 K K 0MK 10M MM► MRi
MM CMM54 4 COAL 3N 1 DR I MIN I mm I DR I MR I I MIA 4m W3 Q IS NO INS.OM IIK t MISS
m com- 5 Clog; 3% I s110 i NK 1 art I M0 1 NO i 1 Mal TONS R IS NOK LM,7AC MK 1 DR 3
M10I01K I GAS 33 I 1.0N O.NI 0.211 CNO 1.116 1 L"M HM10'3 K IO INN SK 1.OM MM 3
W410M 1 ML 33 1 0.173 1.1N 0.317 0.317 SAM { ms x IT INK L4.25L,STC 4.0111 MM3
N00MOR 2 US 31 1 O.OR 0.142 0.2N 0.322 O.M 1 K M NK 9TC 1.0411 01Ms
IIMNIR I 41L 31 1 1.091 1.123 1.319 0.414 0.462 1 K Q om L4.2U SIC 1.N2 was
M01t11K 3 US 40 I sm 2 0.071 0.I56 1.m cm t K M NK STC 0.01 MM s
MIIMIR 3 #It 44 1 0.179 sam 1.224 O.M 0.332 ! K M NK 13O.25XSTC SAM was
IIIIO0IR 4 as 44 1 0.213 0.147 0.20A 0.3" 0.413 1 K M MK sit 0.M3 ma
01INMR 4 OIL 44 1 0.295 O.M 0.241 0.333 0.319 I K or 101E L97.m.s1( 0.I93 MOS
UTILITY SEATKE NEA:
SORM CALIFORNIA EDISON FORK 8-7
DATA FILLO:SEPTEMBER IV61 CIC CONTACT:CALVU 1111
UTILITY CONTACT: NO SCIEOEDER INTIDDIR MAL POLLUTANTS. FUEL STOIAFE, LAND AND OATU USE 1NON1: 1916) 324-3143
UNI: 110-302-9SI4
PLANT NIT FUEL MIT I LIM I LEVEL 2 LEVEL 3 LIM A U9EL,15 I TOM QUANTITY CODL OATU Not TOE. CON. WIS, FAC. M. CN.
MANE N. 7111 CAP I WINES U/M29TI #0125111 I/M2IT0 A/M2111 I STOR. (AS NOTED) WE ]III NARI Itcl CONTROL 11FEC.
-------------- I -------_____------------------------ I ------------_---------------------------__----_---_-------.-______pt14-----_-
WITI06TN I GAS 215 I 0.002 0.124 0.144 0.157 O.ISS I LIQUID 7.266110.6 OT Oc ONE 1RA,STC 0.043 0.650
tM1N6tN I OIL 215 1 0.325 0.735 0.192 0.246 0.323 1 OILS OF OC NNE LSF.252.UA,STC 0.091 0.350
NR106TN 2 GAS 215 1 0.203 0.162 0.143 0.133 0.129 1 OT OC NNE LEA.Src 0.03E 0.650
NUNIINGTON 2 OIL 215 1 0.133 0.166 0.219 0,263 0.267 1 OT OC MN[ ISF.2SI,LU.STC 0.093 0.350
IEITMMTN 3 GAS 215 I 0.15E 0.212 0.146 0.156 6.215 1 ' OT OC NNE LEA,STC 0.007 0.650
MMIN6109 3 OIL 215 0.227 0.271 0.222 0.744 0.284 1 OT OC NNE LS1.252,EfA,STC 0.009 0.356
MU106TON 4 GAS 225 I 0.066 0.05E 0.103 0.151 0.196 1 OT OC NNE LIA,SIC 0.006 O.A50
N1TII61DN 4 OIL 225 1 0.29E 0.37E 0.260 0.291 0.327 1 0T OC NOU LSF.251,LtA.STC 0.013 0.350
UNTIMGTN S GAS 176 1 NOTE 1 Ntt 1 0019 1 NOTE I NR i I NC Nc NNE MOPE NOTE 1 NOR 5
UKTIN67DI 5 DIST 126 I NR 1 NOTE 1 NOTE 1 MOTE 1 Ntt 1 ( NC NC NNE NNE NOR 1 NR 5
TANG KACI 6 OAS 301 1 NR 1 NOTE 1 NOR 1 NR 1 NR 1 I LIQUID 1.275I10.6 OT 6T STEAM SVI 10711 POt[A
L016 GRACE 0 OIL 30) I NOTE I NOTE 1 NOR 1 NOR 1 DOT[1 I DOLS OT By STEAM LSF.OSI,SUI NDE1 I OUR 6
LONG IGCE 9 OAS 227 I DOTI 1 NR I NOT[ I OUR 1 NOTE I I OT IT STEAM SRI IOt1 1 I0114
LONG IWI 9 OIL 221 I OUR 1 N7I 1 NR I NOTE I OUR 1 I OT BY STEAM L4.05I,511 1011 1 NOTE 6
MNONAT 1 GAS 215 1 0.212 0.196 0.190 0.20 0.219 1 LIQUID 720110.3 N Dc NNE TfA,STt 0.031 0.6%
MANDA AY I OIL 215 I 0.293 0.243 0.229 0.240 0.260 I eBLS OT OC NNE ISF.251,LKA,STC 0.06E 0.650
MANDAU! 2 GAS 215 1 0.217 0.163 0.143 0.143 0.151 I OT OC IOU ISA,STC • O.m 0.630
INNDALAT 2 OIL 215 1 0.367 0.304 0.270 0.25E 0.769 1 OT OC NMI LSF.251,ILA,STC 0.077 0.650
MINDYAI 3 DIST 124 1 NOTE 1 NOR 1 NOT[ 1 NR I IOU I I NC NC NNE TOR 0.00 NOT[5
UgNARI 1 CON. 442 1 DDH 1 NOR I VOTE i NOR 1 Ntt 1 I SOLID 560IIO.3 1C 61, NN1 ESF.501.15! 0.000 1m 5
MNARA 2 COY. 442 1 NOR L DOTI I NR I IOR 1 NOTE 1 1 TONS NC GF NONg LSF.50I,15! 0.000 TOR 5
OIMMO MATt 1 W 730 1 0.016 0.007 0.040 0.016 0.116 I LIQUID 2.70110.6 OT OC wit LKA.STC,IUC 0.03I 0.730
• ONIONS RAM I OIL 150 I 0.222 0.20E 0.245 0.271 0.261 I MIS OR OC WE ESF.25E.LEA,6TC,2%C 0.074 0.530
01MN0 MAOR 2 GAS 750 1 OUR 2 0.023 0.012 0.109 O.I15 i OR OC NNE LW,SR,RC 0.021 $.In
OWN MACE 2 OIL 750 1 0.1% 0.155 0.150 0.223 0.201 I OT OC WK tSF.231,LIA,SR,10C 0.051 0.5%
RUOROR 5 US 175 I 0.014 0.071 0.095 0.15E 0.370 1 LLQIID 802I10.3 OT OC POINT LIA,STC 0.067 0.400
REDONDO 5 OIL 17S I 0.137 0.13A 0.176 0.264 0.355 I MIS OT OC WK LSF.25X,EEA,STC 0.064 0.200
low A GAS 173 I 0.030 0.123 0.173 0.214 0.233 I DT OC not LfA,S2C 0.042 0.400
KIOMOR A OIL 115 1 0.13E 0.199 0.210 0.225 0.449 1 OR Oc "I LSE.25I.UA,StC 0.09I 6.200
IUNN I GAS 410 1 0.013 0.039 0.069 0.091 0.104 ( OR Oc NEW: L1A'STC,Rc 0.012 0.ISO
REDONDO 7 OIL 400 I NOTE 1 MR 1 NR 1 NOTE 1 OUR 1 1 OR OC NONt LSF.23I,Lq,Stc,tN NR 1 0.550
IUN00 6 6A5 460 1 0.064 0.05E 0.064 0.097 0.143 1 OT OC NOIIE LU,STC,ttc 0.057 0.750
REDONDO N OIL 400 I NOR 1 NOTE 1 NOR I NOTE 1 NOR 1 1 OT OC NONE LSF.2SI,LFA,STc,RC NOR 1 0.3%
SN MRNDIN 1 GAS V 1 0.070 0.065 0.099 0.112 0.117 1 LIQUID 740110.3 1C N NN1 EIA,STC 0.016 6.736
SAS MARDINS 1 OIL 43 1 0.200 0.195 0.233 0.249 0.252 1 BINS IC M NNN ESF.251,LIA,STC 0.03E 0.531E
SN BUNDIN 2 GAS 63 I 0.067 0.079 0.OU 0.019 0.OR9 I 1C 6F NNt LrA,GIC 0.011 0.730
SN UNWIND 2 OIL 63 1 0.250 0.250 0.251 0.247 0.244 I GC 6! Not LSF.251,UA,Stt 0.029 0.550
•SCE lNTICIlAR'S SWE-IONS CORNERS 4IE-MINTY 582.
NOTES: 1) NE AN/OR TEAT INlIE EQUATIONS DOES NOT EXIST.
2) NI TAXIES CAt.CULATED UPON OFIIICAL TONMAS ARE NEGATIVE.
3) LIQUID FUEL![NT CAPACITY, N NATURAL GAS STORAGE.
41 FUCNNT OF DESIGN, WIN 001.
5) N REGULATORY LIMIT, EXEMPT.
6) 09 tOUM/101E LIMIT.
REVISION DAR: 09/04/6/ 7) FOUR COIN13S RACTIVE STORAGE.
Utility Service Area: Southern California Edison
Date Filed: September, 1987 For Contact: Art Soinaki
Utility Contact: Ron Schroeder OPERATIONS AND RELIABILITY DATA CEC
Phone. (818) 302-9514 Phone: (9I6) 324-3160
ENTER 5-YEAR AVERAGE FOR DATA REQUEST BELOW ENTER ESTIMATED 1992 DATA(FOR EACH FIELD LISTED BELOW
SUN (FOH SUN (MOM + AVAIL. SERV. RES. DUN. SIR! (FOH SUM (HOH + AVAIL. SERV. RES. OWN.
PLANT NAME AND UNIT NUMBER + EUON) PON EPDH + SOFA) HRS. HRS. HRS. + EUGH) PON EPDN + SOEH) HRS. HRS. HRS.
