The URL can be used to link to this page

Home My WebLink AboutSCE COMMON FORECASTING METHODOLOGY VII SUPPLY FORMS11111111111111111111111111111111111111 lill 1111111 *NEW FILE* SCE COMMON FORECASTING METHODOLOGY VII SUPPLY FORMS µ r COMMON FORECASTING METHODOLOGY VII SUPPLY FORMS m i 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 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. -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 development of the plan for this submittal: • 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'1999. • 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. The 200 MW Balsam Meadow commenced construction i completion in early 1988. capability is planned in -3- n Hydroelectric Project, which late 19830 is planned for The inclusion of pump storage 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 U01y Servk a Area: Soudwn Callomla Edson 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 Awat 1905 Ackmd 1956 Actual 1907 lose 1989 1990 1991 1992 1993 1994 1995 1996 1997 1999 1999 1. PEAK LOADS' 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 0 0 0 0 0 O 0 0 0 0 0 0 te.CondBord DSM 0 0 0 0 63 126 ISO 266 298 371 449 502 555 631 701 760 TolalPeak 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 1615 Isis 1615 leis lets le15 1616 lets — Advanced 0 0 0 0 0 0 100 100 too 100 too 100 too 100 100 100 2fdDecade Genak: 123 823 C6andGmSban 8672 8672 8380 Bits 7076 7076 7076 7076 7076 7076 7202 7522 7622 7786 7786 7786 C wnbusdon Turbkw Soo Soo 580 580 Soo Soo 580 580 5a0 580 580 Sao 580 Soo Sao Sao Cw*kW 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 t664 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 516 541 541 541 641 '541 VAW 19 46 84 93 98 ill 117 117 117 117 117 117 117 t17 117 117 Solar 1 15 45 105 159 lei 195 202 205 205 205 205 205 205 205 203 As Ava4aMe 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 Sleraos 0 0 0 0 0 0 10 10 10 10 10 10 10 /0 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 538 535 538 538 538- - 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 ilea lies 1199 1180 IIa0 ttbo 1180 11ao PRNATESUPPLY 152 201 225 304 367 447 S39 635 735 836 925 998 1054 1OB4 1-114 1139 TOTALCAPACDY' 17352 17825 18330 18152 ISM 19372 19412 1977E 19790 19828 20159 20601 21005 21408 21805 22305 3._Sdrdu19dM*ftnaroe 0 0 0 0 0 0 0 0 0 0 a 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 Moon 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 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 16868 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. a J R Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES Phone: (818) 302-9514 Form R-3A p. 1 of 4 CEC Contact: Pat McAuliffe 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 .___ (NW) ......... (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.OD 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 a 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. Utility Service Area: Southern California Edison Date filed: September, 1967 Utility Contact: Ron Schroeder EXISTING AM PLANNED UTILITY OWNED THERMAL RESOURCES Pharr: (413) 302-9514 Fors 1-3A p. 1 of 4 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 unit installed Dependable Average Met location Dote Percent Unit Loading Fuel Cspaeity Capacity Annuat Energy Air Water Plant Name and Unit Number Install/Modified Ownership Type Code Typo (MU) (MW) (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 ELLWOD 1 Aug, 74 100.00 CT 3 G 56.70 46.00 1.97 42 S8A Cc ETIIWANDA 1 Jul, 53 100.00 ST 2 G 12Z.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 X ETIIMNDA 2 Nov, 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 SC ETiWIMDA 3 May, 63 100.00 •T 2 S 333.OD 320.00 "1.28 36 SC SC ETIWMDA 3 May, 63 100.00 ST 2 0 333.00 320.00 "1.28 36 SC SC ETIMANDA 4 Oct, 63 100.00 ST 2 G 333.00 320.00 009.30 36 fC SC ETIMANDA 4 Oct, 63 100.00 ST 2 O 333.00 320.00 80.30 36 SC Sc ETIWMDA 5 Jan, 69 100.00 CT 5 0 138.13 126.00 5.85 36 SC SC ETI4MMDA 5 Jan, 69 100.00 CT 5 G 139.13 126.00 5.85 36 Sc SC HIUR CONNERs 4 JUL. 69 48.00 ST 1 DO 392.69 376.32 2.309.00 64 FOM CORNERS 5 Jut, 70 48.00 ST 1 CO 392.69 376.32 2.272.00 64 MIGIGROYE 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 NIGMGIGVE 2 Jul, 52 100.00 ST 2 G 34.50 32.50 3.42 36 SC SC RIGNGIOVE 2 Jul, 52 100.00 ST 2 0 34.50 32.50 3.42 36 SC SC NIGNGROVE 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 NIGNGROVE 4 Oct, 55 100.00 ST 2 G 50.00 44.50 9.19 36 SC se N14OW E 4 Oct, 55 100.00 ST 2 O 50.00 44.50 9.19 36 SC SC Note: A Unit loading Code of 6 iadtcates these units have been retired and will not be operated without a 6 Month *Nance notice. Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES Phone: (818) 302-9514 Date Percent Unit Plant Name and Unit Number Install/Modified Ownership Type ________________ _________ ---- HUNTINGTON 1 HUNTINGTON 1 HUNTINGTON 2 HUNTINGTON 2 HUNTINGTON 3 HUNTINGTON 3 HUNTINGTON 4 HUNTINGTON 4 HUNTINGTON 5 HUNTINGTON 5 LONG BEACH 8 LONG BEACH 8 LONG BEACH 8 LONG BEACH 8 LONG BEACH 9 LONG BEACH 9 LONG BEACH 9 LONG BEACH 9 MANDALAY 1 MANDALAY 1 MANDALAY 2 MANDALAY 2 MANDALAY 3 MOHAVE 1 MOHAVE 2 ORMOND BEACH 1 ORMOND BEACH 1 ORMOND BEACH 2 Jun, 58 Jun, 58 Dec, 58 Dec, 58 May, 61 May, 61 Jul, 61 Jul, 61 Apr, 69 Apr, 69 Dec, 76 Dec, 76 Dec, 76 Dec, 76 Apr, 77 Apr, 77 Apr, 77 Apr, 77 May, 59 May, 59 Aug, 59 Aug, 59 Apr, 70 Apr, 71 Oct, 71 Dec, 71 Dec, 71 Jun, 73 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 56.00 56.00 100.00 100.00 100.00 ST ST ST ST ST ST ST ST CT CT CT CT ST ST CT CT ST ST ST ST ST ST CT ST ST ST ST ST Unit Loading Code 2 2 2 2 2 2 2 2 5 5 3 3 3 3 3 3 3 3 2 2 2 2 5 1 1 2 2 2 Fuel Type G 0 G 0 G 0 G 0 D G D G D G D G D G G 0 G 0 D CO CO G 0 G Installed Capacity (MW) 217.60 217.60 217.60 217.60 217.60 217.60 217.60 217.60 138.13 138.13 249.50 249.50 85.00 85.00 188.72 1a8.72 63.28 63.28 217.60 217.60 217.60 217.60 138.13 458.14 458.14 806.40 806.40 806.40 Form R-3A p. 1 of 4 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 Dependable Average Net Location Capacity Annual Energy Air Water (MW) (GWH) Canty Basin Region 215.00 215.00 215.00 215.00 215.00 I 215.00 225.00 225.00 133.00 133.00 226.00 226.00 77.00 77.00 170.00 170.00 57.00 57.00 215.00 215.00 215.00 215.00 140.00 442.40 442.40 750.00 750.00 750.00 640.42 640.42 673.88 673.88 594.82 594.82 505.52 505.52 6.80 6.80 909.50 909.50 658.45 658.45 686.63 686.63 4.62 2,504.00 2,688.00 1,949.80 1,949.80 1,812.27 Note: A Unit Loading Code of 6 indicates these units have been retired and will not be operated without a 6 month advance notice. 30 30 30 30 30 30 30 30 30 30 19 19 19 19 19 19 19 19 56 56 56 56 56 60 60 56 56 56 SC SC SC SC SC SC SC SC SC SC SC SC SC SC SC SC SC SC YAP VAP VAP VAP VAP VAP VAP YAP SC SC SC SC SC SC SC SC SC SC SC SC SC SC SC SC SC SC CC CC CC cc CC Utility Service Arts: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder EXISTING AND PUNNED UTILITY OWNED TMERM4L RESOURCES Phone: (918) 302.9514 Date Plant Name and Unit Number .......................... Inatatl/Modified ................ aRMogD NEACN 2 Jun, 73 PALO VERDE 1 Feb, a6 PALO VERDE 2 Sap, 36 PALO VERDE 3 Sap, 86 REDONDO 1 Her, 48 REDONDO 1 Her, 48 REDONDO 2 Apr, 48 REDONDO 2 Apr, 48 REDONDO 3 Aug, 49 REDONDO 3 Ay, 49 REDONDO 4 Oct, 49 REDONDO 4 Oct, 49 REDONDO 5 Oct, 54 REDONDO 5 Oct, 54 REDONDO 6 JUL, 57 REDONDO 6 Jut, 57 ,REDONDO 7 Feb, 67 Room 7 Feb, 67 ROMMO a Jut, 67 REDONDO 8 Jut, 67 SAN NERMARDINO 1 Jun, 57 SAN SERNAMDINO 1 Jun, 57 SAN MERNMNINO 2 Jul, 55 SAN NERMANDINO 2 Jul, 58 SAN OMOFRE 1 Jan, 68 SAN ONOFRE 2 Aug, a3 SAN ONDFRE 3 Apr, 84 TOTAL Fua R-3A p. 1 of 4 CEC Contact: Pat Mdwliffe Phone: (916) 324.3602 Unit Installed Dependable Average Met Location Percent Unit Loading Fuel Capacity Capacity Annual Energy Air Water ownership ......... Type .... Code ------- Type .... (NW) ......... (MW) .......... (GUM) ............. County Ntsin Region 100.00 ST 2 a 806.40 750.00 1,812.27 ........ 56 I............. YAP CC 15.80 RU 1 MU 217.25 193.08 1,300.00 97 15.80 MU i MU 217.25 193.05 1,300.00 97 15.80 NU 1 NU 217.25 193.08 1,300.00 97 100.00 ST 6 6 66.00 74.00 83.73 19 SC SC 100.00 ST 6 0 66.00 74.00 83.73 19 SC SC 100.00 ST 6 G 69.00 74.00 60.62 19 SC SC 100.00 ST 6 0 69.00 74.00 60.62 19 SC SC 100.00 ST 6 6 66.00 70.00 64.50 19 SC SC 100.00 ST 6 0 ".D0 70.00 64.50 19 SC SC 100.00 ST 6 G 69.00 74.Do 73.K 19 SC SC 100.00 ST 6 0 . 69.00 74.00 73.44 19 SC SC 100.00 ST 2 G 156.25 175.00 291.24 19 SC SC 100.00 ST 2 0 156.25 175.00 291.24 19 SC SC 100.00 $T 2 6 163.20 175.00 243.00 19 SC SC 100.00 ST 2 0 163.20 175.OD 243.00 19 SC SC 100.09 ST 2 6 495.00 480.00 1."2.70 19 SC SC 100.00 ST 2 0 493.00 480.00 1,442.70 19 SC SC 100.00 ST 2 G 493.00 40.00 1.56a.06 H gC gC 100.00 ST 2 0, 495.00 480.00 1,568.06 19 SC SC 100.00 ST 2 6 65.28 63.00 100.13 36 SNE SA 100.00 ST 2 0 45.29 63.00 105.13 36 SNE SA 100.00 ST 2 G 65.28 63.00 92.24 36 SDE SA 100.00 ST 2 O 65.28 63.00 92.24 36 SNE SA MOO NU 1 NU 364.a0 34a.a0 2,050.00 37 SO SO 75.05 NU 1 NU 845.81 803.03 5,300.00 37 S0 SO 75.05 NU 1 MU 845.81 810.54 5,300.00 37' SO SO 25491.38 24627.02 73,382.54 Note: A Unit Loading Code of 6 indicates these units have been retired and Witt not be operated without a 6 month advance notice. 4 Utility Service Area: Southern California Edision Date Filed: September, 1987 Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES Phone:(818)302-9514 LEVEL 1 LEVEL 2 Minimum Generation 25% of Dependable Cap -------------------- Capacity Heat Rate ------------------- Capacity Heat Rate Plant Name and Unit Number (HU) (Btu/kWh) (HU) (Btu/kWh) .......................... ALAMITOS 1 ........ 10 ......... 25473 ........ 44 _-------- 12997 ALAMITOS 1 15 21011 44 12461 ALAMITOS 2 10 25473 44 12997 ALAMITOS 2 15 21011 44 12461 ALAMITOS 3 20 22048 80 12066 ALAMITOS 3 40 15136 80 11601 ALAMITOS 4 20 22048 80 12066 ALAMITOS 4 40 15136 80 11601 ALAMITOS 5 70 14177 120 11973 ALAMITOS 5 150 10904 120 11486 ALAMITOS 6 70 14177 120 11973 ALAMITOS 6 150 1D904 120 11486 ALAMITOS 7 1 33 ALAMITOS 7 1 33 COOL WATER 1 1 73442 16 13040 COOL WATER 1 21 12159 16 13368 COOL WATER 2 17 13165 20 12537 COOL WATER 2 25 11530 20 12224 COOL WATER 3 6 34 COOL WATER 3 6 34 COOL WATER 3 50 26 COOL WATER 3 50 26 COOL WATER 4 6 34 COOL WATER 4 6 34 COOL WATER 4 50 26 COOL WATER 4 50 26 EL SEGUNDO 1 10 25725 44 13125 EL SEGUNDO 1 20 16482 44 12399 LEVEL 3 50% of Dependable Cap --------------------- capacity Heat Rate (HW) (Btu/kWh) ........ 87 ......--- 11250 87 10576 87 11250 87 10576 160 10456 160 10290 160 10456 160 10290 240 10489 240 10065 240 10489 240 10065 66 66 32 11120 32 10916 40 10830 40 10518 68 68 52 52 68 68 52 52 87 11361 87 11010 Form R-3A p. 2 of 4 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 LEVEL,4 80% of Dependable Cap ----------------------- Capacity Heat Rate (HW) (Btu/kWh) 139 10751 139 10146 139 10751 139 10146 255 9972 255 9921 255 9972 255 9921 383 10038 383 9632 383 10038 383 9632 106 106 51 10519 51 10189 64 10337 64 9990 108 108 83 83 108 108 83 83 139 10857 139 10707 h Utility service Area: Southern California Edision Date Filed: September, 1967' Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OAHM THERMAL RESOURCES Phone:(81a)302.9514 LEVEL I LEVEL 2 Ninimum� Generation 25% of Dependable Cap ..................... .................... Capacity Neat Rate Capacity Neat Rate Plant Mmw and Unit Number (MW) (RtulkWh) MIA) (RtWkWh) .._...--- .......................... EL SEGUNDO 2 ........ 10 ......... 25725 ........ 44 13125 EL SEGUMOO 2 20 16452 44 12399 EL SEGUMDO 3 20 222" 84 12027 EL SEGUNDO 3 70 13494 84 12521 EL SEGUNDO 4 20 22266 a4 12027 EL SEGUNW 4 70 13494 34 12521 ELLW00D 1 1 12 ELLUM 1 1 12 ET)WNOA 1 10 22145 33 13139 ETIWNDA 1 20 15966 33 13061 ETIW MA 2 10 22145 33 13139 ETIMAMDA 2 20 15966 33 13061 ETIWMOA 3 20 22057 a0 12509 ET/WIOA 3 75 11795 80 115" ETIWMNDA 4 20 22859 80 12509 ETIWMDA 4 75 11795 a0 1-1589 ETIWMDA 5 1 32 ETIWMDA 5 1 32 FOUR CORNERS 4 132 94 ' ram CORNERS 5 132 94 NIGMGROVE 1 4 35270 a MN MIGNGROVE 1 7 23662 a 21083 MIGNGRM 2 4 35270 a 22569 NiGMMOVE 2 7 23662 a ' 21a" NIGMGMOVE 3 5 32671 11 20013 MIGMGROVE 3 12 23960 11 25103 NIGMGROVE 4 5 32671 11 2W13 NIGMGROVE 4 12 23960 11 25103 Font R-3A P. 2 of 4 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 LEVEL 3 LEVEL 4 50% of Dependable Cap ---"................ BOX of Dependable, Cap ....................... Capacity Neat Rate Capacity most Rate (NW) (Btu/kWh) (NY) ........ (Btu/kWh) ......... -------- 117 ......... 11361 139 IMT 87, 11010 139 MOT 167 10495 26T 10050 167 10374 267 9699 167 10495 267 10050 16T 10374 267 96" 24 38 24 38 66 11348 105 low 66 11046 105 10621 66 1134a 105 100" 66 11046 105 10621 160 1Oa40 255 10339 160 10279 255 9910 160 10640 255 10339 160 10279 255 9910 63 100 63 100 IDS 301 188 301 16 16313 25 14175 16 15714 25 13586 tb 16313 25 14175 16 15714 25 135M 22 14798 35 12945 22 law 35 16681 22 14798 35 12945 - 22 - 1a509 35 16691 Y 2 Utility Service Area: Southern California Edision Date Filed: September, 1987 Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES Phone:(818)302-9514 Plant Name and Unit Number HUNTINGTON 1 HUNTINGTON 1 HUNTINGTON 2 HUNTINGTON 2 HUNTINGTON 3 HUNTINGTON 3 HUNTINGTON 4 HUNTINGTON 4 HUNTINGTON 5 HUNTINGTON 5 LONG BEACH 8 LONG BEACH 8 LONG BEACH 8 LONG BEACH 8 LONG BEACH 9 LONG BEACH 9 LONG BEACH 9 LONG BEACH 9 MANDALAY 1 MANDALAY 1 MANDALAY 2 MANDALAY 2 MANDALAY 3 MOHAVE 1 MOHAVE 2 ORMOND BEACH 1 ORMOND BEACH 1 ORMOND BEACH 2 LEVEL 1 Minimum Generation Capacity (MW) 20 30 20 30 90 90 90 90 1 1 3 3 55 55 3 3 55 55 20 24 20 24 1 140 140 250 250 50 Heat Rate (Btu/kWh) 16094 12599 16094 14707 10681 10153 10750 10153 16404 12589 16404 12589 11180 10219 20560 LEVEL 2 25% of Dependable Cap ..................... Capacity Heat Rate (MW) (Btu/kWh) 54 11759 54 10624 54 11759 54 118M 54 11813 54 11211 56 11997 56 11116 33 33 57 57 19 19 43 43 14 14 54 11528 54 10185 54 11528 54 10185 35 111 ill 188 11938 188 10872 188 11938 LEVEL 3 50% of Dependable Cap ..................... Capacity Heat Rate (MW) (Btu/kWh) -------- 107 --------- 10570 107 9649 107 10570 107 10240 107 10428 107 9907 112 10424 112 9850 66 66 113 113 38 38 85 85 28 28 107 10155 107 9266 107 10155 107 9266 70 221 221 375 10452 375 9669 375 10452 Form R-3A p. 2 of 4 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 LEVEL 4 80% of Dependable Cap ----------------------- Capacity Heat Rate (HW) (Btu/kWh) 171 171 171 171 171 171 179 179 106 106 180 180 61 61 135 135 45 45 171 171 171 171 ill 353 353 599 599 599 10218 9359 10218 9679 10029 9469 10060 9446 9763 8977 9763 8977 1OD99 9443 10099 K Utility Service Area: Southern California Edision Date Filed: September, 1987 Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED TNERNAL RESOURCES Phone:(818)302-9514 Plant Name and Unit Number ORMONO KACN 2 PALO VERDE 1 PALO VERDE 2 PALO VERDE 3 REDONDO 1 REDONDO 1 REDONDO 2 REDONDO 2 REDONDO 3 REDONDO 3 REDONDO 4 REDONDO 4 REDONDO 5 REDONDO, 5 REDONDO 6 REDONDO 6 REDONDO 7 REDONDO 7 REDONDO 8 REDONDO 9 SAN BERNARDINO 1 SAN BERNARDINO 1 SO BERNARDINO 2 SAN BERNARDINO 2 SAN ONOFNE I SAN ONDFRE 2 SAN OMOFRE 3 _ LEVEL 1 Mininn Generation .................... Capacity Rest Rate (Mlq ........ (Btu/kWh) ....... 250 10219 0 0 0 3 3982a a 21302 3 37267 a 2MV 3 39MB a 21302 3 3T267 a 20569 16 25473 15 21011 10 25473 15 21011 70 13638 150 10310 7 59M 15 29136 7 17M 17 125% 7 17856 17 12504 50 w 300 t LEVEL 2 25% of Dependable Cap --------------------- Capacity Neat Rate (MW) (atu/kwk) 18a 10672 4a 48 48 19 16604 19 15659 19 16335 19 15474 18 16646 la 15886 19 16335 19 15474 K 1249T K 12"1 K 12997 K 12461 120 11517 120 10805 120 11517 120 lows 16 12a0a 16 12793 16 12a0a 16 12793 87 201 203 LEVEL 3 50% of Dependable Cap ..................... Capacity Nest Rate (MU) (Btu/kWh) 375 9669 96 96 96 37 14518 37 13M 37 14433 3T 13738 35 14639 35 13804 37 14433 3T 13738 a7 11250 87 10576 37 11250 87 10576 240 10090 240 9570 240 10090 240 9570 31 109M 31 10515 31 10980 31 10515 174 401 405 Form R-3A p. 2 of 4 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 LEVEL 4 80% of Dependable Cap ----------------------- Capacity Rest Rate (MM) (NtufkWh) 599 9K3 154 154 154 59 13971 59 13173 59 13711 59 13300 5S 13967 55 13169 59 Ml 59 13300 139 10751 139 101" 139 10751 139 101" 383 %% 383 9130 ?a 96% 383 9130 5o 1030 50 9770 50 10348 50 9T70 277 642 648 i t Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES Phone: (818) 302-9514 Plant Name and Unit Number ALAMITOS 1 ALAMITOS 1 ALAMITOS 2 ALAMITOS 2 ALAMITOS 3 ALAMITOS 3 ALAMITOS 4 ALAMITOS 4 ALAMITOS 5 ALAMITOS 5 ALAMITOS 6 ALAMITOS 6 ALAMITOS 7 ALAMITOS 7 COOL WATER 1 COOL WATER 1 COOL WATER 2 COOL WATER 2 COOL WATER 3 COOL WATER 3 COOL WATER 3 COOL WATER 3 COOL WATER 4 COOL WATER 4 COOL WATER 4 COOL WATER 4 EL SEGUNDO 1 EL SEGUNDO 1 LEVEL 5 Maximum Generation Capacity Heat Rate (MW) (Btu/kWh) -------- 175 --------- 10809 175 10143 175 10809 175 10143 320 9941 320 9806 320 9941 320 9806 480 9964 480 9556 480 9964 480 9556 147 147 65 10391 65 10011 81 10289 81 9938 73 73 110 110 73 73 110 110 175 1D916 175 10683 Start-up Fuel (MMetu/start) 2527.10 2527.10 2527.10 2527.10 4518.10 4518.10 4518.10 4518.10 6181.50 6181.50 6181.50 6181.50 130.00 130.00 748.00 748.00 923.20 923.20 1900.00 1900.00 20.00 20.00 1900.00 1900.00 20.00 20.00 2527.10 2527.10 Fuel Characteristics Heat content Percent Percent (Btu/Unit) Grade Ash Sulfur ------------------------------------------------- 6.00 6.00 6.00 6.00 6 .040 .25 6.00 6.00 5.40 .001 .10 2 6.00 6 .040 6.00 5.40 2 .001 1050.00 5.40 1050.00 6.00 .25 10 Form R-3A p. 3 of 4 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 0 Utility Service Area: Southern California Edison Date Filed: September, 1967 Utility Concect:Ron Schroeder ERISTING AND PLANNED UTILITY OWNED TNERNAL RESOURCES Phone: (E15) 302-9514 Plant Name and Unit Number EL SEGUNDO 2 EL SEGUNDO 2 EL SEGUNDO 3 EL SEGUNDO 3 EL SEGUNDO 4 EL SEGUNDO 4 ELLWOOD 1 ELLWOOD 1 ETIWNDA 1 ETIWWDA 1 ETIWNDA 2 ETIMA DA 2 ETIWNDA 3 ETIW MDA 3 ETIWNDA 4 ETIVANDA 4 ETIWNIDA 5 EMMA 5 FOWL CORNERS 4 FOUR CORNERS 5 NIGNGROVE 1 NIGNGROVE 1 NIGNGROVE 2 NIGNGROVE 2 N10NGw A NIGNPKNr- 3 - N16tlGROVE 4 NIGNGRM 4 LEVEL 5 Maxima Generation Capacity Neat Rate (MN) (Btu/kWh) .....---- ........ 175 10916 175 10653 335 10059 335 9456 335 10059 335 94E6 53 53 132 10E67 132 10671 132 10E67 132 10671 320 10306 320 9795 320 10306 320 9795 142 142 376 376 32 13423 32 12M 32 13423 32 12E26 45 12315 45 1652E 45 12315 45 1652E Start -Up Fuel (NIRtu/start) 252T.10 2527.10 451E.10 451E.10 451E.10 451E.10 1E34.40 1E34.40 1E34.40 1834.40 451E_10 451E_10 451E.10 451E.10 130.00 130.00 5275-00 5275.00 239.90 239.90 239.90 239.90 326.90 326.90 326.90 326.90 Fuel characteristics Neat content Percent Percent (MAIM grade Ash Sulfur ................................................. 6.00 6.00 6.00 5.40 6.00 6 .040 .25 6A0 6 .004 .25 6.OD 6.G6 5.40 2 .001 .10 17.60 22.000 .60 17.60 6.00 6.00 6 .040 .25 6.00 6.00 Form R-3A p. 3 of 4 CEC Contact: Pat NCAullffe Phone: (916) 324-3602 Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact:Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES Phone: (818) 302-9514 Plant New and Unit Number .......................... HUNTINGTON 1 HUNTINGTON 1 HUNTINGTON 2 HUNTINGTON 2 HUNTINGTON 3 HUNTINGTON 3 HUNTINGTON 4 HUNTINGTON 4 HUNTINGTON 5 HUNTINGTON 5 LONG BEACH 8 LONG BEACH 8 LONG BEACH 8 LONG BEACH 8 LONG BEACH 9 LONG BEACH 9 LONG BEACH 9 LONG BEACH 9 MANDALAY 1 MANDALAY 1 MANDALAY 2 MANDALAY 2 MANDALAY 3 MOHAVE 1 MOHAVE 2 ORMOND BEACH 1 ORMOND BEACH 1 ORMOND BEACH 2 LEVEL 5 Maximun Generation Capacity Heat Rate (MW) (Btu/kWh) ........ 215 ......... 10169 215 9268 215 10169 215 9505 215 10021 215 9406 225 9986 225 9415 147 147 60 60 80 80 60 60 60 60 215 9805 215 8936 215 9805 215 8936 215 442 442 750 10279 750 9451 750 10279 Start -Up Fuel Characteristics Fuel Heat content Percent Percent (MMBtu/start) (Btu/Unit) ------......-------.-............................. Grade Ash Sulfur ............. 2989.10 2989.10 6.00 2989.10 2989.10 6.00 3022.00 3022.00 6.00 6 .040 .25 3022.00 3022.00 6.00 130.00 5.40 2 .001 .10 130.00 20.00 5.40 20.00 1000.00 1000.00 1050.00 20.00 5.40 20.00 1000.00 1000.00 1050.00 2 .001 .10 Z989.10 2989.10 6.00 6 .040 .25 2989.10 2989.10 6.00 130.00 5.40 2 .001 .25 6077.00 21.90 10.500 .39 6077.00 21.90 10302.00 10302.00 6.00 6 .040 .25 10302.00 Form R-3A p. 3 of 4 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 Utility Service Area: Southern California Edison Date Filed: September, 1967 Utility Contect:Ron Schroeder EXISTING AND PLANNED UTILITY OWED TMERNAL RESOURCES Phone: (813) 302-9514 LEVEL 5 Maximum Generation Capacity Meet Rate Plant Maine and Unit Muller -------------------------- (NY) ........ (Stu/kWh) ORMOND MEACM 2 750 ......... 9451 PALO VERDE 1 193 PALO VERDE 2 193 PALO VERDE 3 0 REDONDO 1 74 14E29 REDONDO 1 74 13905 REDONDO 2 74 13510 REDONDO 2 74 13573 REDONDO 3 70 14404 REDONDO 3 70 135E2 REDONDO 4 74 13510 REDONDO 4 74 13573 REDONDO 5 175 10009 REDONDO i 175 10143 REDONDO 6 175 10E09 REDONDO 6 175 10143 REDONDO 7 4E0 93M REDONDO 7 4D0 9045 REDONDO E 4E0 95E5 REDONDO a 4E0 9045 SAN BERK40100 1 63 10215 SAN BERNARDINO 1 63 9596 SAN RFRMAROINO 2 63 10215 SAN SOMANDINO 2 63 95% "OMOFAtE 1 349 .SM! Own :j E03 FAN Qil "i 3 _ In Start -Up Fuel Characteristics Fuel Meat content Percent Percent 0001tu/start) (Rtu/Unit) Grade Ash Sulfur ........................................................... 10302.00 6.00 277.20 277.20 6.00 277.20 277.20 6.00 277.20 277.20 6.00 277.20 277.20 6.00 2527.10 2527.10 6.00 2527.10 2527.10 6.00 6191-50 6191.50 6.00 6181.50 6181.50 6.00 723.10 723.10 6.00 723.10 723.10 6.00 2.55 2.55 2.55 6 .040 .25 6 .040 .25 Farm R-3A p. 3 of 4 CEC Contact: Pat McAutiffo Phone: (916) 324-3602 4 Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES Phone: (818) 302-9514 Fixed Variable 0 & M costs 0 & M Costs Plant Name and Unit Nuber (1986f/MWh) (1986$/MWh) .......................... 