Alamitos 1 266 595 324 7.836 5,753 2,083 663 669 268 7,436
Alamitos 2 471 691 180 7,784 5,928 1,857 663 669 268 7,4l6
Alamitos 3(4) 947 1,178 347 6,651 5,863 787 (4) (4) (4) (4)
Alamitos 4 406 695 567 7,418 7,030 387 629 823 334 7,170
Alamitos 5 354 1,154 401 7.074 6,362 712 557 1,270 455 6.700
Alamitos 6 326 1,328 528 6,775 6,174 603 557 1,270 455 6,700
Alamitos 7 230 1,329 133 7,198 101 7,097 188(3) 1,085 204 7,388(3)
Coal Water 1 84 522 483 7,676 2,997 4,680 163(3) 567 243 7,901(3)
Cool Water 2 3,322 334 260 4,852 1,473 3,380 163(3) 457 243 7,9ol(3)
Cool Water 30C 107 $03 290 7,772 2,232 5,540 61 769 129 7,681
Cool Water 4CC 477 734 624 7,600 2,357 5,244 61 769 315 7,681
Ellwood 1 437 1 128 8,222 47 8,175 I43(3) 0(3) (3) g S09(3)
E1 Segundo I 293 880 242 7,486 5,695 1,791 663 669 268 7,436
E1 Segundo 2 263 514 283 7,857 5.780 2,077 663 669 268 7,436
E1 Segundo 3 1,012 1,146 356 6,411 3,472 1,394 629 823 334 7,170
E1 Segundo 4 507 834 347 7,318 6,810 508 629 823 334 7,170
1
Utility Service Area: Southern California Edison Fors RB-8
Date Filed: September, 1987 CEC Contact: Art Soinaki
Utility Contact: Ron Schroeder OPERATIONS AND RELIABILITY DATA Phone: (916) 324-3160
Phone: (818) 302-9514
ENTER 5-YEAR AVERAGE FOR DATA REQUEST BELOW ENTER ESTIMATED 1992 DATA FOR EACH FIELD LISTED BELOW
SUM (FON SUM (MOH + AVAIL. SERV. RES. DWN. SUM (FOH SUM (MOH + AVAIL. SERV. RES. OWN.
PLANT NAME AND UNIT NUMBER + EUGH) PON EPDH + SOEH) HRS. MRS. f HRS. + EUGH PON EPDH + SOEH) HRS. HRS. MRS.
Etivanda 1(4) 293 345 234 7,913 3,36.� 4,544 (4) 378(4) (4) 7,885(4)
Etivanda 2(4) 120 412 414 7,866 3,605 4,261 (4) 378(4) (4) 7,885(4)
Etivanda 3 631 617 ' 289 7,445 5,721 1,724 629 823 289 7,170
Etivanda 4 243 546 341 7,809 7,477 751 629 823 334 7,170
Etivanda 5 160 868 238 7,623 ' 74• 7,549 188(3) 1,085 204 7,388
Highgrove 1(4) 0 147 105 8,512 165 8,347 (4) (4) (4) (4)
Highgrove 2(4) 0 181 89 8,495 156 8,339 (4) (4) (4) (4)
Highgrove 3(4) 77 157 140 8,391 264 8.127 (4) (4) (4) (4)
Highgrove 4(4) 0 285 313 8,167 451. 7,717 (4) (4) (4) (4)
Huntington 1 295 937 301 7,408 7,070 338 275 726 274 7,529
Huntington 2 429 61r 224 7,646 7,028 619 275 726 274 7,529
Huntington 3(4) 846 306 623 7,095 429 7,660 (4) (4) (4) (4)
Huntington 4(4) 588 790 605 6,841 3,521 3,220 (4) (4) (4) (4)
Huntington 5 420 1,271 239 6,989 98 6,890 188(3) 1,085 204(3) 7,388
Long Beach CC 281 563 1,410 8,178 5,215 2,963 36 563 129 8,174
Mandalay 1 202 660 570 7,454 6,761 693 275 726 274 7,529
' ' I
i
Utility Service Area: Southern California Ediaon Fora R8-8
Data Filed: September 1987
Utility Contact. Ron Srchroeder OPERATIONS AND RELIABILITY DATA CEC Contact: Art Soinaki
Phone: (818) 302-9514 one: (916) 324-3I60
ENTER 5-YEAR AVERAGE FOR DATA REQUEST DELOM (
ENTER ESTIMATED 1992 DATA FOR EACH FIELD LISTED BELOW
SUN (FOR SUM (NON + AVAIL. SERV. RES. OWN. sum (FOH SIB! (MOH + AVAIL. S(4) RES. OMN.
PLANT NAME AND UNIT LAUNDER + EUGH� PON EPDH + SOER) HRS. NRS. MRS. + EUGH PON EPON + SOEH) MRS. MRS. MRS.
Mandalay 2 174 691 321 7,627 6,730 898 275 726 274 7,529
Mandalay 3 208 872 2I4 6,133 80 7,430 188(3) 1,085 204 7,358(3)
Mohave 1 2,454 832 227 5.997 5,997 0 1,407(3) 923 118 6,953(3) I.
Mohave 2 2,234 994 22 6,043 6,043 0 1,407(3) 923 118 6,953(3)
Ormond Mach 1 698 1.180 588 6,711 4,816 1,895 654 1,139 395 6,818
Ormond Beach 2 609 1,619 268 6,413 4,679 1,735 654 1,138(3) 395 6,818(3)
Redondo 5 947 1,420 622 6.000 4,503 1,497 945 1,420 511 6,067
Redondo 6 1,756 663 548 6.241 3,954 2,287 663 669 268 7,436
Redondo 7 862 1.136 712 6,512 5,585 928 557 1,270 455 6,700
Redondo 8 685 1,462 471 6,455 6,012 443 557 1,270 455 6,700
San Bernardino 1(4) 87 439 74 8,179 3,719 4.460 (4) 457 (4) 7,901(4)
San Bernardino 2(4) 143 532 147 7,943 3,254 4,689 (4) 457 (4) 7,901(4)
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Utility Service Area: Southern California Edison Form R8-8
Date Filed: September, 1987 CEC Contact: Art Soinsk i
Utility Contact: Ron Schroeder OPERATIONS AND RELIABILITY DATA - Phone: (916) 324-3160
Phone: (818) 302-9514
(1)
ENTER 5-YEAR AVERAGE FOR DATA REQUEST BELOW ENTER ESTIMATED 1992 DATA FOR EACH FIELD LISTED BELOW
SUM (PON SUM (MOH + AVAIL. SERV. RES. OWN. SUM (FOU SUM (MOH + AVAIL. SERV. RES. OWN.
PLANT NAME AND UNIT NUMBER + EDOH) PON EPDH + SOEH) MRS. HRS. HRS. + EUON PON EPDH + SOEH) HRS. HRS. HRS.
(1) The basis for the 1992 data is the average of a the 1982-1986 recorded data. The recorded data has been averaged for each class of units in the
Edison system. The average performance of a group of similar units is a better indicator of future performance than the recorded performance of an
Individual unit. i
(2) In 1992, Edison plane to operate its oil- and gas-fueled unite less than these units were operated during 1982-1986. Available Hours equals
Service Hours plus Reserve Shutdown Hours. Available Hours have been provided, but there is no accurate way to project Service Hours; therefore,
Service Hours and Reserve Shutdown Hours are not provided.
(3) An extraordinar outage occurred on a unit in this class of units during the 5-year record period. The projected data for 1992 assumes an outage
y
of this type wi11 occur once every thirty years on a unit of this type.
(4) This unit will be in Standby Reserve in 1992.
1
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I
Utility Service Area: Southern California Edison ,
Date Filed: September, 1997 Tote CEC C R-gK-8 p. 2 of 2
Att Soimki
Utility Contact: Ron Schroeder OPERATIONS AND RELIABILITY DATA Phone: (916) 324-3160
Phone: (818) 302-9514
(I)
ENTFR ACTUAL I985 DATA FOR EACH FIELD BELOW
I
AMOUNT OF (2) HOURS OF
START-UP ! OF t OF TOTAL SCHED. MAI4NTEN. A' OF AVERAGE
MIN. HIM. FUEL UNIT ATTEMPTED ACTUAL HOURS MAINTEN. DURING FORCED OF HOURS PER
PLANT NAME AND UNIT NUMBER RAMPRATE DOWN TIME UP TIME (M Btu) CHAR. STARTS STARTS CURTAILED MOH FOR CURTAILMENT OUTAGES FORCED OUTAGE
Alamitos 1 ISO 2,0 0 2,500 2 29 28 248 65 248 5 115
Alamitos 2 I80 2.0 0 2.500 2 21 20 2be U 808 4 226
Alamitos 3 300 2.0 0 4,500 2 23 23 631 288 752 14 115
Alamitos 4 300 2.0 0 4,500 2 22 20 502 770 558 8 232 I
Almattos 5 150 2.0 U 6,200 2 8 8 258 U 3,239 8 528
Alamitos 6 150 2.0 0 6,20U 2 5 5 126 46 1,003 1 1,053
Alamitos 7 900 0.1 0 200 5 124 110 70 46 5b5 19 38
Cool Water I Igo 2.0 0 750 2 11 11 0 1.261 339 3 624
Cool Water 2 240 2.0 0 920 2 15 14 12 773 960 3 365
Cool Voter 3ST 300 0.1 O 200 3 77 73 75 394 694 9 12$
Cool Water 3CT 2,000
Cool Water 4ST Igo 0.1 0 200 3 65 65 75 1,001 838 4 527
Cool Water 4CT 2,000I
Ellwood 1 900 0.1 0 100 5 51 38 s 218 0 7 39
E1 Segundo I I80 2.0 0 2,500 2 20 20 219 76 370 3 187
E1 Segundo 2 Igo 2-0 0 2,500 2 25 25 163 895 120 10 131
Utility Service Area: Southern California Edison Fora R-8, p. 2 of 2
Date Filed: September, 1987 CEC Contact: Art Solnskl
Utility Contact: Pon Schroeder OPERATIONS AND RELIABILITY DATA Phone: (916) 324-3160
Phone: (818) 302-9514
ENTER ACTUAL 1985 DATA FOR EACH FIELD BELOW
(1)
AMOUNT OF (2) HOURS OF (4)
START-UP Y OF Y OF TOTAL SCHED. MAINTEN, t OF AVERAGE
MIN. MIN. FUEL UNIT ATTEMPTED ACTUAL HOURS HAINTEN. DURING FORCED OF HOURS PER
PLANT NAME AND UNIT NUMBER RAMPRATE DOWN TIME UP TIME (HHBtu) CHAR. STARTS STARTS CURTAILED MOH PON CURTAILMENT OUTAGES FORCED OUTAGE
El Segundo 3 360 2.0 0 4,500 2 29 28 49 392 1,096 26 116
E1 Segundo 4 300 2.0 0 4,500 2 22 22 310 174 462 15 73
Etiwanda 1 156 2.0 0 1,800 2 30 30 0 499 0 2 276
Etiwanda 2 156 2.0 0 1,800 2 35 33 0 559 0 6 120
Etiwanda 3 300 2.0 0 4.500 2 30 29 189 340 0 6 109
Etiwanda 4 300 2.0 0 4,500 2 26 26 22 417 0 14 59
Erlwanda 5 900 0.1 0 200 5 119 114 150 186 1,636 6 312
Four Corners 4 2160 0 11,000
Pour Corners 5 2161 0 11,000
Highgrove 1 120 2.0 0 240 6 8 8 0 0 101 0 0
Highgrove 2 120 2.0 0 240 6 8 8 0 0 203 0 0
Highgrove 3 120 2.0 O 330 6 10 10 O 0 256 0 0
Highgrove 4 120 2.0 0 330 6 29 29 0 4 193 0 0