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 Instant Capital Costs Expenditures 0985S) As of 12/31/85 Status Form R-3A p. 3 of 4 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 Utility Service Area: Southern Catifornia Edison Date filed: September, 1967 Utility Contact: Ron Schroeder EXISTING AND PUNNED UTILITY OIMED THERMAL RESOURCES Phone: (818) 302-9514 Fixed Variable Instant 0 t If Costs 0 It M Costs Capital Costs Plant Name and Unit INMber (1966IMA) (196"MA) 0965S) NIGNGROVE 3 9D00.00 .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 BEACH a 9000.00 .30 LONG REACH a 9000.00 .30 LONG REACH 9 9000.00 .30 LONG BEACH 9 9000.00 .30 MANDALAY 1 11000.00 .10 NANDALAY 2 11000.00 .10 MANDALAY 3 4400.00 .10 MOHAVE 1 25300.00 1.70 HONAVE 2 2530D.00 1.70 GRMOHD BEACH 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 PEBBLY BEACH -DIESEL a .00 PEBBLY BEACH -DIESEL 10 .00 PEBBLY BEACN-DIESEL it .00 PEBBLY BEACH -DIESEL 12 .OD REDONDO 1 11ODO.00 .10 REDONDO 2 11000.00 .10 REDONDO 3 11000.00 .10 REDONDO 4 llwq.QQ .10 _ Expdsii tures As of 12/31/85 Status Fona R-3A p. 3 of 4 CEC Contact: Pat McAutiffe Phone: (916) 324-3602 t Utility Service Area. Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder EXISTING AND PLANNED UTILITY OWNED THERMAL RESOURCES Phone: (818) 302-9514 Fixed Variable Instant O & M Costs 0 & M Costs Capital Costs Plant Name and Unit Number (1986a/MWh) (1986$/MWh) (1985S) .......................... ............ ....... I--- -..-.-----.-. 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 SAN ONOFRE 1 61500.00 .OD SAN ONOFRE 2 61500.00 .00 SAN ONOFRE 3 61500.00 .00 Expenditures As of 12/31/85 Status Form R-3A p. 3 of 4 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact- Ron Schroeder EXISTING AND PLANNED UTILITY OWNED MYDRS RESOURCES Phone: (918) 302-9514 instatted Dependable Average Met Date Percent Capacity Capacity Amuat Energy Ptant Name and Unit Number -------------------------- Install/Hodified Ownership --------- (CAA) --------- (MW) (GUN) BIG CREEK 1 1 ---------------- Nov, 13 100.00 14.00 .......... 17.50 ............. BIG CREEK 1 2 Mow, 13 100.00 14.00 17.00 575.00 BIG CREEK 1 3 Jut, 23 100.00 14.00 17.20 SIG CREEK 1 4 Jun, 25 100.00 28.00 31.20 SIG CREEK 2 3 Dec, 13 100.00 14.00 15.80 BIG CREEK 2 4 Jan, 14 100.00 14.00 15.60 505.00 BIG CREEK 2 5 Feb, 21 100.00 17.50 16.90 SIG CREEK 2 6 Her, 25 100.00 17.50 15.30 BIG CREEK 2A 1 Aug, 28 MOO 40.00 46.30 370.00 BIG CREEK 2A 2 Dec, 28 100.00 55.00 49.20 BIG CREEK 3 1 Oct, 23 100.00 25.00 34.50 BIG CREEK 3 2 Sep, 23 100.00 25.DO 34.50 850.00 BIG CREEK 3 3 Oct, 23 100.00 25.00 34.30 BIG CREEK 3 4 Apr, 48 100.00 36.00 40.50 BIG CREEK 3 5 Feb, 80 MOO 36.45 38.10 BIG CREEK 4 1 Jun, 51 100.00 50.00 50.10 465.00 BIG CREEK 4 2 Jul, 51 100.00 42.00 50.10 BIG'CREEK 8 1 Aug, 21 100.00 27.00 25.30 350.00 SIG CREEK 8 2 Jun, 29 100.00 31.50 38.70 BISHOP CREEK 2 1 Nov, 08 MOO 2.50 2.50 BISHOP CREEK 2 2 Nov, 08 MOD 2.50 2.50 40.00 BISHOP CREEK 2 3 Juan, 11 100.00 2.32 2.50 BISHOP CREEK 3 1 Jury 13 100.00 2.75 2.60 BISHOP CREEK 3 2 Jun, 13 100.00 2.20 2.60 40.00 BISHOP CREEK 3 3 Jun, 13 100.00 2.20 2.70 BISHOP CREEK 4 1 Sep, 05 100.00 1.00 1.00 BISHOP CREEK 4 2 Sep, 05 MOO 1.00 1.00 51.00 BISHOP CREEK 4 3 Jun, 06 100.00 1.75 2.00 BISHOP CREEK 4 4 Oct, 07 _100.00 1.75 2.00 BISHOP CREEK 4 5 Jun, 09 100.00 - 1.75 2.00 Form R-38 p. 1 of 2 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 Location Air Water County Basin Region 10 10 10 10 10 10 .10 10 10 10 tit 111 111 111 11t itt 111 10 10 14 14 14 14 14 14 14 14 14 14 14 SJV Si SJV SJ SJV SJ SJV sJ SJV sJ siv Si SJV Si SJV SJ SJV SJ SJV SJ SJV Si SJV SJ SJV Si SJV Si SJV Si SJV Si SJV Si V A Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder Phone: (818) 302-9514 EXISTING AND PLANNED UTILITY OWNED HYDRO RESOURCES Date Percent Plant Name and Unit Number Install/Modified Ownership -------------------------- BISHOP CREEK 5 1 ---------------- May, 43 --------- 100.00 BISHOP CREEK 5 2 Jun, 19 100.00 BISHOP CREEK 6 1 Mar, 13 100.00 SOREL 1 Dee, 04 100.00 SOREL 2 Dec, 04 100.00 SOREL 3 Jan, 32 100.00 FONTANA 1 Dee, 17 100.00 FONTANA 2 Dec, 17 100.00 KAWEAH 1 1 May, 29 100.00 KAWEAH 2 2 Sep, 29 100.00 KAWEAH 3 1 May, 13 100.00 KAWEAH 3 2 May, 13 100.00 KERN RIVER 1 1 May, 07 100.00 KERN RIVER 1 2 Jun, 07 100.00 KERN RIVER 1 3 Jul, 07 100.00 KERN RIVER 1 4 Jun, 07 100.00 KERN RIVER 3 1 May, 21 100.00 KERN RIVER 3 2 Mar, 21 1DO.00 LUNDY 1 Dec, 11 100.00 LUNDY 2 Feb, 12 100.00 LYTLE CREEK 1 Oct, 04 100.00 LYTLE CREEK 2 Sep, 04 100.00 MAMMOTH POOL 1 Mar, 60 100.00 MAMMOTH POOL 2 Mar, 60 100.00 MILL CREEK 1 1 Sep, 93 100.00 MILL CREEK 2 1 Aug, 04 100.00 MILL CREEK 3 3 Mar, 03 100.00 MILL CREEK 3 4 Jan, 04 100.00 MILL CREEK 3 5 Mar, 04 100.00 ONTARIO 1 1 Dec, 02 100.00 1 '. Installed Capacity (MW) 2.00 1.50 1.60 3.00 3.00 6.00 1.47 1.47 2.25 1.80 1.40 1.40 6.20 6.20 6.20 6.20 16.00 16.00 1.50 1.50 .20 .25 84.28 64.68 .80 .25 1.00 1.00 1.00 .20 Form R-38 p. 1 of 2 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 Dependable Average Net Location Capacity Annual Energy Air Water (MW) (GWH) County Basin Region .......... 2.00 ---- -------- 23.00 ...................... 14 1.80 14 2.00 11.00 14 2.10 15 2.50 65.00 15 6.40 15 .90 8.00 36 .98 36 2.25 13.00 54 TB 2.05 13.00 54 2.40 25.00 54 2.10 54 6.20 15 6.20 180.00 15 6.20 15 6.20 15 18.40 180.00 15 18.40 15 1.50 9.00 26 SC 1.50 26 Sc .34 4.00 36 SC SC .34 36 SC SC 93.50 610.00 20 93.50 20 .94 5.00 36 .32 36 .89 16.00 36 .89 36 .89 36 .30 19 h Utility Service Area: Southern California Edison Date Filed: September, 1967 Utility Contact: Ron Schroeder Phone: (818) 302-9514 EXISTING AND PLANNED UTILITY WILED HYDRO RESOURCES Fora R-39 p. 1 of 2 CEC Contact: Pat McAuliffe Phone: (916) 324.3602 Installed Dependable Average Net Location Date Percent Capacity Capacity Annual Energy Air Pater Plant Name and Unit Number -'------------------------ Install/Modified ................ Ownership ......... (MN) iMH) (GMI) County Basin Region 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 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 GORGONIO 1 1 Dec, 23 100.00 1.50 1.50 3.00 33 SAN GORGONIO 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.0O .40 .70 5.00 36 SANTA AMA 2 2 Nay, 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 TITLE 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 TR TOTAL 827.28 943.24 4,576.00 x Y Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact:Ron Schroeder Phone: (818) 302-9514 EXISTING AND PLANNED UTILITY OWNED HYDRO RESOURCES 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 form R-30 p. 2 of 2 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 h I Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact -Ron Schroeder EXISTING AND PLANNED UTILITY OWNED WORD RESOURCES Phone: (815) 302-9514 Fixed Variable Instant OR.N Costa OB.N Costs Capital Costs Expenditures Plant Nave and Unit Number -------------------------- (19865/)NNh) (19US/Mh) (1985S) As of 12/31/85 Status BISHOP CREEK 5 1 ----------- 15100.00 ----------- .00 ------------- -------------- ------ BISHOP CREEK 5 2 15100.00 .00 BISHOP CREEK 6 1 15100.00 .00 BOREL 1 15100.00 .00 SOREL 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 KAWEAH 2 2 15100.00 .00 XANEAN 3 1 15100.00 .00 KAYEAN 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 MAMMOTH POOL 1 15100.00 .00 NAWWN POOL 2 151OO.OD .00 HILL CREEK 1 1 .00 HILL CREEK 2 1 15700.00 .00 HILL CREEK 3 3 15100.00 .00 HILL CREEK 3 4 15100.00 .00 HILL CREEK 3 5 15100.00 .00 ONTARIO 1 1 15106.00 .00 =-- Fond R-31 p. 2 of 2 CEC Contact: Pat McAutiffe Phone: (916) 324-3602 c Utility Service Area: Southern California Edison Date Filed: Septedmr, 1987 Utility Contact:Ron Schroeder Phone: (818) 302-9514 ONTARIO 1 2 ONTARIO 1 3 ONTARIO 2 1 POOLE 1 PORTAL 1 RUSH CREEK 1 RUSH CREEK 2 SAN GORGONIO 1 1 SAN GORGONIO 2 1 SANTA ANA 1 1 SANTA ANA 1 2 SANTA ANA 1 3 SANTA ANA 1 4 SANTA ANA 2 1 SANTA ANA 2 2 SANTA ANA 3 1 SHAVER MICRO 1 SIERRA 1 SIERRA 2 TULE RIVER 1 TULE RIVER 2 EXISTING AND PLANNED UTILITY OWNED HYDRO RESOURCES Form R-38 p. 2 of 2 CEC Contact: Pat McAuliffe Phone: (916) 324-3602 Uewy Service Area: Sculhern CaMomia Edson Dale Fled: Sep-87 Utility Contact RonSchioeder Month January February Mach April May June July Annual Tod 1977 . Dry Year MONTHLY AND ANWAL HYDRO VARIATION Big Creels System Average Year' Tsai cry (MW)' Energy R - of - R Maximum (GWh) 53 44 22 18 28 209 228 197 87 44 51 121 1072 1980 - Wet Year Capacity (MW) R - of- R Maximum Taal Energy (GWh) Capacity (MW) R - of - R Maximum Total Energy (GWh) 111 976 230 480 699 403 99 978 208 460 657 426 291 980 349 620 732 495 300 989 366 625 663 464 466 1003 483 626 730 486 460 1009 480 680 734 617 382 1009 463 690 736 538 249 1006 397 620 734 486 217 994 374 400 732 353 84 978 246 250 713 259 112 973 195 210 610 231 107 974 214 too 686 212 Although hisbrkW Words are not available fa dslen irre the R - of - R and Pardape Capacityy, it is ressonabM to assume that 9n R - of - R capacity was isigrWard "Assumes ftiaMood Powerhare (BYsom Meadow) aims. Bawd an 6year aF I iraIort nnodeL Also assumes addliond upgrades and improverranls since 1930. 4005 4870 Form R-30 CEC cadact Pat MwAuWle Phone: (916) 324-3602 r 'Utility Service Area: Southern California Edison Date Flied: Sep-87 Utility Contact: Ron Schroeder MONTHLY AND ANNUAL HYDRO VARIATION Big Creek System Average Year' Total Total Capadty (MIN) Energy Capacity (MW) Energy Month 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 Capacity (MW) R - of - R Maximum Assumes Eastwood Powerhouse (Balsam Meadow) and Big Creek Expansion Project online. Based on 6 year optimization model. Total Energy (GWh) Form R-3D CEC contact: Pat MaeAuliffe Phone: (916) 324-3602 Ud ft Service Area: Southern CaUornia Efton Dab Find: Sap•67 U" Contact: Ron Schroeder MOKMLY AND ANiOAL HYDRO VARIATION Southern Hydro Bishop tiydro 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 'Alt energy is R - of - R. Form R•3D CEC contact Pat MeekMft Plwne: (916) 324.3502 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 (MM 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 01and 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 Wily Serves At": Sodlrsrn Cablornim Edison Date Food: Shp-87 Umy Conta[t: RanSdaasdn GOrWa8on (GWh) Nuclear Coal - Convendonel - Advanood 08ardGMSOM Combustion Tud*w Contbeied Cycle Rydro so" SW(ap p nwadSbraw MIAL 1964 1965 lose Actual Actual Actual` EXISTNW AND PLAWIED UTILITY OWNED RESOURCES Foie R-3E p. 2 of 2 CECconlatPat WAUI e Phone: (916) 324.3602 1987 too$ 1959 logo 1991 1992 1993 1994 1995 1096 1997 1998 toss 7239 8421 11939 12556 14071 15487 14937 14136 14310 14271 14270 14272 14315 14265 14272 14276 9642 5909 10057 10201 9995 9325 92tS 9719 9533 9540 gels 9613 959a 9443 9669' 9604 $98 662 501 570 503 564 541 $64 503 563 20945 27t88 17423 24980 16317 9921 8542 7887 9220 11181 12460 14269 14901 17299 15865 17483 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 2.3 945 1667 1119 1121 994 475 482 352 502 320 956 532 822 204 843 076 5459 4417 5784 3418 4520 4874 4874 4974 4874 4874 4874 4874 4915 4997 5007 8007 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 -1.6 -1.6 -1.4 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 44454 47642 46372 52306 45428 39052 38545 37538 38938 40755 42680 44123 45091 46771 47181 47790 • 19114 - 19M Oda from ADS7 Report •1967 and toss Daft from Fuel 1 Purrhaud Power 8tdpet Repot 0 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 UONY Contact Ran Sdsoeder QUALWYNG FACUMES AND PRNATE SUPPLY Pfrom: (916) 324-3602 Qualifying 1984 toss 1986 1987 lose 1989 1990 1991 1292 1993 1994 4995 1996 1A97 1998, 1999 Facilises (GWfn) Acbai Adual Ac FoulCogumatlorn 593 1857 3278 3508 8032 11280 11868 12479 12642 12607 12607 12807 12642 12607 t2607 12607 mmic ai caysn Blarms as 146 229 S99 1037 1186 1599 t789 1804 1826 1845 1345 1849 1845 1545 1845 Geosrmal 44 1,48 548 toss 1672 2456 3370 3433 3442 3492 3566 3701 3782 3774 3774 3774 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 28 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 Dale Filed: Sap-87 Udity Contact: Pon Schroeder INTERUTILITY EXPORT Form R-SA p. 1 at 3 CEC oartact At Alwaado Phone: (016) 324-3152 t984 1985 toss 1987 1988 1989 1990 1091 1992 1993 1994 1995 1096 1997 1998 1990 Actual Actual Actual Firm Exports A. Capacity (MW) Northwst - 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 otter - 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 8. Energy (GWh) Northwest-1 25 885 955 803 74 73 132 198 231 229 229 229 3E4 538 662 719 Soutrwest 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 Otxtr-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 Nortwreat - 1 0 0 0 0 O a 0 0 0 0 0 0 0 0 0 0 Southold 0 0 a 0 0 0 0 0 0 0 0 0 0 0 0 a Catbnia - 2 0 0 0 O O 0 0 0 0 0 0 0 0 0 0 0 Otte-3 23283 - 50820 - 22206 - 31530 - 59t86 65529 71057 76748 84459 89757 99188 106667 116253 125366 136586 147606 Told Co6t$0DD 23283 50820 22206 31530 - 59186 - 6SS29 - 71057 - 76748 -- 84459 - 89757 - 99188 - 106667 - 115253 - 125366 - 136586 - 147806 I- NW Contact Return O6llpatom a Capadty for Energy Edrargec 2 - CDWR a MIND 3 - miscefformous Interchange i Sales to Otters 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 0 i UWMy SerAce Area: Southern CaMmin EdamOf Dab Fied: Sep-87 Form R3A p. 3 A 24- 3 CEO contact At ha Uft Contact Ron Schroeder DITERUTILITY EXP0RT TRANSACTS Phone: (916) 3 ION2 1984 1985 1986 1247 1983 1969 1990 1991 1992 1993 1994 1995 1996 1997 1995 1999 Actual Actual Aeaul Firm Exports A. Capadty (MM Northwest - 1 0 0 0 O 0 0 0 0 0 0 0 O 0 0 0 0 SouBnrast 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CaMomia - 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Omar - 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. Energy (GWh) Nord~ -1 25 885 955 803 74 73 t32 t96 231 229 229 229 354 53S 662 719 Soutiweat 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 Camornia-2 4139 4075 5016 4758 St89 4552 4455 4455 4455 4882 4870 4546 4573 4216 4216 4222 01br-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 6786 6909 6972 Non6rm Exports A. Energy (GWh) NrBwat 0 0 0 0 0 0 Scut~ 0 0 0 0 0 0 CaWgnia O 0 0 0 0 O Tod Her " Export 0 0 0 0 0 0 1- NW Conked Maim O69pa8rr 8 Capacly for Energy Exhanges 2-CDWR& MWD 3. MkcaNarrane ItMrtharrpe i Sorbs b OBrrs 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ARIZONA PUBLIC SERVICE COMPANY (APS) - EDISON CHOLLA NO 4 LAYOFF AGREEMENT 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. RRS:smc 2153/AES:2 09/08/87 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. RRS:smc 2153/AES:3 09/08/87 • ; • .� • MR HIMV�. 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. n RRS:smc 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 Hoover Power Purchase Agreement DATE EFFECTIVE: January 1, 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. -2- RESERVE SUPPORT: Reserves are provided by Edison. RRS:smc 2153/AES:5 09/08/87 DISTRICT - EDISON 1987 SERVICE AND INTERCHANGE AGREEMENT 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 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 MM 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 2153/AES:6 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. TRANSMISSION BETWEEN PP&L AND EDISON SYSTEMS: RESERVE SUPPORT RRS:smc 2153/AES:7 09/08/87 -2- 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. Reserves are provided by the utility (PP&L or Edison) making capacity available. PACIFIC-PORTLAND SALES AND EXC&BGS AGREEMENT 4r : r : r ' r • Jv�' v�' REFERENCE: Portland General Electric (PGE) 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 PGE 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 PGE. 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. TRANSMISSION BETWEEN PGE AND EDISON SYSTEMS: RESERVE SUPPORT: RRS:smc 2153/AES:8 09/08/87 -2- Provided by Edison's and PGE's firm entitlements in and ownership of the Pacific Intertie. Reserves are provided by PGE. 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 CAPACITY EXCHANGE AGREEMENT BETWEEN SOUTHERN CALIFORNIA EDISON COMPANY AND STATE OF CALIFORNIA DEPARTMENT OF WATER RESOURCES (CDWR) 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: RESERVE SUPPORT: RRS:smc 2153/AES:10 09/08/87 _2_ 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, Reserves for the purchases by Edison of electrical output from CDWR's resources are provided by Edison. 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 TRANSMISSION FROM CDWR TO EDISON SYSTEM: RESERVE SUPPORT: RRS:smc 2153/AES:11 09/08/87 -2- 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. Reserves for the purchases by Edison of electrical output from CDWR's resources are provided by Edison. Utility Service Area: Southern California Edison Date Fled: Sep-87 Utility Contact: Ron Schroeder INTERUTILITY IMPORT TRANSACTIONS Form R-56 p. 3 Of 3 CEC contact: At Alvarado 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 (NM) ' 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 - 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 Non6rm Import 20636 16194 12640 12547 14051 14523 16245 17920 18005 17024 16759 13911 14287 13943 14782 14240 1 - Includes SCE Hower and Mexico GeoBtermal Udit service Am& SmOvern CaNlornfs Edson Daft Filad: -07 Farm R•5B µ z d a U y Contact on Sd Ron aoedsr RlTERUTIUTT WORT TRANSACTIONS CECosr - - Ai Ahmvm& Phone: (016) 324.3152 1984 t985 1985 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 AtWal AcKW Acwg Nonkm I nporta A. Enaryy (GWh) NorYmest t1031 10053 7t39 8321 4979 6296 6187 6962 6549 6033 5059 4007 3464 3438 3461 3412 Soutwest 6169 5489 2928 3489 7286 8200 9040 9979 10419 9873 9488 8671 9576 9217 9969 9522 CaMbmia 3435 652 257S 737 1787 1027 1010 979 1037 Ills 1212 1233 1247 1288 1312 1306 Taal Nmwm Nnpart 20635 16194 12640 12547 140SI 14523 16245 17920 t8005 17024 15 559 13911 14287 13 443 1,4782 14240 Casts (A) In SIMft Nod wrast 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 So98wsat 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 Caifannls 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 Tool Cast$000 4SO216 405607 212123 212690 28t252 320212 397276 469071 518371 52050E 530330 SO4291 564791 594210 68629S 714116 Utility Service Area: Southern California Edison Date Fled: Sep-87 Utility Contact: Ron Schroeder Firm Imports A. Capacity (MM Northwest Southwest California Other - 1 Total Firm Import B. Energy (GWh) Northwest Southwest California Other - 1 Total Firm Import C. Total Cost in $000 Northwest Southwest California Other Total Cost $000 INTERUTILITY IMPORT TRANSACTIONS Form R-5B p. 1 Of 3 CEC contact: At Alvarado Phone: (916) 324-3152 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 Actual Actual Actual 667 667 667 221 736 736 588 773 773 773 961 1055 1313 1456 1456 1456 622 622 339 339 190 0 0 0 0 0 0 0 0 0 0 0 456 456 601 538 538 538 538 538 538 538 538 538 538 538 538 671 377 431 347 347 347 347 347 347 347 347 347 347 277 277 277 277 - - - - - - - - - - - - - - - - 2122 2176 1954 1445 1811 1621 1473 1658 1658 1658 1846 1940 2128 2271 2271 2404 0 0 1213 1821 2580 3100 2577 2549 2555 2549 3043 3686 4120 4234 4342 4342 2778 4058 4193 2010 2008 1483 414 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2697 1802 1838 1365 882 767 796 813 775 776 781 781 685 251 251 254 - - - - - - - - - - - - - - - - 5475 5860 7244 5196 5470 5350 3787 3362 3330 3325 3824 4467 4605 4485 4593 4596 0 0 27879 62656 118153 128826 121674 119742 132369 138341 180504 230685 261509 280176 300624 322139 63374 132197 158247 109231 98381 55640 22223 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8241 3956 4741 28830 34006 34012 35549 36724 36681 37171 38382 36955 28426 4295 4424 4607 - - - - - - - - - - - - - - - - 71615 136153 190867 200717 250540 218478 179446 156466 169050 175512 218886 267640 289934 284471 305048 326746 1 - Includes SCE Hoover and Mexico Geofhennal EXISTING AND PROPOSED BULK TRANSMISSION FACILITIES utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder Phone: (818) 302-9514 Page 2 Fore R-6A CEC Contact: Al Alvarado Phone: (9I6) 324-3152 Location From: To: Operating) tine Hating Length Ent. $ of Land (1) Assoc. w/Project Est. Construction (1) California $ of Project Voltage kV Mod. Date More. 4 Fmerg. (Miles) (Book Cost) (Book Cost) Counties Involved 220 kV Lines (Continued) Amperes on Line on Another 4109 Chino-Yaricus 220 2320-3070/ 88.54 86.74 8,068,067 35,067,437 San Bernardino- 4111 Big Creek 13-Big 220 2540-3386 820/900 5.79 1,944 318,872 Riverside -Orange Creek 14 Fresno 4113 Dig Creek 13-Springville 220 1160/L270 128.32 516.651 2,995,409, Fresno-Tulsre-Kern- 4114 4115 Laguna Bell -Various Hinson -Various 220 220 2320/2540 I106-3070/ 80.83 15.73 44.18 13.31 3,234,285 1,655,287 11.358,653 5,119.334 L.A. Los Angeles 1215-3380 Los Angeles 4116 EI Nido-Various 220 2240-2320/ 57.34 34.02 3,020,030 14.337.584 Los Angeles 41I7 4118 Pispah 01-2-Lugo Mira Loma -Various 220 220 2460-2540 820/900 820-2320/ 303.00 9I.61 59.75 769,311 5,718,274 4,642,388 13,404,094 San Bernardino 900-2540 San Bernardino- 4119 Center-Varioua 220 2320/2540 92.93 54.72 2,OOL,319 14,627,956 Orange Los Angeles 4120 Alamitos -Various 220 2320-3070/ 84.66 40.05 4,269,503 11,643,205 Los Angeles- 4121 Big Creed 14- Springville 220 2540-3386 820/900 132.74 196,637 3,876,873 Orange Fresno -Tulare -Kern 4125 Moorpark -Various 220 1160-3070/ 221.69 194.29 10,973,961 42,489,558 Los Angeles 4127 4133 Circa -Pisgah (MV) Kramer -Various 220 115/220 (2) 1270-3380 820/900 Various 84.46 103.93 0.63 102.24 19,842 1,250,420 1,015,629 17.807.145 San Bernardino 4144 Eldorado -Meade (NV) 220 2320/2540 30.64 9,993 903.913 San Bernardino -Kern Waved* 4153- 4156 PearbIossom-Vincent E131a-Santiago 11-2 220 220 820/900 3070/3380 13.14 14.83 14.67 310,659 6,599966 890,388 Los Angeles 4157 Rio Hondo -Vincent 12 220 2320-3600/ 22.41 106:504 7,366,672 6.135,204 Orange Los Angeles 2540-3%0 4166 Big Creek 12-3- 220 Various 902 9,034 300.481 Fresno Big Creek 18 4168 Rig Creek /3- 220 820/900 6.50 4,33I 472,834 Fresno Mammoth Pool 4169 Dig Creek - Various 220 Various 290.35 7.27 213,456 7.981,176 Madera-Freano-Twlare- 4756 Devers-Various 220 800-1 80.56 39.7 -1 1,086,115 12,982.737 Kern Riverside -San Bernardino 900-1270 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. lines are not extant. (2) Operating Voltage/Design Voltage PFM:ssc 2068 1985 dollars costa for the large majority of these ' Utility Service Area: Southern California pate Filed: September, 1987 Utility Contact: Ron Schroeder Phone: (818) 302-9514 Location From: To: Voltage kV EXISTING AND PROPOSED Edison Operating/ Line Rating Mod. Date Norm. 6 Emerg. BULK TRANSMISSION Length (Miles) FACILITIES Est. $ of Land (1) Assoc. w/Pro act (Book Cost) Form R-6A CEC Contact: Al Alvarado Phone: (916) 324-3152 Est. Construction (1) California $ of Project Counties (Book Coat) Involved On n 800 kV Lines (DC) Amperes Line Another 4031 Sylmar - Celflo (CA) 800 3100 336.17 $0 $16955368 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 556959 Los Angeles , 4147 2540-3960 27.48 3915235 6154:626 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 1917 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 276517 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 28423788 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 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. >� ,^5�.... 