Huntington 1 240 2.0 U 3,000 2 14 14 75 77 880 4 293
Huntington 2 240 2.0 0 3,000 2 .23 23 139 123 1,737 7 302
/Represents Edison's share "
Utility Service Area: Southern California Edison
Date Filed: September, 1987 Utility Contact: Form R-8, p, 2 of 2
Schroeder OPERATIONS AND RELIABILITY DATA
Phone: (818) 3U2-9519514 P CEC Contact: Art SoinakiPhone: (916) 324-3160
(1) ENTER ACTUAL 1985 DATA FOR EACH FIELD BELOW
AMOUNT OF (2) HOURS OF
START-UP OF l OF TOTAL SCHED. NAINTEN. # OF AVERAGE #
MIN. HIM. FUEL UNIT ATTEMPTED ACTUAL HOURS MAINTEN. DURING FORCED OF
PLANT NAME AND UNIT MINDER RAMPRATE DOWN TIME UP TIME (M btu) CHAR. STARTS STARTS CURTAILED Noll POW CURTA__ ILMETf OUyACFS FORCED SpU,1P, E
Huntington 3 240 2.0 0 3,000 2 25
22 21
Huntington 4 240 2.0 0 3,000 2 15 4 29 87 24 0 565 10 118 145
2U0 5 SS 76 623 2/3 158
Huntington 5 900 0_1 0 558
Long Beach 8ST ISO O. 3 14
1 0 200 3 1
Lon beach .677 1,466 269 0 380 p
H 8CT 2,200 0
Long beach 9ST ISO 0 200 3
Long beach 9CT 334 U 380 0
0 2,210
Mandalay 1 ISO 2.0 0
3,000 2 9 9 186 U 252 2 �
Mandalay 2 ISO 2.0 0 3,000 2 148
8 47 34 429
8 O 0 Mandalay 3 900 0.1 0 200 5 53 50
13 43 2,290 4 585
Mohave 1 168# 2.0 0 11,000 1 25 25 233 (1555 31 179
ii
Mohave 2 I68f 2.0 0 11,000 1 16 16 136
O 504 21 269
Ormond beach 1 145 2.0 0 10,000 2 15 15 38
175 1,I43 10 137
Ormond Beach 2 145 2.0 0 l0,OD0 2 8 8 107 142 2,167 g
Redondo 5 ISO 2.G D 333
2,SOU 2 19 I9 94 67 289 5
#Represents Edison's share 390
Utility Service Area: Southern California Edison Form R-B, p. 2 of 2
Date Filed: September, 1987 CEC Contact: Art Sofnaki
Utility Contact: Ron Schroeder OPERATIONS AND RELIABILITY DATA Phone: (916) 324-3160
Phone: (618) 302-9514
ENTER ACTUAL 1985 DATA FOR EACH FIELD BELOW
(1)
AMOUNT OF
HOURS F
START-UP / OF / OF TOTAL SCHED. MAINTEN. / OF AVERAGE /
MIN. MIN. FUEL UNIT ATTEMPTED ACTUAL HOURS MAINTEN. DURING FORCED OF HOURS PER
PLANT NAME AND UNIT NUMBER RAMPRATE DOWN TIME UP TIME MMBtu CHAR. STARTS STARTS CURTAILED MOU PON CURTAILMENT OUTAGES FORCED OUTAGE
Redondo 6 180 2.0 0 2,500 2 16 16 173 329 0 2 238
Redondo 7 150 2.0 0 6,200 2 15 15 349 145 987 14 132
Redondo 8 ISO 2.0 0 6,200 2 12 12 301 168 891 4 336
San Bernardino 1 120 2.0 0 720 2 14 14 0 23 141 1 214
San Bernardino 2 120 2.0 0 720 2 13 13 0 210 128 1 344 '
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'F
utility Service Area: Southern California Edison Form R-8, p. 2 of 2
Date Filed: September, 1987 CEC Contact: Art Soinski
Utility Contact: Ron Schroeder OPFKAIIUNS AhU HFIIABILIIY bA1A Phone: (916) 324-3160
Phone: (818) 302-9514
ENTER ACTUAL 1485 bAIA FOR EACH FIELN BELOW
(3)
AMOUNT OF (2) UOORS OF (4)
START-UP Y OF Y OF TOTAL S1'11Eb. MAINTEN. E OF AVERAGE ►
MIN. MIN. FUEL UNIT AWEMPTED A1.1UAL 11GURS HAINIFN. [MIRING FORCED OF HOURS PER
PLANT NAME AND UNIT NUMBER RAMPRATE DOWN TIME UP TIME (HMBtu) GUAR. STARTS STARTS LURTAII EU mul VON LURTAILMENT OUTAGES FORCED OUTAGE
(1) Start-up heat input values listed are for cold start-ups, i.e., unit assumed off-line 50 or more hours.
(2) The Total Hours Curtailed column has been computed as total equivalent derate hours.
(3) The orlRinal column label was "Hours of Scheduled Maintenance." Provided is Maintenance Outage flours (WAf) and Imlanned Outage Hours (PON).
(4) SCE does not tabulate maintenance hours worked during unit curtailments.
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L
1 `
Utility Service Area: Southern California Edison Form R-9A
Date Fled: Sep-87 CEC contact Melinda Merritt
Utility Contact Ron Schroeder OFF SYSTEM LOSSES Phone: (916) 324-3148
(MW)
1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
Actual Actual Actual
Off System Losses
BPA ExdharW 33.00 33.00 33.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Choila 3.68 10.50 10.50 10.50 10.50 5.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Navajo 8.84 8.84 8.84 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
PGE ExdkvW 6.00 6.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
PGECont. 0.00 0.00 4.50 4.50 4.50 4.50 4.50 18.00 18.00 18.00 18.00 18.00 18.00 18.00 18.00 18.00
WW&P 3.60 3.60 3.60 3.60 3.60 3.60 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
APPA' -0.89 -0.89 -0.89 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Oroville 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 i14.00 14.00 14.00 14.00 14.00 14.00 14.00
Four Corners 22.00 22.00 22.00 22.00 22.00 22.00 22.00 22.00 22.00 22.00 22.00 22.00 22.00 22.00 22.00 22.00
Mexico Geothermal 0.00 0.00 1.74 1.74 1.74 1.74 1.74 1.74 1.74 1.74 1.74 1.74 1.74 0.00 0.00 0.00
IPP 0.00 0.00 5.56 5.56 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00
IPP T/L 0.00 0.00 0.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00
PP&L 0.00 0.00 0.00 0.00 18.00 18.00 11.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00
COT Project 0.00 0.00 0.00. 0.00 0.00 0.00 0.00 9.00 9.00 9.00 9.00 8.00 8.00 8.00 8.00 8.00
PNW Purchase 0.00 0.00 0.00 0.00 15.00 15.00 15.00 16.00 15.00 15.00 27.00 33.00 50.00 57.00 65.00 65.00
Total 90.23 97.06 108.86 83.90 122.34 117.34 101.24 122.74 122.74 122.74 134.74 139.74 166.74 162.00 170.00 170.00
Ubft Service Arai: SouBern-Cewomti Edem Form ROB
Daft Filed: S*"7 CEC contact Shbu Dahr
U" Contact Rm Schroeder RESERVE REOUIREMEMS Phone: (916) 324.3153
1984 1995 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1999 1999
Actual Aceral AckW
PWrwft Rea. (%) M25 21.86 25.49 23.34 21.26 20.46 18.42 17.97 16.58 16.45 16.08 16.00 16.00 16.00 16.00 15.00
PUnnkg An. (MMI) 2165 3189 3721 3480 3227 3160 2922 2917 2757 2789 2784 2832 2895 2951 3008 3065
Spkairg Res- (%) 7.36 8.10 7.61 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00
Spkmkg Res. (MW) 1118 1182 1111 1044 1063 1081 1110 1136 1164 1187 1212 1239 1266 1291 1316 1341
LOW SULFUR FUEL OIL
CHEVRON U.S.A. OPTION AGREEMENT
DATED MAY 1985
AGREEMENT : Chevron U.S.A. to sell and deliver low sulfur
fuel oil to Southern California Edison Company.
TERM: 10 years (July 1985 through June 1995) .
QUANTITY: Edison has no obligation to purchase any
volume . Option quantities:
- Up to 500,000 barrels within 60 days
- Up to 1 million barrels/month on 60 days '
notice
- Up to 2 million barrels/month on 90 days '
notice
- Any combination of the above
- Orders may be repeated every 30 days
Maximum delivery rate of 2 million barrels/month.
QUALITY: Edison's current LSFO specification or later
revised specification.
PRICE: Market price applicable to the calendar month
prior to delivery.
DELIVERY: By pipeline or ship, at Edison' s option.
DEMAND CHARGE : $750,000/month (no escalation) .
RMS:90
CHEVRON U.S.A. , INC. CATALINA DIESEL
FUEL OIL AGREEMENT DATED JULY 30, 1980, AS AMENDED
AGREEMENT: Chevron U.S.A. , Inc. to sell and deliver diesel
fuel oil to Southern California Edison Company.
TERM. Ongoing until• terminated on 90 days' written
notice .
UANTITY: Each year, Edison shall provide Chevron an
estimate of the annual quantity of diesel it
desires to purchase during the next calendar
year.
UALITY: Chevron Diesel Fuel No. 21 which shall meet the
typical test data.
PRICE : Chevron's posted price, less applicable buyer' s
purchase discount.
MEASUREMENT: Gross quantity in delivery trucks, corrected to
a temperature of 60OF in accordance with ASTM
Table No. 6B.
DELIVERY: Delivery by flat barge and truck to buyer's
storage facility.
RMS:90
(
SOUTHERN CALIFORNIA GAS COMPANY
INTERRUPTIBLE GAS SERVICE
RATE SCHEDULE NO. GN-5
AGREEMENT: Southern California Gas Company ( "SoCal" ) to
provide Southern California Edison Company
interruptible natural gas service under Schedule
No. GN-5.
TERM: Ongoing .
QUANTITY: SoCal to make available natural gas service to
Edison electric generating stations for uses
classified in Rule 23 as Priorities 21 3, and 5.
QUALITY: Heat content averages 1,050 Btu per cubic foot .