1_Ilc _--ww 4W 111 IW W Ma 10 I. CNN. CMI 1. MW SW 1e CYN CMI WSW 41" 17.31 391e PA 43w I2.3.4) law (2) Etc xsw (11 Ma 111 Nw 121 "is (0) a]a 12.41 lose la) alas tic not, 11) not, Iq 47w (7A) 391E 13,91 am P.3.41 last 131 ETC 3Sw 111 ]ast Ill Oa (a) "is 10) na (7,4) lose P) 3105 tic Sew 11) MM (1) 47w 12,31 3910 /3.01 awa 42,3,41 lose PI ETC 3300 (1) not, 11) 47a lal nit (e) nst I2.41 law P) ales tic Ma It) Ma 11) 47w Ia,w) Mts 113.9) saw Il,a.q Saw (a) ETC Two P) awe IU Aa 433 MP (a) calla 42.4) am PI ales IIC Mae Ill Mst (11 Ow (7.3) 391e (2A) am PAN) lass 13) ETC 25" (1) Mw (1) 47a PI Mu (e) 41a IaA) lose (Iq Ens tic not P) aaw 11) ow IAa) 3e1e 13,1) am 12.3,4) law PI ETC 15M III Ma Ill 47w (a) "to P) qst 17./) law (e) 71N5 Ile Mae Ill Mw (1) 47a 42.3) 3916 PA) am (aA.a) lass" (3) Etc 2500 11) Min (it 47w PI nit 15) uw Iaa) law PI else IIC Ma (1) net (1) a/a (2.3) 1e1e P,$) 4M 42.3.4) law (2) ETC 23a 11) not, (1) 47w (2) "to Iq aaa PA law le) else tic Sew TO Mw Ill 47a I2,3) Sale (31e) am 12,3,4) lass P) ETC 13a 11) ww 11) a" 1231 n11 P) as P.V law 491 tote$ sic Sew (1) not, (1) ow 12.3) 301e 13.9) am 12,3,4) law is) tic 25" (1) Lw 11) 47w 131 Nis let pw P.O last PI Iles IIC MM (1) Saw (1) nw PA) ML 43.0) am 42.3.4) loss, ' If) ETC 25w (1) Lee 411 atst 131 MU (a) am (2.41 last (e) Isle$ IIC Mst It) Mw 11) a" 13.31 isle Me) am PA,41 taw la) ETC Sale (1) Sew 41) aw PI "is PI nee (M) less PI /nl lie Ma IT.$) Sew 11.5) 7ew (ap.$) $Me (3.e) low I2A.4,11 Mw (37.9) ETC Ma IM) Sew (I.$) 7aa Ise) am (a) sees 13.4.11 Saw 17,$) 1193 tic Sew IT'S) 3eN PA) few (aA,q am 42.4) ww 41.3.4.71 Mae to.?M ETC MIS IT,q not (IM Two (2.$) all (6) sees PAT) wee P.N clef tic Sew 11.51 Sew 11.51 7m 10.3.e1 am (3,a) sees 42.3A,71 aeee (2,7.e1 ETC Mst IT'S) Mae P.S) law 12.9) taw is) sees (SAM ewe P.M slew tic Ma (Isl Ma 11,$) Taw 1=A,e) am PA sew 42,2.4,71 awe 13.7./0 Etc Sew (S.$) Sew IT'S) Mw (as) sxee la) sew IZATI aeee 0.E1 snt tic Saw (IA Sew 41.0 Test 1=A,e) na PA sew 12.3.,4,7) Sew 13,7,0) ETC Sea 41.6) Mw It,q 7e411 (w.q SM (a) ar (tATI ww (7.1a enw Ile Ma 11.4/ 3ws 11.5) 1ew P.3.Q 53" PA) sew (3.3.4.71 wee P.7.N ETC Lee to.$) lase IT.$) 7ew (aA) am IS) sees MIA last IT." 711C 11C Sow ISM aeea U,el few (lA,q am P,a) saw 13,3.4.71 wall p,7.q ETC Lst (I.$) ewe (1.5) 7ea PA) awn IS) sass (2,4,7) Ma IT." e ISS tic 30a P./) not 11.5) 70" (a.a.N am P.01 Ease (2.3.4.71 wee I3.LE) ETC aoes (t.l) ]Sae it.%) iew PA) fwa to) lest I2.4.7) west 17.51 enl tic loss 11.5) Lee (1.$) 70w P.a.q am PA ewe IiA.a,7) awe IS.1,A) ETC low /I,SI Lw I1.51 iaw 12.0) Sm is) aaa (7.4.1) aoae 17.y rani Ilc last Its) awe IT.$) 74w P,a.4) fLa P,q ewe I2.2.4.71 aaae /a.7.q ETC Swa (1,51 awe P,5) law (l,a) Stea lfl saw 12.4.1) awe 17.e1 nn: IIC Lw IL9 law (1,5) 79" (lA.4) iMe /a,q ewe 12,3.4d) Sow P,7A) Ell La 11,51 3000 11,5) law (x,q Sloe (f) SOM I3.a.$) Los P.a) 1L s a IIc aoa 11.51 awe 11,si 74" (2,3,6) SLS (a,al ewe IaA.4.71 seas P.T.S) ElC ]110a I S ]ea I S 7Ma 12.61 allle a sea l a> not i s I11LIti AP111 AM: AMtum cotini01A MISM DATA Ilnl: S&TOn IM7 MRITI CwActe SO SC110Mn PM.. O11-112-9514 KW Ott 1111, MIT 1 UHL) OAK M. TYPE CAI 1 1/mm L1111. 2 timm M01M MAL MIUIMIS, MR SMW, LAW AIOI MTR ISt t11113 L2111.4 E1011.5 i VOL WnTI COOL VA M OAl2M 0771 m aimm 1 sm. (N Am) TTR 7m MI Utm IOL. CO. um "W 1-1 INC CNTMTI CM.ON VIM MM. J9IO 324-310 /KS. INC. IK, a. COOING OIK. - -- MM1 m I GAS 1 113 1 0.322 O.2S0 0,220 0.222 - 0.229 { 00m 3 MT1 3 OI OC MOI 1IA,SOC 1.1M M 4- 1.440 MAIMS I OIL PS 1 6.20 0.191 SAM 8.186 0.2S9 1 LIQOIO 3.1"IIO'6 Of OC MK ta.25t,W.STC 0.M] 0.20 MMITM 2 U6 IA t 1.m 0.205 0.111 0.2t2 4.M- [ nu 0t K OOON LSA,SK 1.M5 0.40 ALWA M 2 OIL 175 1 0.077 0.17S 0.220 0.234 0.73A I M K IONI t5[.23ZjK%5TC $.On cm ALAMM 3 AAS 320 I 0.0U 0.4% 0.011 0AN 1.07Z [ at K IIOO tM,Mt 1.010, 0.731 AGII m 3 OIL 320 l 0.315 0.241 0.202 0.230 4.361 ( Or K )OK LSI.232,IL1,21C 0.0% UVA AMISS 4 OAS 320 1 0.022 0.OA5 O.OM 0.a10 0.129 J at K OOK (IA,tiC 1.Nt 0.750 MMtlTM 4 OIL 328 1 0.314 9.228 0.170 0.10 1.210 1 M K MK LA.231,W,KC 1.0/4 4.3M MANTM S OAS 40 i 0.007 0.121 0.0V 0.0% 0.i14 1 0t K MOl I)A,stC,IK O.MA 0.7.M MMIpM 3 OIL 40 1 0.2" 9.20 0.201 0.227 6.217 I Or K MK La.=,LU SIC,IK 0.111 1.5M MMOtOS A SAS No t 0.02 OA43 1.01E 0.116 0.156 1 M K IOOO I)A,SK,0K 0.M5 ►.)30 M1MNs A OIL 480 t 0.264 O-W 0.207 1.196 4.232 I 0T K MK La.23Z.tU STC,MC SAO SAW ALWISS 7 US Ilk i Mm I am I Im t Mu I 11m 1 ( K K MK No owl MR 3 omm 7 11ST 126 J Om i MCI wit 1 00R I Mm I I K K MK UK on 1 Mm % OK stal I sm AS 1 0.I04 0.140 1.005 0.0M 1.101 1 UPI► 1.237110'A K a ASK W.sK 0.MI S.730 COL M1M 2 OIL 63 J OR 2 MM I iR 1 WM t MK 1 1 01LS K a NK LSFJSL,tM,SIC NMI 6.3% OK am 2 0RS M I O.IU 0.10 1.N5 0.9% 0.11% 1 K GI MK im sic CON, 0.751 OK I01K 2 OIL U I am I MK I MIN I MIN I UM I( K a m 159 m,In4,sK on I 1.311 OIL 100M 3 US 256 1 I0m I Mm I SOM I MR 1 MR I 1 K OF wit 51l I1m I C735 OIL NIM 3 OIL 236 1 NO I I1m 1 Mt t MR 1 111g L F K or INN La.052,1011 101m 1 4.371 OIL MIN 4 iA5 25A I MIL I MR 1 1MI l Mm I not 11 K OF MIN 911 m I 0.730 aK ma 4 ML 23A I Mm I MK 1 mat na I NM I I K a Mom L4.15xlm WWI 0.3010 •I.MM I sK 32 1 NO I MR I owl Owl Mm I J L1pM 1MW3 K K MMI 1M MM 1 0.731 OLMM I OIL 33 [ MM 1 WM I MM 2 MR I OM0 I I MIN; K K om tM.05I,MN 1M11 C210 K M 1 94 115 ( 0.IA3 4.146 0.135 0.105 4.243 1 LR M AtlIW3 M st MK 1III,11C 1.0M 6.1141 BL o t OIL 175 t 0.147 0.139 0.2" 1.211 0.311 t "Is K K OK 15T.=,[L.SK Cm 0.24111 K! I iK OS 1 1.731 O./M 6130 O.IM 1.10 1 or K NK tM.MC SAN 0.441 NLM 2 ML 03 1 1.M0 0.311 1.299 "1 1.322 I M Sc MN L? 24,tM,11C 0An 4.30 K» 3 0/6 335 I 0.144 0.073 0.175 RNA 4.091 1 of Sc >eR LM,R 1.07 0.731 a sm 2 ME. 335 1 1.104 0.111 0.296 0.229 0.2A I K K UK LWAS1 IO,fC 1.0►1 0.370 M. M 4 GAO 31a 1 O.Nt 0.062 1.a1 0.07 4.125 1 M K ME [)A,MC Rin Lm I<5001M1 4 OIL 321 1 0.211 1.2TA 0.2" 4.25A 4.239 i of K MK L4.232,tM4MC 41.141 0.531 umm I Us 132 t 0.276 cul 0.142 SAM 0.114 1 Lwm 1.16mrA K R NK 2M.sK Lou 0.4411 2 mia 1 OIL 132 ( 4.4" 0.354 CM 1.1M 9.163 1 ONES K is MK LY.25t,tMySm 0.00 1.310 Qtwm 2 G9 in I 0.120 O.m *.sm 0.017 1.109 i K is 00m ta.sK 1.444 SAN viI 2 OIL IV 1 0.230 0.75I 0.262 0.23A 1.2N 1 K IS MK IA.23I.tM UC 4.00 R2M UMAMt 3 04 320 { 9.94A SAO 0.056 41,091 0.129 1 K K NM Lp,StC.1C 0.M2 0.730 InO 3 OIL 319 I 0.1M 0.1% SAM 0.231 0.240 ( K Is MK La.231,tm wc.l6 NAP" Lm n11IM0 4 US 334 1 O.N2 OAU 0.076 1.W 1.131 1 >K Is MK W,11C.NC 1.M1 L731 2TIMOM 4 OR 330 I 0.271 0.272 0.237 0.232 1.248 { K 6 NK 13.231.RA,SK,MC 0.003 0.351 allom 5 UO 126 I MIN I Mm I Mm i Mm I MK 1 1 K K MK MM owl m 3 Mt01M4 3 17ST ix 1 A1m I IMl I MK 1 Mm I NM I 1 K K MK MM MM ► MMi MM L�4 4 INK 3N 1 On I MIN I Mm I MR I MM I I MLA 4mW3 CI IS NO INS.NO 20K t MISS m CARS• 5 Clog; 3% I MR i mNK 1 MR I MR 1 NO 1 1 Mal TONS It IS IOK us'la IIm 1 Mm 3 MIMMm I OAS 33 I 6.0N O.NI 0.211 CNO 41.116 1 L7/0M HM10'3 K OF INN SK O.OM MM 3 W410M 1 ML 33 1 0.173 0.1M 0.317 0.317 SAM { ms x IF MK La.25L,STC 4.011 MM3 M00M011 2 US 31 1 O.OR 0.142 0.2N 0.322 O.N3 1 K IN MK SIC 0.0411 "as IIMNIR I OIL 13 1 0.0911 1.123 1.319 0.414 0.462 1 K a M11 L4.2U SIC 1.M2 was MOIt1IK 3 ON 44 I sm 2 0.071 0.I56 1.m cm t K If MK STC 0.01 MM s MMMIII 3 O1l 44 1 0.179 0.2N 1.224 O.2M 0.332 ! K Or NK 13O.25XSTC SAM was wilum 4 as 44 1 0.213 0.147 0.20A 0.3" 0.413 1 K IF OOK sit 0.0N ma IIANMm 4 OIL 44 1 1.295 O.LS 0.241 0.333 0.219 I K or MK L97.m.sel 0.I93 owl UTILITY SEATKE NEA: SORM CALIFORNIA EDISON FORK 8-7 DATA FILLO: SEPTEMMN IV61 CIC CONTACT: CALVU 1111 UTILITY CONTACT: NO SCROINR INTIDDIR MAL POLLUTANTS. FUEL STOIAFE, LAND AND OATU USE 1NON1: 1916) 324-3143 PIER: 110-302-9SI4 PINT NIT FUEL OMIT I LIM I LEVEL 2 LEVEL 3 LIM A LIVEL,l I TOM QUANTITY CODL OATU Not POE. CON. N115, FAC. M. CN. WE N. 7111 CAP I WINES U/M29TI #0125111 I/M2BT1 A/M2IEI I STOR. (AS NO RD) WE ]III OARI ItCO 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 tM1M6tN I OIL 215 1 0.325 0.735 0.192 0.246 0.323 I OILS OF OC NONE LSF.252.UA,STC 0.091 0.350 NKT106TON 2 GAS 215 1 0.203 0.162 0.143 0.133 0.129 I 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 IRA ISF.2SI,LU.STC 0.093 0.350 IE1T11MTN 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 E 0.227 0.271 0.222 0.744 0.284 1 OT OC NNE LSF.