PRICE : Monthly Customer/Demand Charge : $9 M2
Monthly Tier I Volume : 35 M Therms
Tier I Price : System Supply Commodity Rate plus
$1. 01/M2Btu
Monthly Tier II Volume : All volume not purchased
as Tier I
Tier II Price : Short term purchases plus
$0. 15/M2Btu
DELIVERY: Delivery of gas is made to El Segundo, Long
Beach, Redondo, Alamitos, Huntington Beach,
Etiwanda, San Bernardino, Highgrove, Ellwood,
Mandalay, and Ormond Beach Generating Stations .
NOTE : Small quantities of gas received under Rate
Schedule Nos . GN-2 through GN-4 for the fuel oil
pumping and heating stations.
RMS:90 '
CITY OF LONG BEACH
NATURAL GAS PURCHASE AGREEMENT
DATED JANUARY 1t 1983
AGREEMENT: City of Long Beach ( "City" ) to deliver to
Southern California Edison Company ("Edison" )
interruptible gas to be used for electric
generation.
TERM: Five years expiring December 31, 1987, unless
terminated by either party on 12-month advance
written notice .
QUANTITY: City shall offer quantities of gas to Edison.
Edison may purchase any or all of such gas at
Edison's sole discretion.
QUALITY: Natural Gas Specification included in agreement
represents pipeline quality gas.
PRICE: Not to exceed the rate paid to Southern
California Gas Company.
MEASUREMENT: Measurement to be determined by City and
expressed in cubic feet in accordance with
normal industry practice .
DELIVERY: Delivery of gas made into Edison's facilities at
Alamitos or Huntington Beach Generating
Stations, at pressures agreed to between the
parties.
RMS:90
PACIFIC GAS AND ELECTRIC COMPANY
PRIORITY 5 NATURAL GAS FUEL AGREEMENT
DATED FEBRUARY 6, 1959, AS AMENDED
AGREEMENT: Pacific Gas and Electric Company ( "PGandE" ) to
deliver and Southern California Edison Company
to receive interruptible gas for electric
generation.
TERM: From April 27, 1961 (date of first delivery) to
April 26, 1966, and year-to-year thereafter.
QUANTITY: PGandE's maximum volume obligation is 1.5 M2
cubic feet per hour. -
QUALITY: Not specified.
PRICE : Prorated monthly demand charge based on
historical purchases plus G-57 tariff commodity
rate .
MEASUREMENT: Measurement in cubic feet in accordance with
provisions of the California Natural Gasoline
Association Bulletin TS-561 or revisions thereto.
DELIVERY : Delivery of gas is made to Cool Water Generating
Station, Units 1 and 2 .
RMS: 90
PACIFIC GAS AND ELECTRIC COMPANY
PRIORITY 3 GAS SERVICE AGREEMENT
DATED NOVEMBER 18, 1980
AGREEMENT: Pacific Gas and Electric Company ( "PGandE" ) to
deliver and Southern California Edison Company
to receive interruptible gas to be used in gas
turbines for electric generation.
TERM; December 18, 1980 to December 18, 1983, and
month-to-month thereafter.
QUANTITY: Flow rate not to exceed 5.6 M2 cubic feet per
hour for total daily requirement of 134 M2
cubic feet.
QUALITY: Not specified.
PRICE : Customer Charge: Fixed fee based on highest
monthly purchases in therms during the last
12 months.
Demand Charge : Fixed rate based on highest
seasonal monthly purchases in therms during the
current season.
Commodity charge : Fixed rate per therms.
MEASUREMENT: Measurement in units of cubic feet in accordance
with standard industry practice .
DELIVERY: Delivery of gas is made to Cool Water Generating
Station, Units 3 and 4.
RMS:90
MOBIL OIL CORPORATION REFINERY GAS
PURCHASE AGREEMENT
DATED AUGUST 71 1981, AS AMENDED_
AGREEMENT: Mobil Oil Corporation ( "Mobil" ) to sell and
deliver refinery gas to Southern California
Edison Company.
TERM: September 1, 1981, through September 11 1986,
and year-to-year thereafter.
QUANTITY: Refinery gas meeting Air Quality Management
District regulations.
QUALITY : Mobil to provide an estimate of gas availability
each October 11 for three ensuing years.
PRICE : The lower of split the savings between Edison' s
alternate fuel cost and Mobil ' s netback if their
gas were sold to others or 95 percent of
Edison' s incremental fuel cost.
MEASUREMENT: Measurement in units of cubic feet at 14. 73 psia
and 60OF using standard industry practice .
DELIVERY: Delivery of refinery gas is made to the Redondo
Beach Generating Station.
RMS:90
ATLANTIC RICHFIELD COMPANY (MANDALAY)
GAS PURCHASE AGREEMENT
DATED MAY 15, 1959, AS AMENDED
AGREEMENT: Atlantic Richfield Company ( "ARCO" ) to sell and
deliver natural gas to Southern California
Edison Company.
TERM: January 1, 1985, until January 11 1989, and
thereafter until terminated by either party upon
90-days ' written notice.
QUANTITY; ARCO to provide Edison an estimate of available
natural gas each January 1 for the ensuing
calendar year.
QUALITY: Natural gas meeting Air Quality Management
District regulations.
PRICE : 95 percent of Southern California Gas Company
Rate Schedule GN-5, Tier II gas price .
MEASUREMENT: In units of cubic feet at 14.73 psig and 60OF
using procedures in the current Western Gas
Processors and Oil Refiners Association Bulletin
TS-561.
DELIVERY: Delivery of gas is made to the Mandalay
Generating Station.
RMS:90
1
'F
i
ATLANTIC RICHFIELD COMPANY (REDONDO)
FUEL GAS AGREEMENT
DATED JUNE 26, 1986, AS AMENDED__
AGREEMENT: Atlantic Richfield Company ( "ARCO" ) to sell and
deliver natural gas to Southern California
Edison Company.
TERM: From June 26, 1961, until terminated by either
party upon 90 days ' written notice .
QUANTITY: ARCO to provide Edison an estimate of available
natural gas each January 1 for the ensuing
calendar year .
QUALITY: Natural gas meeting Air Quality Management
District regulations .
PRICE : 95 percent of Southern California Gas Company
Rate Schedule GN-5, Tier II gas price .
MEASUREMENT: In units of cubic feet in accordance with
procedure outlined in California Natural
Gasoline Association or current revisions.
DELIVERY: Delivery of gas is made to the Redondo Beach
Generating Station.
RMS: 90
WORLDWIDE PACIFIC CORPORATION
FUEL GAS PURCHASE AGREEMENT
DATED DECEMBER 16, 1957, AS AMENDED
AGREEMENT; Worldwide Pacific Corporation ("WPC" ) to sell
and deliver natural as to Southern California
n r g r
Edison Company.
TERM: Ongoing until terminated by either party upon
190 ' days written notice .
QUANTITY: WPC to provide an estimate of natural gas by
January 1 for the ensuing years.
,Q_UAL_ITY . Natural gas meeting Air Quality Management
District regulations and agreed-upon minimum
heating content value .
PRICE: 95 percent of Southern California Gas Company
Rate Schedule GN-St Tier II gas price .
MEASUREMENT: In units of cubic feet in accordance With
procedure outlined in California Natural
Gasoline Association methods.
DELIVERY: Gas is delivered to Edison's Redondo Beach
Generating Station.
RMS:90
SOUTHWEST GAS CORPORATION
MOHAVE PROJECT IGNITION AND INCIDENTAL
GAS SERVICE AGREEMENT
DATED OCTOBER 15, 1969
AGREEMENT: Southwest Gas Corporation ( "Southwest" ) to
deliver and the Mohave Participants (SCE 56
percent, Nevada 14 percent, Salt River Project
10 percent, LADWP 20 percent) to receive gas at
the Mohave Generating Station for coal ignition
and other purposes.
TERM: Ten years with automatic extension unless
cancelled by either party with a 12-month
written notice .
QUANTITY: Southwest obligated to provide up to 10,400 Mcf
in any -24-hour period and may deliver greater
amounts of gas if available and desired by
Mohave Participants.
UAQ LITY : Southwest to deliver commercial quality natural
gas with not less than 900 Btu/cubic feet and a
pressure range of 50-75 psig.
PRICE: Spot gas purchase price plus Southwest' s
transportation rate on file with the Nevada
Public Service Commission.
MEASUREMENT: Gas quantity is measured in accordance with
mutually acceptable procedures by meters
installed and operated by Southwest.
DELIVERY: Gas is delivered to the Mohave Generating
Station's property.
TITLE: Title and risk of loss pass at the point of
connection between Southwest's delivery
facilities and the Participants ' receiving
facilities .
RMS:90
SOUTHWEST GAS CORPORATION AND
ARIZONA PUBLIC SERVICE COMPANY
GAS SERVICE AGREEMENT (AXIS)
DATED OCTOBER 15. 1984
AGREEMENT: Southwest Gas Corporation ("Southwest" ) to sell
and deliver 'natural gas to Arizona Public
Service Company.
TERM: October l5, 1984, through December 31, 1987, and
year-to-year thereafter.
QUANTITY: Buyer shall submit quantity nominations to
sellers on a daily basis and seller shall in
turn learn from El Paso Natural Gas ( "El Paso" ) ,
the supplier of gas, the allocations of gas to
be made available .
QUALITY; Specific gravity shall be determined daily and
heat content shall be determined by a recording
calorimeter.
PRICE: A base rate commodity charge subject to increase
or decrease to reflect any changes in E1 Paso' s
Rate Schedule ABD-L.
MEASUREMENT: Southwest shall provide the accuracy of
measurement which can be verified by APS .
DELIVERY: Delivery of gas is made to Axis Yucca power
plant.
RMS:90
NAVAJO TRIBAL UTILITY AUTHORITY
GAS SERVICE AGREEMENT FOR UNITS 4 AND 5
FOUR CORNERS PLANT
DATED AUGUST 31. 1979
AGREEMENT: Navajo Tribal Utility Authority ( "NTUA" ) to
deliver natural gas to Units 4 and 5 at the Four
Corners coal-fired generating station.
TERM: Two years and thereafter for succeeding terms of
one year each, unless and until 90-days prior
written notice .
QUANTITY: Not specified.
QUALITY: Not specified.
PRICE : Rates for gas sales are set forth in NUTA's rate
Schedule GN-51.
MEASUREMENT: Gas quantity is measured in accordance with
mutually acceptable procedures.
DELIVERY: Gas. is delivered via transmission line to the
Four Corners Generating Station at a pressure
mutually acceptable , but not to exceed 40 psig.
RMS :90
SPOT AND TERM
INTERRUPTIBLE GAS SALES AGREEMENTS
AGREEMENT: Various suppliers to provide Southern California
Edison Company interruptible natural gas. (See
attached list of suppliers. )
TERM: Month to month.
QUANTITY: As agreed to between the parties.
QUALITY: Pipeline quality conforming to the quality
provisions contained in the General Terms and
Conditions of FERC Gas Tariffs.
PRICE: As agreed to between the parties.
MEASUREMENT: Measured through interstate pipeline and SoCal
metering systems.
DELIVERY: Delivered by El Paso Natural Gas Company and/or
Transwestern Pipeline and SoCal Gas to Edison
generating stations.
RMS:90
Existing Spot Contracts
Supplier Date of Agreement
ARCO December 31, 1986
City of Long Beach June 11 1987
Dolphin Energy June 26, 1987
Enron Gas Marketing Being finalized
Gasmark February 9, 1987
Gulf Energy Marketing August 1, 1987
Gulf Ohio Pipeline Corp. March 12, 1987
Hadson Gas Systems January 29, 1987
Mobil March 13, 1987
Mountain Industrial Being finalized
Pacific Atlantic Marketing October 1, 1986
Petrus Oil Company July 10, 1987
Richardson Products January 22, 1987
Rocky Mountain Energy Exchange May 41 1987
Sunshine Energy May 18, 1987
Trigen Energy January 16, 1987
TXO Gas Marketing March 12, 1987
Existing Term Contracts '
Richardson March 13, 1987
Catenaga July 31, 1987
RMS:90
UdW Sonic* Area: Southern CaWoffk Edison Form R-10A and 108
Dar FAed: SeP-s7 CEO contact Pat MacAullle
UtlNQr Contact: Ron Schroeder PROJECTED FUEL CONSUA T1ON AND CAPACITY FACTORS Phone: (916) 324.3W2
Data not AvaiHtle
• i
ill
t
iL
Utility Service Area: Southern California Edison FORM R-11
Data Filed: September, 1987 Contact: Richard Grix
Utility Contact: Ron Schroeder Phone: (916) 324-3146
Phone: (818) 302-9514
LEVELIZED ANNUAL FIXED CHARGE RATES
(IN % OF CAPITALIZED COSTS)
A & G
GENERIC BOOK INCOME TAXES AD VAL,
RESOURCE DEPR. RETURN FEDERAL STATE & INS. TOTAL
NUCLEAR 3.33 8.98 3.64 1.00 2.22 19.2
COAL 3.11 - 9.13 3.49 .97 2.22 18.9
COMBUSTION
TURBINE 4.08 8.48 3.19 .85 2.22 18.8
IGCC 4.08 7.58 3.02 .90 2.22 17.8
FUEL CELLS 4.08 7.40 2.77 .81 2.22 17.3
BIOMASS 3.11 7.86 2.96 .79 2.22 16.9
GEOTHERMAL 3.11 7.84 2.94 .78 2.22 16.9
WIND 4.08 7.33 2.67 .78 2.22 17.1
SOLAR:
PHOTOVOLTAIC 4.08 7.36 2.71 .79 2.22 17.2
THERMAL 3.11 7.89 2.99 .80 2.22 17.0
HYDRO 1.44 10.35 3.62 1.02 2.22 18.6
TRANSMISSION:
SUBSTATIONS 2.21 9.74 2.65 .76 2.22 17.6
LINE 3.24 8.82 3.32 .86 2.22 18.5
DISTRIBUTION:
SUBSTATIONS 3.00 9.19 2.90 .81 2.22 18.1
LINES 5.75 7.45 3.54 1.03 2.22 20.0
Treasurer's/Financial Analysis
August 28, 1987
20001/5
APPENDIX I '
OF
FORM R-11
CFM VII
FIXED CHARGE RATES
GENERAL ASSUMPTIONS
-------------------
1. Cost of Capital and Discount Rate:
Capital Cost Weighted
Ratio factor Cost
Debt 45.00% 10.50% 4.73%
Preferred 6. 00% 9 . 50% 0.57%
Common Equity 49 .00% 15.00% 7.35%
------ --_--
Total 100.00% 12,65%
2. Annual expenses as % of total in-service capital costs:
A&G 1.00%
Ad Valorem Tax 1. 12%
Insurance 0. 10%
Total 2.224
3 . Income Taxes :
Investment Tax Credit (ITC) W 0.0%
Federal Income Tax Rate N 34.0%
State Income Tax Rate ■ 9 . 6%
4 . Sources:
Book Life (1) : Property Accounting
Salvage Value : Property Accounting
Federal Tax Depreciation (2) : Tax
State Tax Depreciation (2) : Tax
Construction Cash Flows (3) Engineering and
Construction
Note: (1) A full-year in-service date convention is used for
book depreciation.
(2) A mid-year in-service date convention is used for
tax depreciation.
(3) Construction Cash Flows were used in the calculation
of capitalized interest as % of in-service cost.
Financial Analysis
20001/6 August 28, 1987
' APPENDIX II
OF
FORM R-11
CFM VII
FIXED CHARGE RATES
RESOURCE SPECIFIC ASSUMPTIONS
FERC BOOK SALVAGE FED DEPR. STATE DEPR. CAP. INT. AS
GENERIC UNIFORM LIFE VALUE TYPE YEAR TYPE YEARS % ICOSTRV
RESOURCE ACCOUNT (Yrs.) M
NUCLEAR 321-325 301/ 0?/ DBI/ 15 ODB4/ 20 43.1
COAL 311-316 35 (9) DS 20 DOB 28 28.9
COMBUSTION
TURBINE 341-346 25 (2) DB 15 DOB 20 20.2
IGCC 341-346 25 (2) DOB 5 DDB 28 26.0
FUEL CELLS 341-346 25 (2) DDB 5 DDB 28 16.7
BIOMASS •311-316 35 (9) DDB 5 DDB 28 20.5
GEOTHERMAL 311-316 35 (9) DDB 5 DDB 28 19.5
WIND 341-346 25 (2) DDB 5 DDB 28 12.9
SOLAR:
PHOTOVOLTAIC 341-346 25 (2) DDB 5 DDB 28 14.4
THERMAL 311-316 35 (9) DDB 5 DDB 28 22.0
HYDRO 331-336 75 (8) 08 20 DDB 50 32.2
TRANSMISSION:
SUBSTATION 352-353 29 36 DB 20 DOB 30 5.8
LINES 354-359 41 (33) DS 20 DOB 30 5.8
DISTRIBUTION:
SUBSTATION 361-362 30 10 DB 20 DOB 30 6.8
LINES 364-367 28 (61) DB 20 DDB 30 5.8
1/ Based on book life of SONGS Units 2 8 3.
g/ Does not include decommissioning cost.
1/ 150% declining balance
A/ 200% declining balance
Treasurer's/Financial Analysis
August 28, 1987
20001/4
Page tof2
Utility Service Area: Southern California Edison form R-12
Date Fitted: Sep-87 CEC contact: Richard Brix
Utility Contact: Ron Schroeder CONSTRUCTION OUTLAYS FOR Phone: (916) 324-3146
Phone: (818) 302.9514 INDIVIDUAL ELECTRIC PLANT ADDITIONS
(MILLIONS OF DOLLARS *Totals way not add due to independent rounding)
Prior Yrs. (Cum.) 1966 1987 198a 1989 1990 1991
DESCRIPTION Total Cash IOC or Total Cash IDC or Total Cash IOC or Total Cash IDC or Total Cash IDC or Total Cash IDC or Total Cash IDC or
AFUDC AFUDC AFUDC AFUDC AFUDC AFUDC AFUDC
I.Pato Verde 1320 1023 297 212 85 127 180 36 144 40 12 28 11 a 2 10 7 3 it 7 4
Gen. Station
2.Dev./P.V. 1 T T 1 4 3 28 26 2 102 93 a 39 33 7
Line 2
3.8atsa Mead. 116 103 12 109 92 17 66 40 25 5 5
Hydro Plant
4-3alsa Mead. 1 1 3 3 1
Pump Storage
5.eig Creek 3 3 2 2 1 1 1 1 i 6 5 1 15 13 2
Expan.Proj.
6.Load 15 15 1 1 2 2 2 2 2 2 4 4
Management
T.CoMASw. 20 19 1 9 9 9 9 1 1 2 2
Power Projects
B.Mind Coarser- 14 13 4 4 5 5 2 2
ciatization
9.MVDC 2 2 7 7 1 35 32 3 62 55 7
Expansion
1O.CA/Oregon 3 3 3 3 5 4 T 38 35 3 45 38 7 5 5
T/L Project
it.Lg.Oit Field 2 2 4 3 4 3 1 3 2 1
Cogeneration
12.west of a a 17 is 2 4 3 1
Devers T/L
13.SCE CT
Peaking Res.
14.SCE CC
Inter. Res.
Y
Page 2of2
Form R-12
Utility Service Area: Southern California Edison CEC contact: Richard Grix
Date Filled: Sep-87 CONSTRUCTION OUTLAYS FOR Phone: (916) 324.3146
Utility Contact: Ron Schroeder INDIVIDUAL ELECTRIC PLANT ADDITIONS
Phone: (818) 302.9514 (MILLIONS OF DOLLARS *Totals may not add due to independent rounding)
1992 1993 1994 1995 1996 1997 1998 1999
Total Cash IDC or Total Cash IDC or Total Cash IDC or Total Cash IDC or Total Cash IDC or Total Cash IDC or Total Cash IDC or Total Cash IDC or
AFUDC AFUDC AFUDC AFUDC AFUDC AFUDC AFUDC AFUDC
1. 13 8 5
2.
3.
4 •
5. 50 45 6 128 116 12 255 224 31 175 152 23 83 68 15 60 45 15 2 1
6.
7.
8.
9.
10.
IT.
12.
13. 1 3 2 31 25 4 79 68 a 93 76 15
14. - 3 3 16 15 1 47 43 4 95 82 13 147 120 26 179 143 37
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r.
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Utility Service Area: Southern California Edison Aggregate Construction Outlays Form R-13 p. 2 of 3
r
Date Filed: September 1987 For Total Utility Electric Plant Additions CEC contact: Richard Grix
Utility Contact: Ron Schroeder (Millions of Nominal Dollars) Phone: (916) 324-3146
Phone: (818) 302-9514
Estimated % of Total for
Other Plants Sumtion (Totals) Pollution Control (1)
.................................................................................
Year Total Cash AFUDC Total cash AFUDC Total Cash AFIAC
1984-Rec. $50 $41 S9 $1,030 $852 $177 $169 n.a. n.a.
1985-Rec. 101 89 12 1,219 1,076 143 6 n.a, n.a.
1986-Rec. 138 125 13 1,205 1,090 115 282 n.a. n.a. l
1987 156 153 3 1,140 1,023 117 7 n.s. n.a.
1988 115 105 10 926 869 57 0 n.a. n.a.
1989 94 87 7 900 858 42 1 n.a. n.a.