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 1B1T1NSiN 4 OIL 225 1 0.29I 0.37E 0.260 0.291 0.327 1 0T OC NOR[ LSF.251,LtA,STC 0.013 0.350 KHTIOGTN S GAS 176 1 NOTE 1 Ntt 1 0019 1 NOTE I NR i I PC NC NNE MOPE NOTE I NOTE 5 UKTIN67DI 5 DIST 126 I NR 1 NOTE 1 NOTE 1 OOR 1 Ntt 1 ( NC NC NNE NOR NOR 1 IDTt 5 TANG KAU 6 OAS 301 1 NR 1 NOTE 1 NOR 1 NR 1 NR 1 I LIQUID 1.275I10.6 OT 1T STEAM SVI 10711 IM A L016 GRACE I OIL 30) I NOTE I NOTE 1 NOR 1 NOR 1 DOT[ 1 I DOLS OT By STEAM (SF.OSI,SII t0R I OUR 6 LONG IGCR 9 OAS 227 I DOTI 1 NR I NOT[ I OUR 1 NOTE I I OT IT STEAM SRI IOT1 1 I0114 LONG IGCI 9 OIL 221 I OUR 1 N7I 1 NR I NOTE I OUR 1 I OT BY STEAM L4.05I,511 1011 1 NOR 6 MNONAT 1 GAS 215 1 0.212 0.196 0.190 0.20 0.219 1 LIQUID 720110.3 OT a NNE TfA,Src 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,LtA,STC 0.06E 0.650 MANDAUI 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 0.0/7 0.650 MAND1(AI 3 DIST 124 1 NOTE 1 NOR 1 NOT[ 1 NR I IOU I I NC K DONE TOR 0.00 N011 5 1tNAIEI 1 CON. 442 1 NR 1 NOR I NOR i NOR 1 Ntt 1 I SOLID 560IIO.3 IC W NN1 ESF.501.15P 0.000 NR 5 MNA1/4 2 CON. 442 1 NOR L DOTI I NR I IOR 1 NOTE 1 1 TONS NC 6F NONE LSF.50I,15E 0.000 TOR 5 ONIONY RACK 1 W 730 1 0.016 0.007 0.040 0.006 0.116 I LIQUID 2.70110.6 OT OC wit LKA.STC,IIC 0.03I 0.730 • ONIONS RAM I OIL 150 I 0.222 0.20E 0.245 0.271 0.261 I OBIS OR OC WE ESF.251.LG,6TC,2%C 0.074 0.530 O1MN0 MAOR 2 GAS 750 1 OUR 2 0.023 0.012 0.109 O.I15 i OR OC NNE LW,STC,RC 0.021 $.In OWN MACE 2 OIL 750 1 0.1% 0.155 0.150 0.223 0.261 I OT OC NN1 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 LTQIID 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 RN1 LSF.25X,UA,STC 0.064 0.200 low A GAMS 173 I 0.03E 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 a "I LSF.25I.L&A,StC 0.09I 6.200 IINNM I GAS 410 I 0.013 0.039 0.069 0.091 0.104 ( OR OC NEW: L1A,STC,RC 0.012 0.ISO REDONDO 7 OIL 00 I NOTE 1 MR 1 NR 1 VOTE 1 OUR 1 1 OR OC NONt LSF.23I,Lq,StC,tN Ntt 1 0.550 IUN00 6 GAS 460 1 0.064 0.05E 0.064 0.097 0.143 1 OT OC 1O119 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 not LSF.2SI,LFA,STC,RC NOR 1 0.3% SN MRNDIN 1 us V 1 0.076 0.065 0.099 0.112 0.117 1 LIQUID 740110.3 1C N NR E[A,STC 0.01E 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 SAN BUNNN 2 GAS 63 I 0.067 0.079 0.OU 0.019 0.OR9 I 1C 6F Not LrA,GIC 0.011 0.730 SN UNWIND 2 OIL 63 1 0.250 0.250 0.251 0.247 0.244 I GC 6F Not LSF.251,UA,Stt 0.029 0.550 A SCE PNTICIPAIE'S SHIN - FOUR CORNERS 49X - MONAR 561. NOTES: 1) NI AN/N TEAT INPUT EQUATIONS DOES NOT EXIST. 2) NI TAXIES CAtCKATED UPON OFIIICAL TONMAS ARE NEGATIVE. 3) LIQUID FUEL P[NT CAPACITY, N NATURAL GAS STORAGE. 41 FUCM OF DESIGN, WIN 001. 5) N REGULATORY LIMIT, EXEMPT. 6) 09 POUM/1019 LIMIT. REVISION DAR: 09/04/6/ 7) FOUR COIN13S RACTIVE STORAGE. qr Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder OPERATIONS AND RELIABILITY DATA Phone. (818) 302-9514 PLANT NAME AND UNIT NUMBER Alamitos 1 Alamitos 2 Alamitos 3(4) Alamitos 4 Alamitos 5 Alamitos 6 Alamitos 7 Coal Water I Cool Water 2 Cool Water 30C Cool Water 4CC Ellwood 1 E1 Segundo I E1 Segundo 2 E1 Segundo 3 E1 Segundo 4 Port RR-8 CEC Contact: Art Soinski Phone: (9I6) 324-3160 ENTER 5-YEAR AVERAGE FOR DATA REQUEST BELOW ENTER ESTIMATED 1992 DATA(FUR EACH FIELD LISTED BELOW SUN (FOIL + BOOM) PON SUN (MOH + EPDH + SOFA) AVAIL. HRS. SERV. HRS. M. DWM. HRS. SIR! (FOH + EUGH) SUN (MOH + AVAIL. SERV. RES. OWN. PON EPDH + SOEH) HRS. HRS. HRS. 266 595 324 7.836 5,753 2,083 663 669 268 7,436 471 691 180 7,784 5,928 1,857 663 669 268 7,4l6 947 1,I78 347 6,651 5,863 787 (4) (4) (4) (4) 406 695 567 7,418 7,030 387 629 823 334 7,170 354 1,154 401 7.074 6,362 712 557 1,270 455 6.700 326 1,328 528 6,775 6,174 603 557 1,270 455 6,700 230 1,329 133 7,198 101 7,097 188(3) 1,085 204 7,388(3) 84 522 483 7,676 2,997 4,680 163(3) 567 243 7,901(3) 3,322 334 260 4,852 1,473 3,380 163(3) 457 243 7,901(3) 107 $03 290 7,772 2,232 5,540 61 769 129 7,681 477 734 624 7,600 2,357 5,244 61 769 315 7,681 437 1 128 8,222 47 8,175 I43(3) 0(3) (3) 8 509(3) 293 880 242 7,486 5,695 1,791 663 669 268 7,436 263 514 283 7,857 5.780 2,077 663 669 268 7,436 1,012 1,146 356 6,411 3,472 1,394 629 823 334 7,170 507 834 347 7,318 6,810 508 629 823 334 7,170 it Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder OPERATIONS AND RELIABILITY DATA Phone: (818) 302-9514 PLANT NAME AND UNIT NUMBER Etivanda 1(4) Etivanda 2(4) Etivanda 3 Etivanda 4 Etivanda 5 Highgrove 1(4) Highgrove 2(4) Highgrove 3(4) Highgrove 4(4) Huntington 1 Huntington 2 Huntington 3(4) Huntington 4(4) Huntington 5 Long Beach CC Mandalay 1 Fors RB-8 CEC Contact: Art Soinaki Phone: (916) 324-3160 ( 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. + EUGH) PON EPDH + SOEH) HRS. HRS.f HRS. + EUGH PON EPDH + SOEH) HRS. HRS. HRS. 293 345 234 7,913 3,36.� 4,544 (4) 378(4) (4) 7,885(4) 120 412 414 7,866 3,605 4,261 (4) 378(4) (4) 7,885(4) 631 617 ' 289 7,445 5,721 1,724 629 823 289 7, 170 243 546 341 7,809 7,477 751 629 823 334 7,170 160 868 238 7,623 '74• 7,549 188(3) 1,085 204 7,388 0 147 105 8,512 165 8,347 (4) (4) (4) (4) 0 181 89 8,495 156 8,339 (4) (4) (4) (4) 77 157 140 8,391 264 8.127 (4) (4) (4) (4) 0 285 313 8,167 451. 7,717 (4) (4) (4) (4) 295 937 301 7,408 7,070 338 275 726 274 7,529 429 61r 224 7,646 7,028 619 275 726 274 7,529 846 306 623 7,095 429 7,660 (4) (4) (4) (4) 588 790 605 6,841 3,521 3,220 (4) (4) (4) (4) 420 1,271 239 6,989 98 6,890 188(3) 1,085 204(3) 7,388 281 563 1,410 8,178 5,215 2,963 36 563 129 8,174 202 660 570 7,454 6,761 693 275 726 274 7,529 Utility Service Area: Southern California Ediaon Data Filed: September 1987 Utility contact. Ron 9chroeaer OPERATIONS AND RELIABILITY DATA Phone: Fora R8-8 CEC Contact: Art Soinaki Phone: (916) 324-3I60 ENTER 5-YEAR AVERAGE FOR DATA REQUEST DELOM ( ENTER ESTIMATED 1992 DATA FOR EACH FIELD PLANT NAME AND UNIT NUMBER SUM (FOR + EUOM) PON SUM (MOH + EPDH + SOER) AVAIL. HRS. SERV. NRS. RES. OWN. MRS. SUN (PON + EUGH SIB! (MOH + LISTED BQAY AVAIL. SERV, RES. DMN. PON EPDH + SOEN) MRS. MRS. MRS. Mandalay 2 I74 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) Mohave 2 2,234 994 22 6,043 6,043 0 1,407(3) 923 118 6,953(3) Ormond Beach 1 698 I.180 588 6,71I 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 I,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 I47 7,943 3,254 4,689 (4) 457 (4) 7,901(4) 1 DRS•ldn 2015/AES 09/04/97 Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder OPERATIONS AND RELIABILITY DATA Phone: (818) 302-9514 Form R8-8 CEC Contact: Art Soinski Phone: (916) 324-3160 (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. SUN (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 unite 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 extraordinaroutage 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. IM; RRS:Idn 2015/AES 09/04/87 Utility Service Area: Southern California Edison Date Filed: September, 1997 Utility Contact: Ron Schroeder OPERATIONS AND RELIABILITY DATA Phone: (818) 302-9514 Fora R-8, p. 2 of 2 CEC Contact: Art Soinaki Phone: (916) 324-3160 AMOUNT OF (2) HOURS OF MIN. HIM. START-UP FUEL UNIT ! OF ATTEMPTED t OF ACTUAL TOTAL HOURS SrHED. MAINTEN. MAI4NTEN. DURING / OF FORCED AVERAGE OF HOURS PER PLANT NAME AND UNIT NUMBER RAMPRATE DOWN TIME UP TIME (MIBtu) 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 2bg O SOS 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 5O2 770 558 8 232 Alamitos 5 150 2.0 O 6,200 2 8 8 258 O 3,239 8 528 Alamitos 6 I50 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 Water 3ST 300 0.1 O 200 3 77 73 75 394 694 9 123 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 2,000 Ellwood 1 900 0.1 0 100 5 51 38 a 218 0 7 39 E1 Segundo I Igo 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 Soinski 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 POH 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 0 0 256 0 0 Highgrove 4 120 2.0 0 330 6 29 29 0 4 193 0 0 Huntington 1 240 2.0 0 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 " Ir Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder Phone. (818) 302-9514 PLANT NAME AND UNIT NUMBER RAMPRATE Huntington 3 240 Huntington 4 240 Huntington 5 900 Long Beach 8ST ISO Long Beach 8CT Long Beach 9ST ISO Long Beach 9CT Mandalay 1 ISO Mandalay 2 ISO Mandalay 3 900 Mohave 1 168# Mohave 2 168t Ormond Beach 1 145 Ormond Beach 2 145 Redondo 5 ISO #Represents Edison's share OPERATIONS AND RELIABILITY DATA Form 1-8, p. 2 of 2 CEC Contact: Art Soinaki Phone: (916) 324-3160 (1) +.+. a>w uw�w tOR EACH FIELD BELOW AMOUNT OF START-UP OF l OF (2) TOTAL HOURS OF MIN. DOWN TIME MIN. UP TINE FUEL (MNatu) UNIT CNAR. ATTEMPTED ACTUAL HOURS SCHED. HAINTEN. MAINTEN. DURING # OF AVERAGE # STARTS STARTS CURTAILED MOIL PON CU_ TA_ I gFjRCED OF CED ��E 2.0 0 3,000 2 25 22 14 0 887 2.0 0 3,000 2 15 14 29 87 565 I8 121 0.1 0 200 5 85 76 623 2/3 158 10 145 O.1 0 200 3 1,677 1,466 269 0 380 3 154 0 0 2,2(A1 0 200 3 334 u 380 0 2,200 O 2.0 0 3.000 2 9 9 186 0 252 2.0 0 3,000 2 8 8 47 2 14 0.1 0 200 5 53 50 34 429 0 a 0 13 43 2,290 4 585 2.0 0 11,000 1 25 25 233 0 555 2.0 0 11,000 1 16 16 139 0 504 31 179 2.0 0 10,000 2 15 15 38 175 1,143 21 269 2.0 0 30,000 2 8 8 107 142 2,167 10 137 2.G 0 2,500 2 19 I9 94 67 289 g 3 33 5 390 Utility Service Area: Southern California Edison Date Filed: Septeaber, 1987 Utility Contact: Ron Schroeder Phone: (818) 302-9514 OPERATIONS AND RELIABILITY DATA Fora R-8, p. 2 of 2 CEC Contact: Art Sofnski Phone: (916) 324-3160 (1) - ' -- AMOUNT OF HOURS F START-UP / OF / OF TOTAL SCHED. MAINTEN. / OF AVERAGE / PLANT NAME AND UNIT NUMBER RAMPRATE MIN. DOWN TIME MIN. UP TIME FUEL MMBtu UNIT CHAR. ATTEMPTED STARTS ACTUAL STARTS HOURS CURTAILED MAINTEN. DURING FORCED OF HOURS PER 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 RRS:jh 2015/AES 09/04/87 4 utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder OPFKAIIUNS AhU HFIIABILIIY bA1A Phone: (818) 302-9514 Form R-8, p. 2 of 2 CEC Contact: Art Soinski Phone: (916) 324-3160 ENTER ACTUAL 1485 LAIA FOR EACH FIELN HELW 1 (3) AMOUNT OF (2) UbORS 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 (NHbtu) GUAR. STARTS STARTS LURTAIf EU MUH VON LURTAIL.HENT 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 original column label was "Hours of Scheduled Maintenance." Provided is Maintenance Outage flours (WIH) and 11Ianned Outage Hours (PON). (4) SCE does not tabulate maintenance hours worked during unit curtailments. RRS:,)h 2D15/AFS 09/04/87 Utility Service Area: Southern California Edison Date Fled: Sep-87 Utility Contact Ron Schroeder OFF SYSTEM LOSSES (MW) Forth R-9A CEC contact Melinda Merritt Phone: (916) 324-3148 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 Choila 3.68 10.50 10.50 Navajo 8.84 8.84 8.84 PGE ExdkvW 6.00 6.00 6.00 PGECont. 0.00 0.00 4.50 WW&P 3.60 3.60 3.60 APPA' -0.89 -0.89 -0.89 Oroville 14.00 14.00 14.00 Four Corners 22.00 22.00 22.00 Mexico Geothermal 0.00 0.00 1.74 IPP 0.00 0.00 5.56 IPP T/L 0.00 0.00 0.00 PP&L 0.00 0.00 0.00 COT Project 0.00 0.00 0.00 PNW Purchase 0.00 0.00 0.00 Total 90.23 97.05 108.86 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 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 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 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 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 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 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 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 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 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 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 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 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 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 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 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 UWW Somice Aron: Soohern CaMomta Edsm Gals Fled: S*"7 U" Contact RM Scroadw RESERVE Form ROB CECcoi ShbuGYr Phone: (916) 324.3153 19a4 1995 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1999 1999 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 PWnnkg An.