1990 94 87 7 845 799 46 4 n.A. n.a.
1991 92 85 7 803 772 31 7 n.a: n.a.
1992 96 89 7 836 799 37 n.a. n.a„ n.a.
1993 100 93 7 922 875 47 n.a. n.s. n.a.
1994 106 98 8 1,063 996 67 n.a. n.a. n.a.
1995 111 103 8 1,058 985 70 n.a. n.a. n.a.
i
1996 116 108 a 1,018 966 52 n.a. n.a. n.a.
..................
(1) Only plant closings are available. No foretaste made beyond 1991.
Utility Service Area: Southern California Edison Aggregate Construction Outlays Form R-13 p. 3 of 3
Date Filed: September 1987 For Total Utility Electric Plant Additions CEC contact: Richard Grix I
Utility Contact: Ron Schroeder (Millions of Nominal Dollars) Phone: (9T6) 324.31"
Phone: (btd) 302-9514
Estimated% of Total forII
Other Plants Summation (Totats) Pollution Control (1) !I
--^............................................................................. !
Year Total Cash AFUDC Total Cash AFUDC Total Cash AFUDC !
1997 122 113 9 1,OFNi 1,036 52 n.a. n.a. n.a. '
1996 129 119 9 1,ia3 1,114 69 n.s. n.a. n.a.
1999 135 125 10 1,264 1,1E0 a4 n.a. n.a. n.a.
I!
------------------
i
(1) Only plant closings are available. No forecasts amde beyond 1991.
v
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t
Aw'
Utility Service Area: Southern California Edison ,
Pate Filed: September, 1987 Form R-14
Utility Contact: Ron Schroeder CEC Contact: Richard Grix
Phone: (818) 302-9514 Phone: (916) 324-3146
NUCLEAR FUEL INVESTMENT
(Millions of Nominal Dollars)
1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
Actual Actual Actual
Additions to Nuclear Fuel(5)
Palo Verde(4) 150) 150) 9(1) 30) 60) 10(l) 13(2) 18(2) 12•(2) 15(2) 17(2) 15(2) 22(3) 20(3) 20(3) 23(3)
(1) Contracted.
(2) Partially contracted. Partially projected.
(3) Projected.
(4) Owned fuel. Excludes AFUDC. Average equilibrium batch life expectancy 4.7 years.
(5) San Onofre fuel not included since under lease.
RRS: h
2176)AES:S
09/09/87
UWNy Swvke Are: Soutwn CaMornia E&w Form R-1SA
Deb Fled: Sap-87 CEC corftct Richard Griot
UNNty Contact Ran Schroeder TOTAL VAIMADLF ElIP 31M Phone (916) 324-3146
MiWons of Nominal DoNws
1984 1985 1986 1987 i988 1969 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
AckW AcWW Actual'
Nuclear Fud 100.00 97.00 t32.00 168.00 168.54 182-67 160.32 141.45 135.26 120.29 124.80 116.64 117.19 120.31 126.82 131.40
NUCk w Ver. O&M 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
CoalFud 102.32 69.74 112.40 117.31 115.67 111.83 114,70 125.26 127.96 132.02 138.73 143.69 151.84 158,68 168.02 175.51
Coal VarWia O&M 17.95 18.25 17.66 18.11 20.00 20.70 21.92 23.46 24.97 26.55 27.81 30.36 31.99
Nak"Gas Fuel 1122.46 1182.00 501.10 714.60 477.74 373.81 400.09 409.91 616.82 627.84 788.55 921.42 1060.00 1259.52 1390.53 1552.39
Vat.OSM:Gas Plarfs 4.97 2.89 1.63 1.64 1.53 1.94 2.27 3.33 3.99 4.68 5.40 6.37 7.02
Residual Fuel
Var.OAM:Res.Plants
D4Wkft Fuel 0.41 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.01 0.01 OM 0.02 0.04
Var.06M:DIL Piwrts 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
SW&WAc Fuels 0 0 0 0 0 0 44,56 44.19 41.83 50,29 47.11 56.83 55.41 59.73 55.07 62,05
Var.OAM:Syn.Planar O 0 0 1.18 1.16 t.09 1.31 1.23 1.46 1.50 1.66 1.59 1.88
PURPA Pudrse 61.10 172.42 330.15 417.70 837.80 1262.78 1500.62 1652.62 1763.95 1870.37 1996.22 2138.85 2214.65 2279.35 2366.98 2368.20
Imports
Fimr 71.61 136.15 190.57 206.72 250.54 218.45 179.45 156.47 169.05 175.48 218.89 267.64 289.93 284.47 305.05 461.27
Eom art 456M 405.89 212.1 212.69 281.22 320.21 397.24 469.03 518.42 520.48 530.33 504.3 564.77 594.2 686.19 714.04
Salasto08ws -23.25 -50.82 -22.21 -31.53 -69.19 -65.53 -71.06 -76.75 -84.46 -89.76 -99.19 -10SX7 -116.25 -125.37 -136.59 -147.81
Fuet l"x*p 99.13 235.4 69.69 168.44 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00
Trial 1390.32 2012.33 1456.41 1997.26 2143.36 2473.54 2796.85 2994.87 3262.56 3482.51 3822.55 4122.13 4420.28 4715.86 5050.4 5407.96
1964- 19M Data not AvabMe for Variable O&M
i
♦ r �
Utility Service Area: Southern California Form: R-15B
Edison CEC Contact:
Date Filed: September, 1987 Richard Grix
Utility Contact: Ron Schroeder Phone: (916) 324-3146
Phone: (818) 302-9514
HEAT CONTENT AND COST OF FUEL RESOURCES
1985
Heat Content Cost
(Btu/Unit) ($/Million Btu)
Nuclear 1.05
Coal 19.28 MMBtu/Ton 1.06
Oil
--Pistillate 5 .44 MMBtu/Bbl 7 .56
--Residual 6.13 MMBtu/Bbl 6.48
Natural Gas 1,053 Btu/Cubic Foot 4.11
Biomass--Municipal Waste Not Available l/ Not Available 1/
Geothermal
--Vapor Not Available 1/ Not Available 1/
--Brine Not Available T/ Not Available T/
Synthetics
--Methanol Not Available 1/ Not Available 1/
--Ethanol Not Available T/ Not Available T/
Low/Medium Btu gas Not Available 1/ Not Available l/
1/ Edison does not wholly own any facilities that makes use of such
fuels nor has plans for such facilities at the present time.
RRS:ih
2176/AES :6
09/09/87
Utility Service Area: Southern California Edison Fora R-16
Date Filed: Septembers 1987 CEC Contact: Richard Crix
Utility Contact: Ron Schroeder Phone: (916) 324-3146
Phone: (818) 302-9514
FIXED OPERATION AND MAINTENANCE EXPENSES
i
Millions of Nominal Dollars
1tua Actual
1tua 1987 1988 1489 1990 1991 1992 1993 1494 1995 19% 1997 1998 1999
Actual ActwF Actual i
Nuclear 19,90 20.72 25.83 26.73 30.02 31.I4 32.31 33.84 35.69 37.77 40.11 42.70 45.48 48.43 51.52 54,77
Coal--Conventional 37.20 39.75 40.35 41.76 43.34 44.95 46.65 49.85 51.53 54.54 57.91 61.65 65.66 69.91 74.37 79.07
--Advanced 0.00 0.00 0.00 0.00 0.00 0.00 1.27 1.33 1.40 1.49 1.59 1.68 1.79 1.91 2.03 2.16
Oil and Can Steam 94.95 85.96 89.52 90.16 82.57 85.65 88.89 93.07 98.18 103.90 111.95 123.60 131.63 144.24 153.48 163.17
Combustion Turbine 2.35 2.45 2.55 2.64 2.74 2.84 2.95 3.69 3.26 3.45 3.66 3.90 4.15 4.42 4.70 5.00
Combined Cycle 7.28 7.58 7.90 8.17 9.48 8.80 9.13 9.56 10.09 10.67 11.33 12.07 12.85 13.69 14.56 15.49
Hydro 12.93 I3.66 14.24 14.83 18.65 I9.45 20.18 21.13 22.29 23.59 25.05 26.67 28.40 30.24 32.17 34.20
Pumped Storage 0.00 0.00 0.00 U.Ou O.UO 0.00 0.17 0.18 0.19 0.20 0.22 0.21 0.24 0.26 0.28 0.29
TOTAL 164.62 169.23 130.39 184.30 185.79 192.82 201.54 211.05 222.64 235.62 251.80 272.50 290.21 313.13 333.11 354.13
x
f
Y
Utility Service Area: Southern California Edison Form R-16
Date Filed: September, 1987 CEC Confect: Richard Crix
Utility Contact: Ron Schroeder Pbone: act: Richard
Phone: (818) 302-9514
FIXED OPERATION AND MAINTENANCE EXPENSES
Millions of Nominal Dollars
(Continued)
1984 1985 1986 1987 1988 1989 �• 1990 1991 1992 1993 1994 1995 1996 1997
Actual Actual Actual
Trans- 72,999 73,160 82,083 76,654 78,548 81,760 81,920 86,147 88r 928 91,600 96,377 101,780 107,434 112,867
mission
Dietri- 166,461 141,765 143,401 163,433 164,810 171,553 169,043 174,993 177,997 180,656 187,291 194,890 202,702 210,027
button
Customer 89,615 97,682 103,505 104,697 107,413 111,798 112,054 117,990 122,076 126,027 132,900 140,667 148,818 156,843
Accounts
Sales 80,535 83,601 70,817 60,562 60,854 66,921 65,598 66,973 67,319 67,520 69,175 71,133 73.113 74,793
Expenses
Adminis- 303,187 324,855 366,109 350.696 370,958 386,247 398,561 428,355 452,401 476,754 513,203 554,487 598,813 643,634
tration
and
General
1998 1999 2000 2001 2002 2003 2004 2005 2006 2007
Trans- 119,138 125,725 132,640 139,896 147,510 155,499 163,874 172,657 181,864 191,520
mission
Distri- 218,653 227,572 236,790 246,316 256,155266,317 276,809 287,638 298,N14 310,358
bution
Customer 166,089 175,832 186,095 196,906 208,287 220,269 232,879 246,145 260,099 274,785
Accounts
i
SHIPS 76,876 78,996 81,153 83,346 85,575 87,840 90,141 92,479 94,852 97,261,
FxpPnaPN
Adminis- 695,109 750.494 810,074 874,147 943,035 1,017,082 2,096,652 1,182,138 1,273,955 1,372,612
t rnti on
and
General
RRS:lh
2176/AF.S:3-4
09/11/87
Utility Service Ares: Southern California Edison Key Financial Variables Form R-17A
Date Filed: September 1, 1967 CEC contact: Richard Grix
Utility Contact-, Terry cook Phone: (916) 324-3146
Phone: (318) 302-4467
1964 1905 1966
Actual Actual Actual 1967 1966 1969 1990 1991 1992 1993 1994 1995 1996 1997 199E 1999
---...............'-..................................................'.........................
I. Band Rate of Sew issues (1) 12.4% 11.2% 6.41 (See note below)
2. AFUDC Rate for (2):
a. Equity Funds 7.4% 7.6% 6.0%
b. Borrowed Funds 2.6% 2.6% 2.5%
c. Total AFUDC 10.2% 10.4% 10.51 11.1% 10.1% 10.2% 10.2% 10.2% 10.2% 10.2% 10.3% 10.3% 10.3% 10.4% 10.4% 10.4%
3. Yield an New Preferred issues (3) -- -- -- (See note below}
4. Required Return an Common Equity 16.3% 15.6% 15.1% (See note below)
5. Capital Structure for System
a. Percent Debt 45.6X 46.6X 46.5% The debt rate, preferred yield, required return on capon equity, and target capital structure are
b. Percent Preferred 9.5X 6-6% 6.6% based upon an assessment of future uncertainty, ad business and financial risks. These factors
c. Percent Common 44.7% 44.6% ".ax are used in determining the Company's tag-term cost of captial for capital budgeting purposes.
------------------
(1) New bond issues retire in 30 years and have a constant coupon rate.
(2) For 1984 through 1966, not of tax rates were used, for 19g7 and on, gross rates were used because of changes to the tax law.
(3) Sane issued
i
V
Utility Service Area: Southern California Form R-17B '
Date Filed: September 1987 CEC Contact: Richard Grix
Utility Contact: Ron Schroeder FINANCIAL VARIABLES ON Phone: (916) 324-3146
Phone: (818) 302-9514 LIFE OF PLANT BY ASSET TYPE
1. Average Tax Life of Net Plant Assets in Service:
2. Average Book Life of Net Plant Assets in Service:
3. For each plant type listed provide the life of the plant by asset type:
Economic Book Federal Tax State Tax
-------------------------------------------------------------------------------------------------------------
Nuclear
Coal--Conventional
--Advanced
Oil and Gas Steam Please refer to
Combustion Turbine
Cogeneration Appendix II
Biomass of
Geothermal--Vapor Form R-11
--Liquid
(Note: The economic life is equal to the book life)
Wind
Solar--Photovoltaic
--Thermal
Fuel Cells
Hydro
Pumped Storage
Transmission
Distribution
Pollution Control
(indicate whre distinguishable
Other
Utility Service Area: Southern California Edison Fora R-18
Data Filed: September, 1987 CEC Contact: Richard Grix
Utility contact: Ron Schroeder P Phone: (818) 302-9514 hone: (916) 324-3146
INFLATION, DISCOUNT, AND ESCALATION RATES
1984 1985 1986 1987 1988 1989 19" 1991 1992 1993 1994 1995 1996 1997 1998 1999
Actual Actual Actual
1. GENERAL RATE OF INFLATION (I) 3.7 3.2 2.6 2.6 3.5 3.7 3.7 4.3 4.9 5.2 5.4 5.6 5,.6 5.6 5.5 5.4
2. NOMINAL DISCOUNT RATE* (1) 15.00 14.66 13.70 12.65 12.65 12.65 12.65 12.65 12.65 12.65 12.65 12.65 12.65 12.65 12.65 12.65
3. REAL ESCALATION RATES (I)
A. General Construction Costs
Nuclear .3 (.2) (.6) .4 .5 .3 .3 .7 11 (.2) (.4) (.6) (.6) (.6) (.5) (.4}
Coal--Conventional
--Advanced
Oil and Gas Steam
Combustion Turbine,
Cogeneration
Biomass '.
Geothermal--Vapor
--Liquid
Wind
Solar--Photovoltaic
--Thermal
Fuel Cells '.
' Hydro
Pumped Storage .3 (.2) (.6)
Transmission (.7) (2.2) (1.6)
Distribution (I.7) (1.2) (.6)
Pollution Control .3 ) (
Other (.7) (1.2) (.6) .4 .5 .3 .3 .7 .1 (.1) (.4) (.6) (.6) (.6)
a. Fuel CostsNucl '.
Coal`t! MA NA NA hA 3 3 3 3 1 1 Y 1 1 1
NA NA NA NA (1.1) (1.1) (1.1) 1.1 1.1 1.1 1.1 1.1 1.2 1.2 1.2 1.2
Natural Gas (5.8) (15.4) (39.1) NA 3.6 3.6 3.6 3.9 3.9 3.9 3.9 3.9 3.1 3.1 3.1 3.1
Residual Oil (I0.5) (7.3) (3.9) NA 3.6 3.6 3.6 3.9 3.9 3.9 3.9 3.9 3.1 3.1 3.1 3.1
Distillate OHM NA NA NA NA 3.7 3.7 3.7 3.6 3.6 3.6 3.6 3.6 2.9 2.9 2.9 2.9
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Utility Service Area: Southern California Edison Form R-18
Date Filed: September, 1987 CEC Contact: Richard Grix
Utility Contact: Ron Schroeder Phone: (916) 324-3146
Phone: (818) 302-9514
INFLATION, DISCOUNT, AND ESCALATION RATES
i (Continued)
1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
Actual Actual Actual
C. OEM
Labor 2.0 2.6 1.3 .9 .0 (.2) (.2) .7 1.0 .9 1.1 1.2 1.2 1.2 1.2 1.3
Materials (.5) (.3) (.7) .9 .5 .2 .3 .4 .3 .4 .7 .7 ,7 .7 .7 ,7
TOTAL LABOR/MATERIALS .5 .9 .3 .9 .3 .0 .1 .4 .6 .6 .8 .9 .9 .9 .9 .9
D. Purchases
PURPA Purchases
Energy -8.4% -15.4% 6.1% -1.87. 13.1% 9.1% 7.8% 8.2% 6.9% 8.0% 6.7% 3.8% 4.2% 4.2% 0.7%
Capacity 14.4% 13.5% 3.7% 8.9% 3.0% 0.8% -0.2% 0.6% 0.8% 0.7% 1.7% 2.8% 0.3% 0.2% 0.4%
SCF.'s Average Cost of Capital
NOTE: Numbers in parentheses represent deescalation.
(1) Based on Generic coal price forecast.
(2 Based on turbine fuel price forecast.
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Utflity Service Area.- Southern Catifomis Edison Financial Anotysis
Dote Filed: September 1917 (Investor Owned Utilities) Force R•19P p. t of 4
Utility Contact: Ron Schroeder CEC contact: Richard GrfR
Phone: (31e) 302.9514 Phone: (916) 324.31"
1964 1965 1956
Actual Actual Actuot 1937 1958 1959 1990 1991 1992 1993 1994 1995 1996 1997 IM 19P9
...................._................................_.................._....._......._._........................................
Prices (cants/kWh)
Ultioote @otsoers (nominal S) 7.50 6.06 5.35 5.44 5.75 9.45 9.55 9.79 10.07 10.38 10.83 11.27 11.67 11.99 12.31 12.70
Uttfmta Custown (1905 S) 6.19 8.09 7.95 7.65 7.56 7.77 7.45 7.31 7.16 7.03 6.96 6.92 6.82 6.69 6.53 6.42
Whetewtt 5.06 6.12 6.17 Cnot available)
sales Oltn '.
Ultimate Cuotaasra 56,271 59,30Z 60,430 63,450 64,00 65,960 6T,380 69,273 70,732 71,639 72,596 73,550 74,617 75,327 77,132 76,500
IEaaleools 5.039 5166T 3.767 No no no a" No 1160 me S60 No WO 860 am 660
TOTAL 63,310 64,W 64,197 64,310 65.740 66,530 65,240 70,133 71,592 72,499 73,459 74.440 75,477 76,657 77,992 79,360
C.epitat Mgdrd(1)
Constriction SM $1,076 $1,090 S1,023 SUP $SSS S7W IM ST96 $675 S9% S969 S%6 S1,W St,113 $1,180
Ratin two-Tom Debt 499 09 1,0St 326 204 135 414 171 166 108 163 109 509 140 7 1fI
Rottre PWorred Stock 20 21 19 13 21 23 1s 11 11 11 11 13 13 14 15 13
Other, 0 0 0 64 149 151 152 154 156 156 159 161 1" 1" 166 170
TOTAL WiTAL REWIRED S1,3T1 S1,714 $2,943 $1,446 $1,243 S1,167 St.300 $1,106 51,133 $1,152 S1,349 $1.272 S1,652 $1,357 $1,305 $1,475
Sources of Cepltat (2)
OspreetstieNAnwrtitatim s399 $455 f503 S52S f645 5690 f731 $740 f774 SSOT $639 S879 $912 2942 S966 S994
Other Intel t Sources 5 9 1T 424 2S4 370 230 261 226 213 1ST too 169 17T 135 its
►faposd Financing
Cee.an Stock 209 91 4 0 0 0 0 0 0 0 0 0 0 0 0 0
PWernd Stock 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 D
Lang-Taro Debt 630 1.112 1,427 325 275 250 375 175 200 175 350 225 575 225 200 373
Short-Toro Debt 128 129 "1 171 33 Ct44) 43 (69) (66) (44) (ZT) pp (7) fie 2 CII)
Other 0 D 0 2 2 2 2 2 2 2 2 2 2 2 2 2
TOTAL MKIR EI $1,371 $1,796 $2,943 $1,447 $1,244 $1,165 11,391 S1,109 $1,134 $1,153 $1,351 S1,272 $1,651 S1,356 $1.305 $1,475
..................
(1) Total sptm
(2) Includes the drawdon of pollution control issues and the rollover of high coupon debt at lower interest rates.
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Utility Service Area: Southern California Edison Financial Analysis Forty 1-19P P. 2 of 4
Date Filed: September 1987 (Investor Owned Utilities) CEC contact: Richard Grix
Utility Contact: Ron Schroeder Phone: (916) 324-3146 v
Phone: (818) 302.9514
1984 1985 1986
Actual Actual Actual 1987 1988 1989 f990 1991 1992 1993 1994 1995 1996 1997 1998 1999
................................................................................................................................