(MMq 2165 3189 3721 3480 3227 3160 2922 2917 2757 2789 2784 2832 2895 2951 3008 3065 Spi wft Rea• (%) 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 Spkv*V 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 I 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 Alamitos or Stations, at parties. RMS:90 gas made into Edison's facilities at Huntington Beach Generating pressures agreed to between the 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 n PACIFIC GAS AND ELECTRIC COMPANY PRIORITY 3 GAS SERVICE AGREEMENT DATED NOVEMBER 18, 198,0 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. s 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 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 gas to Southern California 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. QUALITY: 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 I 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 15, 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 E1 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 Servke Area: Soosrm CaWOMkk Edison Die FAed: SeP-s7 UtiNly Contact: Ron Schroeder Data not AvaNaNe PROJECTED FUEL CONSUw1PT1ON AND CAPACITY FACTORS Form R-10A and 108 CEO contact PatMMM#Ad N Phone: (916) 324.3602 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 1. CFM VII FIXED CHARGE RATES GENERAL ASSUMPTIONS ------------------- 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 Ad Valorem Tax Insurance Total 3. Income Taxes: 1.00% 1.12% 0.10% 2.224 Investment Tax Credit (ITC) Federal Income Tax Rate State Income Tax Rate 4. Sources: Book Life (1) Salvage Value Federal Tax Depreciation (2) State Tax Depreciation (2) Construction Cash Flows (3) W 0.0% = 34.0% ■ 9.6% : Property Accounting : Property Accounting : Tax : Tax : Enaineerina 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: 29 36 DB 20 DOB 30 5.8 SUBSTATION 352-353 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 3.8atsam Mead. 116 103 12 109 92 17 66 40 25 5 5 Hydro Plant 4.ealsa 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. 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 Q £ £ !t t9s US 0 tL ft t sS 66 6S slip LLf 666t 0 £ £ ft 6£S £SS 0 It It t 95 LS S! Ss£ on 966t 0 £ £ It MS M 0 It It t W SL 6Z ft£ Of L66t 0 £ £ £L 66f US 0 Zt 2t 2 fa so 6Z t9Z 06Z 9"1 0 £ £ 2t on Z61F 0 it tt 9 IZL RL f! OR ill£ S66t o £ £ Zt I" £Lip O it It It M LLt O£ 69Z 66Z %6L o £ £ It £ff fSf 0 at at s 66 LOL LZ SZ2 "Z 566t 0 £ £ It 9Zf L£f 0 OL at f £9 L9 SL La 2Z2 Z66t 0 £ £ at Ot'r m 0 6 6 £ l5 is It , £LZ ft2 t66t, 0 Z 2 at 6s£ 66£ 0 6 6 9L fit 6Zt It "I tt2 066L 0 2 Z OL ss£ 96£ 0 9 s SL £sl 96L OL t6t t02 606L 0 Z Z at Ott on 0 Zt Zt ft lot 56t £Z 6st Zvi SOU 0 t L. 0 ltf tit it sts 6ts s ZSl 09t sot la 26£ "It 0 £ f n toil £f! It 92t Oft 9! f£f on '.70s-9s61 uolAlawt t f S it ZLf %£ In p030loom Lt sZt "I ZL £!S St9 '=I-Ss6L uolnlw jl u1 pw"PuI ZS 66 its Lfs sm sit$ Ott on sit* 66t 9Lft sm **"-fs6t OQUY 4000 10301 OOW 4000 10301 3orm MW3 10301 301W klm 1030L 300iY 4"3 10301 J001 ------------------------------"----------------------------•_--_------.-----------___---------------------------------•-------------- ww"Sm mm P007 Ljo13ug133210 u01303 M5 /A uo1303awt /M n013"O ng P0301*000V 3oll uolsslwwJl PO30tm9SY uolsslMwil 1156-20£ (its) -a m - 9ft£-f2£ OWL '-mml (>N01104 1M10e0 0 OntillM) 4*8*mpg u08 nmuD3 A3t113p _ MOS P?!lplll e}g3u0a 332 wol3lPPi 3u016 214=13 A311130 10301 jai ml j0gwvbs :P■lli 0300 £ t0 t -a £t-: wmi Lulve u0l3anj3ww3 63050.166y UOS1P3 01UJQ31103 UMNpn t ¢way 0olAwat A311130 r 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 Sumution (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. 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. 1996 116 108 a 1,018 966 52 n.a. n.a. n.a. .................. (1) Only plant closings are available. No forecasts made beyond 1991 D Utility Service Area: Southern California Edison Aggregate Construction Outlays Date Filed: September 1987 For Total Utility Electric Plant Additions Utility Contact: Ron Schroeder (Millions of Nominal Dollars) Phone: (bid) 302-9514 Estimated % of Total for --^-----------------------------------------------"----------------..--....---. Other Plants Summation (Totats) Pollution Control (1) Year Total Cash AFUDC Total Cash AFUDC Total Cash AFUDC 1997 122 113 9 1,OFR1 1,036 52 n.a. n.a. n.a. 1996 129 119 9 1,1a3 1,114 69 n.s. n.a. n.a. 1999 135 125 10 1,264 1,1E0 N. n.a. n.a. n.m. (1) Only plant closings are available. No forecasts made beyond 1991. Form R-13 p. 3 of 3 CEC contact: Richard Grix Phone: (9T6) 324.31" y Utility Service Area: Southern California Edison Pate Filed: September, 1987 Utility Contact: Ron Schroeder Phone: (818) 302-9514 NUCLEAR FUEL INVESTMENT (Millions of Nominal Dollars) Form R-14 CEC Contact: Richard Grix Phone: (916) 324-3146 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(1) 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. UWily Swviu Are: Soultwn CaMomhL E&w Deb Fled: Sap-87 UtIrAy CaMaot Ran Schroeder TOTAL VARIADLE ElIP 31M MiWons of Nominal Dollars 1984 1985 1986 1987 i988 1989 1990 1991 AckW AGuel Actual' Nuclear Fud Nuclear Ver. O&M Coal Fud Coal Variable O&M Natures Gas Fud Var.OSM: Gas Pharft RnWual Fud Var. OAM: ReA. Plants DiWMaM Fuel Var. O&M: Dis. Plan SpWWAc Fusis Var. OAM: SM Planer PtR PA Pun3rse Imports Firm Emwrry Sales to 09ws Fuel l"x%p TOW Form R-1SA CEC cwMaet Ridwd Gdr Phone: (916) 324-3146 1992 1993 1994 1995 1996 1997 1998 1999 100.00 97.00 t32.00 168.00 168.54 182-67 160.32 141.45 135.26 120.29 124.89 118.54 117.19 120.31 126.82 131.40 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 102.32 69.74 112.40 117.31 115.67 111.83 114,70 12S.26 127.96 132.02 138.73 143.69 151.84 158.68 168.02 176.51 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 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 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 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 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 0 0 0 0 0 44,56 44.19 41.83 50,29 47.11 56.83 55.41 59.73 55.07 6205 0 0 0 1.18 1.16 t.09 1.21 1.23 1.46 1.50 1.66 1.58 1.88 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 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 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 -23.25 -50.82 -22.21 -31.53 -69.19 -6S.53 -71.06 -76.75 -84.46 -89.76 -99.19 -10SA7 -116.25 -125.37-136.59 -147.81 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 SO-00 50.00 1390.32 2012.33 1456.41 1997.26 2143.35 2473.54 2796.85 2994.87 3262.56 3482.51 3822.55 4122.13 4420.28 4715.86 5050.4 5407.96 1964- 19M Deta not AvabMe for Variable O&M 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 6.13 MMBtu/Bbl 7.56 6.48 --Residual 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/ T/ --Brine Not Available T/ Not Available Svnthetics --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 Date Filed. September, 1987 Utility Contact: Ron Schroeder Phone: (818) 302-9514 Nuclear Coal --Conventional --Advanced Oil and Can Steam Combustion Turbine Combined Cvcle Hydro Pumped Storage TOTAL 1984 1985 1986 Actual Actual Actual Fora R-16 CEC Contact: Richard Crix Phone: (916) 324-3I46 FIXED OPERATION AND MAINTENANCE EXPENSES Millions of Nominal Dollars 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 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 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 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 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 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 7.28 7.59 7.90 9.17 9.48 8.80 9.13 9.56 10.09 10.67 11.33 12.07 12.85 13.68 14.56 I5.49 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 0.00 0.00 0.00 U.OU 0.UO 0.00 0.17 0.18 0.19 0.20 0.22 0.21 0.24 0.26 0.28 0.29 164.62 169.13 130.39 184.30 185.79 192.82 201.54 211.05 222.64 235.62 l51.80 272.50 290.21 313.13 333.11 354.13 x i Y Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder Phone: (818) 302-9514 FIXED OPERATION AND MAINTENANCE EXPENSES Millions of Nominal Dollars (Continued) 1984 1985 1986 1987 1988 1989 �• 1990 1991 1992 Actual Actual Actual Form R-16 CEC Contact: Richard Grix Phone: (916) 324-3146 1993 1994 1995 1996 1997 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 Distri- 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 I07,413 111,798 �112,054 117,990 122,076 126,027 132,900 140,667 148,818 156,843 Accounts i 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- 218,653 227,572 236,790 246,316 256,155266,317 276,809 287,638 298,814 310,358 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, FxpPnseN Adminls- 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 ration 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 ---...............'-..................................................'........--'---.................................._....... 1. hard Rate of Sew issues (1) 2. AFUDC Rate for (2): a. Equity Funds b. Borrowed Funds c. Total AFUDC 12.4% 11.2% 8.41 (See note below) 7.4% 7.8% 6.0% 2.8% 2.6% 2.5% 10.2% 10.4% 10.51 11.1% 10.1% 10.2% 10.2% 10.2% 10.2% 10.2% 10.32 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.a% 15.1% (See note below) 5. Capital Structure for System a. Percent Debt 45.8Z 46.6X 46.5% The debt rate, preferred yield, required return on common equity, and target capital structure are b. Percent Preferred 9.5X 8.6% 6.6% based upon an assessment of future uncertainty, and business and financial risks. These factors c. Percent Common 44.7% 44.a% 46_a% 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 19" through 1966, net of tax rates were used, for 1967 and on, gross rates were used because of charges to the tax law. (3) Sane issued VI } Utility Service Area: Southern California Date Filed: September 1987 Utility Contact: Ron Schroeder FINANCIAL VARIABLES ON 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 Nuclear Coal --Conventional --Advanced Oil and Gas Steam Combustion Turbine Cogeneration Biomass Geothermal --Vapor --Liquid Wind Solar --Photovoltaic --Thermal Fuel Cells Hydro Pumped Storage Transmission Distribution Pollution Control (indicate whre distinguishable Other Please refer to Appendix II of Form R-11 Form R-17B CEC Contact: Richard Grix Phone: (916) 324-3146 Federal Tax State Tax (Note: The economic life is equal to the book life) Utility Service Area: Southern California Edison Date Filed: September, 1987 Utility Contact: Ron Schroeder Phone: (818) 302-9514 1. GENERAL RATE OF INFLATION (I) 2. NOMINAL DISCOUNT RATE* (%) 3. REAL ESCALATION RATES (I) A. General Construction Costs Nuclear Coal --Conventional --Advanced oil and Gas Steam Combustion Turbine, Cogeneration Biomass Geothermal --Vapor --Liquid Wind Solar --Photovoltaic --Thermal Fuel Cells Hydro Pumped Storage Transmission Distribution Pollution Control Other a. FuelCosts Nucl Cool `t! Natural Gas Residual Oil Distillate OHM s Fora R-18 CEC Contact: Richard Grix Phone: (916) 324-3146 1984 Actual 1985 Actual INFLATION, DISCOUNT, 1986 1987 1988 Actual AND ESCALATION RATES 1989 19" 1991 1992 1993 1994 1995 1996 1997 1998 1999 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 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 (.2) (.6) .4 .5 .3 .3 .7 11 ((�2) t (.4) (.6) (.6) (.6) (.5) (.4) (.7) (2.2) (1.6) (1 7) (1.2) ((.6) (.7) (1.2) (.6) .4 .5 .3 .3 .7 .1 (.1) (A) (.6) (.6) (.6) (.5) (.4) NA NA NA hA 3 3 3 3 1 1 1 1 1 1 1 1 NA (5.8) NA (15.4) NA (39.1) NA NA (1.1) 3.6 (1.1) 3.6 (1. 