Capital Structure
Long-Term Debt
First Mortgage Bands S3,849 $3,771 $4,037 14,785 14,856 S4,971 $4,932 S4,936 $4,967 15,034 $5,200 S5,317 S5,383 $5,465 $5,659 15.922
Debentures 352 234 156 (Included in first Mortgage Bonds)
Other Long-Tors Debt 148 529 578 (included in First Mortgage Bonds)
Assets
Utility Plant at Original Cost $10,906 $11,853 $13,677 S14,827 S16,818 S17,559 $18,624 $19.409 $20,1112 S20,991 S21,807 S22,935 $24,243 $25,211 S26,167 S27,406
• Less Accumulated Depreciation 2,764 3,152 3.556 4,276 4,901 5,571 6,281 7,021 7,794 8,601 9,439 10,318 11,230 12,171 13,137 14,130
Net Utility Plant (electric) 8,142 8,701 10,091 10,551 11,917 11,988 12,343 12,388 12.388 12,390 12,365 12,617 13,013 13.040 13,030 13,276
CWIP (electric) 1,649 2,042 1,342 1,340 275 434 214 234 296 410 657 588 298 419 648 674
Other Assets (less other limb.) 295 494 68 (379) (369) (262) (206) (88) 23 99 155 192 250 322 420 537
TOTAL ASSETS $10,256 $11.237 $11,501 $11,512 $11,823 S12,160 $12,351 S12,534 112,707 $12,899 S13,180 S13,397 S13,561 $13.781 314,098 S14,487
Capitalization and Liabilities
Comm Stock $2,356 SZ,447 $2,450 $4,644 $4,731 $4,818 $4.906 S4,950 $4,994 $5.033 $5.083 $5,128 35,172 $5.266 $5,360 $5,454
Retained Earnings 1,887 2,129 2,344 tlncluded in Cannon Stock)
Total Cowan Equity 4,243 4,575 4,794 4,644 4,731 4,818 4,906 4,950 4,994 5,038 5,083 5,125 5,172 5,266 5,360 5,454
Preferred Stock 908 882 683 657 636 612 597 586 576 564 553 540 527 513 498 485
Mortgage Bonds 3,595 3,755 4,019 4,785 4,856 4,971 4,932 4,936 4,967 5,034 5,200 5,317 5,353 5,468 5,659 5,922
Debentures 754 1,007 752 (Included in First Mortgage Bonds)
Total Long-Ten Debt 5,257 5,644 5,454 5,442 5,492 5,583 5,529 5,522 5,543 5,598 5,753 5,857 5,910 5,931 6,157 6,407
Total Capitalizetion S9,500 S10,219 $10,245 S10,OB6 $10,223 S10,401 $10,435 S10,472 510,537 S1O,636 $10,836 $10,985 $11,082 S11,247 $11,517 S11,861
Accumulated Deferred Inc. Taxes
Due to Accelerated Depreciate 337 532 708 892 1,083 1,261 1.435 1,598 1,726 1,836 1,936 2,024 2,110 2,182 2,248 2,310
Accuoulated Deferred ITC 399 436 545 534 517 500 481 463 445 426 407 389 370 351 333 314
total Liabilities 786 1,018 1,253 1,426 1,600 1,761 1,916 2,061 2,171 2,262 2,343 2,413 2,480 2,533 2,551 2,624
TOTAL CAPITALIZATION S LIABILITIES $10.266 $11,237 $11,501 $11,512 $11.823 S12,162 S12,351 $12,533 $12,708 S12,898 S13,179 $13,398 S13,562 $13,780 S14,098 S14,485
OPERATING REVENUE $4,899 S5,169 $5,312 $5,475 $5,803 S6,376 $6,590 $6,951 $7,300 $7,618 $8,048 S8,487 S8,906 $9,295 S9,699 S10,183
Operating and Maintenance Expenses
Fuel (other than natural gas) $356 $501 S377 S456 $361 $345 $370 $360 $355 S352 $361 $367 S374 S389 S400 $418
Purchases Natural Gas (electric) 1,122 1,182 501 723 524 374 400 410 517 628 789 *1 1,060 1,260 1,391 1,552
PURPA Purchases 61 172 330 418 786 1,263 1,501 1,653 1,764 1,870 1,995 2,139 2,215 2,279 2,367 2,368
Net Purchases from Other Utilities 546 534 446 364 441 473 505 548 603 605 650 665 739 753 354 1,027
70TAL FUEL AND PURCHASED POWER 12,085 $2,359 S1,654 $1,961 S2,112 S2,455 S2,776 S2,971 $3,239 S3,455 S3,795 54,092 $4,398 $4,651 S5,012 S5,365
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Utility Sarvfae Area: Sanharn Caltfarn(a Edison Financial Analysis Fors R-19P p. 3 of 4
Date Filed: September 1967 (Investor Owed Utilities) CEC Contact: Nichard @Tx
Utility Contact: Ron Schroeder Phone: (916) 324-31"
Phone: (513) 3OZ-9514
19" 1985 1986
Actual Actual Actual 1987 1988 1989 1990 1991 1992 1993 1994 199S 1996 1997 1990 1999
................................................................................................................................
Generation;Related ONM S378 S349 $401 $432 SK7 S476 S501 S500 $514 S530 $562 S59t WS $"I S695 $730
Other am 632 637 695 702 721 752 762 809 842 373 929 992 1,059 1,124 1,199 1.280
Cam w Han Expenses 61 84 71 54 61 66 65 66 67 67 69 71 72 74 76 78
TOTAL ON (W fust and purehaaes) $3,176 $3,459 S2,821 $3,149 $3,341 $3,749 S4,104 $4,346 24,662 $4,927 S5,355 25,746 $6,142 S6,540 S6,962 ST,453
DeproctatfaVAmortizattal ISM) CS152) $674 $611 $769 S914 S736 S826 S541 $571 1884 $909 S885 EBBS SM 5850
Tara
rodwal Income Taxis S398 S466 SM $461 $430 SW S423 S471 S511 SS56 $556 SS" $557 $532 SS26 $514
State Income Taxes 57 25 108 (Included In federal Intact Taxes) `
Warred Team (due to Anal Depr) 130 146 in 134 191 178 174 163 128 110 100 88 86 72 66 Q
ITC Adjusdmot (rat) 55 84 39 (11) (16) (19) (18) (18) (19) C19) (19) C19) (19) (19) C19) C19)
Namstfzsd Interest Expanse C7ncludsd In Faderst Inter Teses)
Other Taw (1) t2t 131 143 130 TIP 78 167 134 137 133 13S 140 165 190 203 209
TOTAL TARES $761 2852 S854 ST64 $724 S725 ST" $750 S757 2780 ST72 2773 S789 5795 ST76 ST"
TOTAL OPERATING EXPENSES 23,876 S4,159 54,34P 24,524 $4,04 15,3B8 S5,586 15,922 $6,260 26,573 $7,011 ST,428 S7,1116 $8,190 SB,396 19,069
Other Income and Dedw:tions
Altoamre for Wty finds
lied During Construction 5746 S123 $106 S74 Su $25 S27 S19 S22 S29 340 S42 131 $32 242 $51
ITC Amortization 68 84 97 0 0 0 0 0 0 0 0 0 0 0 0 0
Other-- at 34 48 51 112 52 44 39 36 31 26 19 12 6 2 0 0
TOTAL OTM IMCOrE AND DEDWTIOMS S249 SMS S254 $186 186 $69 S66 $55 S53 S55 $59 S54 $37 $34 S42 $51
OPERATING INC. SEFORE TNT. CNAAGES S1,271 $1,265 S1,217 S1,137 $1,055 S1,05T S1,070 ST,084 $1,093 S1,095 S1,096 S1,113 S1,t27 $1,139 $1,145 $1,165
Interest Charles
Long-term $443 $419 $42.0 $444 S455 U64 S463 S462 S462 $465 1476 $490 S5OZ $511 $526 $50
Short-term ST 69 63 (Included in Long-Term)
Allowance for Narrowed Funds
Used During Casttutt(on (49) (35) (29) (43) (23) (17) (18) (12) (15) (19) C27) (28) (21) (21) (29) (34)
TOTAL INTEREST MUCES $01 U53 $454 $401 S435 S447 S445 $450 $447 $446 $449 $462 $481 S490 S498 $514
1.................
(T) )netuudes Deferred Taxes an Rewtatary Balancing Accents, Other Deferred Taxes, Property Taxes, and Payroll Taxes.
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Utility Service Ares- Southern California Edison Financtat Analysis form R•19P p. 4 of 4
Date Filed: Soptember 1987 (Investor Owned Utilities) CEC contact: Richard Grin 3
Utility Contact: Ron Schroeder Phone: (916) 324-3146
Phone: (813) 302.9514
1984 1985 1986
Actual Actual Actual 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999
.........•....................•............._.............-•---•..----....••.•...............----..................•.--.....--..
Not Income $789 $812 $763 S736 $620 S610 S625 $634 S646 •S649 $647 $651 S646 S649 SW S651
Preferred Dividends 73 72 55 51 50 48 - 46 45 44 43 41 40 39 37 36 35
Balance for CoRtson 716 740 705 685 570 562 579 589 602 606 606 611 607 612 611 616
Rate Rase (1) 8,051 8,646 9,226 9,426 10,420 10,538 10,623 10,717 10,689 10,713 10,705 10,932 11,271 11,410 11,455 11,610
Rate of Return on Rate Rue 12.0% 11.3% 10.5% 11.1% 10.1% 10.2% 10.2% 10.2% 10.2% 10.2% 10.3% 10.3% 10.3% 10.4% 10.4% 10.4%
Rate of Return on Canaan Equity (2) 16.3% 15.7% 15.1% 13.9% 12.0% 12.0% 12.0% 12.0% 12.0% 12.0% 12.0% 12.0% 12.0% 12.OX 12.0X 12.0%
Embedded Interest Rote on Bonds 10.0% 9.9% 9.1% 9.1% 8.6% 8.6% 8.7% 8.6% 8.8% 8.8% 8.9% 9.0% 9.0% 9.2% 9.2% 9.2%
Roody's Coverage Ratios (3)
Before Tax 3.8 3.4 3.4 3.4 3.4 3.4 3.4 3.5 3.5 3.5 3.4 3.3 3.3 3.3 3.2 3.0
After Tax 2.3 2.1 2.1 2.1 2.1 2.1 2.2 2.2 2.3 2.2 2.2 2.2 2.2 2.2 2.1 2.0
Debenture Indenture Coverage
Required 3.5 3.5 3.5 3.5 3.5 3.5 3.5 3.5 3.5 3.5 3.5 3.5 3.5 3.5 3.5 3.5
Expected 4.4 4.8 4.6 (not &vat table)
Revenue Requirements (millions) $4,899 35,169 S5,312 $5,475 $5,803 S6,376 $6,590 S6,951 $7,300 S7,618 S8,048 $8,487 S6,906 $9,295 $9,699 S10,183
...............•..
(1) Assuming eontim atien Of existing regulatory policies (i.e., no CUIP in rate base).
(2) The company's authorized return has been wed for 1987.
for 1968.99, the California Public Utilities Commission Staff has provided these rates, which were also used in the Company's G.D. 1310 filing,
The CPUC Staff also provided assu ptions for incremental cost: Long-Term Debt 9.5% and Preferred Stock 9.25%.
(3) Calculated based on Total Debt Interest.
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