1) 3.6 1.1 3.9 1.1 3.9 1.1 3.9 1.1 3.9 1.1 1.2 1.2 1.2 1.2 00.5) (7.3) (3.9) NA 3.6 3.6 3.6 3.9 3.9 3.9 3.9 3.9 3.9 3.1 3.1 3.1 3.1 3.1 3.1 3.1 3.1 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 i 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. RRS:jh 2176/AES:1-2 09/09/87 Utflity Service Area.- Southern California Edison Dote Filed: September 1987 Utilfty Contact: Ron Schroeder Phone: (318) 302.9514 Prices (CWAS/kW) Ultioote Customers (nominal S) Ultlsote Cnrtoaers (1955 S) WAtaalt Sala m& Ultimate Wotoaara Yrlaools TOTAL Capital, Reglitd (1) Construction Ratin two -Tom Debt Red to PWwred Stock Other TOTAL WITAL IEWIMO Sources of C"Atot (2) DeproeiatiaVAeortita%lon other Intanrt Sovces ►rapoeed Financing Ccurt Stock Preferred Stock Lang -Tort Debt Short -Tan Debt Other TOTAL SOIMICES 1984 1985 1986 Actual Actual Actual Financial Anotysis (Investor Owned Utilities) Fore R•19P p. 1 of 4 CEC contact: Richard OrfR Phone: (916) 324.31" 1937 1958 1959 1990 1991 1992 1993 1994 1995 1996 1997 IM 1999 7.80 8.06 8.35 8.44 8.75 9.45 9.55 9.79 MOT 10.38 10.83 11.27 11.67 11.99 12.31 12.70 8.19 8.09 7.95 7.65 7.56 7.77 7.48 7.31 7.16 7.03 6.96 6.92 6.82 6.69 6.53 6.42 5.86 6.12 6.17 (not available) 58,2T1 59,30Z 60,430 63,450 64,00 65,980 6T,380 69,273 70,732 71,639 72,596 75,580 74,617 75,827 77,132 78,500 5.039 5,60 3.767 860 850 850 a" No 060 me we 860 WO 860 am 860 63,310 64,W 64,197 64,310 65,740 66,830 65,240 70,133 71,592 72,499 73,459 74,440 75,477 76,687 77,992 79,360 SM $1,076 $1,090 S1,023 SUP $a% S7W IM S798 $875 S9% S909 S%6 S1,W St,113 $1,180 499 09 t,o34 328 204 135 414 171 168 108 183 109 509 140 9 11I 20 21 19 13 21 23 Is 11 t1 11 11 13 13 14 1S 13 a 0 0 34 149 151 152 154 156 158 159 161 1" 1" 169 170 Si,3T1 $1,796 $2,943 $1,446 $1,243 S7,167 St.300 $1,108 51,133 $1,152 S1,349 $1.272 S1,65Z $1,357 $1,305 $1,475 S399 $435 S505 SSM S64S S690 S731 $740 S774 5807 $09 Sa79 $912 $942 5966 S994 5 9 17 424 2S4 NO 230 261 226 213 1ST too 169 177 135 115 209 91 4 0 0 0 0 0 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 a 0 0 0 0 0 0 a 630 1.112 1,427 325 275 250 375 175 200 175 350 225 575 225 200 373 128 129 "1 171 33 (t44) 43 (69) (68) (44) (ZT) (U) (7) fie 2 tit) 0 D 0 2 2 2 2 2 2 2 2 2 2 2 2 2 $1,371 S1,754 $2,943 $1,447 $1,244 $1,168 11,391 S1,109 $1,134 $1,153 $1,351 S1,272 $1,651 51,356 $1.305 $1,475 .................. (1) Total syaton (2) Includes the drwdo n of pollution control issues and the rollover of high coupon debt at lower interest rates. y wr eam�r r ew.utms w: eumerma ewe oaermaa w. r rarer ar arw+mmee nor rswmnw �w es aermr r crane ar. � r rem aare�a err smr � wa nsue.ra a.rar arrea amp wr rya a"rn'a�wromr�r:a � sr u..�im r�mw s ra as a eedenw. r e1 1 i Utility Service Area: Southern California Edison Financial Analysis Fors 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 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 Debentures Other Long -Tors Debt Assets Utility Plant at Original Cost • lass Accumulated Depreciation Net Utility Plant (electric) NIP (electric) Other Assets (less other limb.) TOTAL ASSETS Capitalization end Liabilities Comm Stock Retained Earnings Total Common Equity Preferred Stock Mortgage Bonds Debentures Total Long -Term Debt Total Capitalizetion Accumulated Deferred Inc. Taxes Due to Accelerated Deprecistn ACCwtated Deferred ITC total Liabilities TOTAL CAPITALIZATION i LIABILITIES OPERATING REVENUE Operating and Maintenance Expenses Fuel (other than natural gas) Purchases Natural Gas (electric) PURPA Purchases Net Purchases from Other Utilities 70TAL FUEL AND PURCHASED POWER S3,849 $3,771 $4,037 14,785 14,856 S4,971 14,932 S4,936 $4,967 15,034 $5,200 S5,317 15,383 $5,465 $5,659 S5,922 352 234 156 (included in first Mortgage Bonds) 148 529 578 (included in First Mortgage Bonds) $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 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 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 1,649 2,042 1,342 1,340 275 434 214 234 296 410 657 588 298 419 648 674 295 494 68 (379) (369) (262) (206) (88) 23 99 155 192 250 322 420 537 $10,256 $11.237 $11,501 $11,512 $11,823 S12,160 $12,351 S12,534 112,707 $12,899 i13,180 S13,397 S13,561 $13.781 314,098 S14,487 $2,356 s2,447 $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 S5,454 1,887 2,129 2,344 Oncluded in Cannon Stock) 4,243 4,575 4,794 4,644 4,731 4,818 4,906 4,950 4,994 5,035 5,083 5,125 5,172 5,266 5,360 5,454 908 882 683 657 636 612 597 586 576 564 553 540 527 513 498 485 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 5,922 754 1,007 752 (Included in First Mortgage Bads) 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 s9,500 S10,219 S10,248 S10,OB6 $10,223 110,401 $10,435 s10,472 s10,537 S1O,636 $10,836 $10,985 S11,082 S11,247 $11,517 S11,861 337 532 708 892 1,083 1,261 1.435 1,598 1,726 1,836 1,936 2,024 2,110 2,182 2,248 2.310 399 436 545 534 517 500 481 463 445 426 407 389 370 351 333 314 786 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 $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 S13,780 s14,098 S14,485 $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 $356 $501 S377 S456 $361 s345 $370 $360 $355 S352 $361 S367 1374 S389 S400 $418 1,122 1,in 501 723 524 374 400 410 517 628 789 *1 1,060 1,260 1,391 1,552 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 2,368 546 534 446 364 441 473 505 548 603 605 650 665 739 753 354 1,027 S2,085 $2,359 S1,654 S1,961 s2,112 12,455 s2,776 s2,971 s3,239 13,455 s3,795 $4,092 $4,398 $4,651 S5,012 s5,365 t+o reee�rrilte w cabin " t 4 S~" teaser rtattee g ,ae }i pte > tetrhslee rmmY e rCtetem erMS Y stair e! WA" w. rltO M seelre O 0000a mtere abttYr eCe ton et 1~te sweet drertYlm tam Te leis yegl" AND so 06tWnaa ee tY oI10000ft � rnsmse A tat sW \ widsm. W Utility Sarrfee Area: Sartharn Caltfornia Edison Date Filed: September 1967 Utility Contact: Ron Schroeder Phone: (eis) 30Z-9514 19" 1985 1986 Actual Actual Actual ...................... Financial Analysis (Investor Owxd Utilities) Fors R-19P p. 3 of 4 CEC Contact: 81Chard @ix Phone: (916) 324-31" 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1990 1999 ..................................................................................................... Generation Related OW 5378 5349 $401 $432 VA7 5476 5501 55DO $514 5530 $562 S59t WS $"I 5695 $730 Other am 632 637 695 702 721 752 762 809 842 373 929 992 1,059 1,124 1,199 1.280 Cam rvatlM Expnes 61 84 71 54 61 66 65 66 67 67 69 71 72 74 76 78 TOTAL ON (W fuet and purchases) $3,176 $3,459 52,821 $3,149 $3,341 $3,749 54,104 $4,346 24,662 $4,927 55,355 55,746 $6,142 56,540 56,962 57,453 DeproctattaVAamKtzatton ISM) CS152) $674 $611 $769 5914 5736 5826 S541 $571 1884 $909 S88S EBBS 183a 5850 Tara Fodwal Inoaa Taxis 5398 5466 13T3 $461 $430 SW 5423 5471 S511 SS56 $556 SS" $557 $532 SS26 $514 State Income Taxes 57 25 108 (Included in Federst Income Tax**) ` Sefu red Taw (due to Accol Oapr) 130 146 in 134 191 178 174 163 128 110 100 88 86 72 66 Q ITC Adjustment (rat) 55 84 39 05) (16) (19) (18) (18) (19) C19) (19) C19) (19) (19) C19) C19) Normalized Interat Expense (7ncludod In Federal Income Tax**) Other Taw (1) t21 131 143 130 M 78 167 134 137 133 13S 10 165 190 203 209 TOTAL TAXES $761 2852 5854 5764 $724 5725 St" $750 5757 2780 Sift 2773 2789 5795 S"6 ST" TOTAL OPERATING SWIMS 23,876 54,159 24,349 24.524 $4,04 15,388 55,586 15,922 $6,260 26,573 $7,011 ST,428 S7,1116 $8,190 SB,596 59,069 Other Incom and Deductions Alteumee for Wty Funds Used b rfro Construction 5746 5123 $106 S74 SX $25 S27 S19 S22 S29 340 S42 131 $32 242 $51 TIC Amortization 68 84 97 0 0 0 0 0 0 0 0 0 0 0 0 0 Other --Nat 34 48 51 112 52 44 39 36 31 26 19 12 6 2 0 0 TOTAL DIM INCOIE AND DE000TIORS 5249 SMS 5254 $186 Sm $69 S66 $55 S53 S55 $59 S54 $37 $34 24Z $51 OPERATING INC. BEFORE TNT. CNARGES 51,271 $1,265 51,217 SI,137 $1,055 $1,05T 51,070 57,084 $1,093 51,095 51,096 51,113 21,t27 $1,139 $1,145 $1,165 Interest Charges Long-term $443 $419 $420 $444 5455 $464 5463 5462 5462 $465 1476 $490 S50Z $511 $526 $50 Short-term 8T 69 63 (Included in Long-term) Allowance for borrowed Funds Used Durime Caatnict(on C49) (35) (29) (43) (23) (17) (18) (12) (15) (19) C27) (28) (21) (21) (29) (34) TOTAL INTEREST MUCES $01 $453 $454 $401 5435 5447 5445 $450 $447 $446 $449 $462 $481 5490 5498 $514 1............."" (1) )netuudes Deferred Taxes on Regulatory Balancing Accents, Other Deferred Taxes, Property Taxes, and Payroll Taxes. ee r.nemxwmw r sweet w ss arsmawms a� erne t wa wont w asemws sera sow amnrr aes.wsr w w seurem see met at mss�e aauosw r e.w w nrrmssa enwa was serstwa r emus w w wa ra x ssnnw. t f Utility Service Ares- Southern California Edison Financial Analysis form R-19P p. 4 of 4 Date Filed: September 1987 (Investor owned Utilities) CEC contact: Richard Grin 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 Preferred Dividends Balance for Comtson Rate Rase (1) Rate of Return on Rate Rue Rate of Return on Common Equity (2) Embedded Interest Note on Bonds Roody's Coverage Ratios (3) Before Tax After Tax Debenture Indenture Coverage Required Expected Revenue Requirements (millions) $789 $812 $763 S736 $620 S610 $625 $634 5646 'S649 $647 $651 $646 S649 SW $651 73 72 55 51 50 48 - 46 45 44 43 41 40 39 37 36 35 716 740 705 685 570 562 579 589 602 606 606 611 607 612 611 616 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 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% 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% 12.0X 12.0% 12.0% 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% 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 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 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 4.4 4.8 4.6 (not &vat table) $4,899 35,169 $5,312 $5,475 $5,803 S6,376 $6,590 S6,951 $7,300 S7,618 S8,048 $8,487 $8,906 $9,295 $9,699 S10,183 .................. (1) Assuming continuation of existing regulatory policies (i.e., no CUIP in rate base). (2) The company's authorized return has been wed for 1987. for 1988.99, the California Public Utilities Commission Staff has provided these rates, which were also used in the Company's G.D. 131E 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. Tlla tAla�mtlM aM n'a'I}fma fa 1r tllllarM Means aImIMIM mea T{ W Me M tlil WiT nitre aML1/ICIfr emmM L /wutm ax mn Mw. to SWUM +r /aelr'a M/IwrM ra IpaY! fM tr 1010 CIJ.IrYIA r///a " Sal M m/IaaY AI/ Ws ma CMlafVlailaDa aaaMa 1Is 71� laaOalmll�M aa�am.IWM•M fa Illma ap0 A W19I00. I