ML17298A469

Updated Environ Rept for Facilities,Vols 1-4

ML17298A469
Person / Time
Site:	Palo Verde
Issue date:	12/31/1981
From:	ARIZONA PUBLIC SERVICE CO. (FORMERLY ARIZONA NUCLEAR
To:
References
ENVR-811231, NUDOCS 8307290153
Download: ML17298A469 (186)

Text

{{#Wiki_filter:8307290153 Sii231 PDR ADQCK 05000528 C PDR PALO VERDE NUCLEAR GENERATING STATION 8$;L~l%r~~r I JI C r.j.kL..$c P 4, 4'0 p>~frp~~jr 2 J ,Cj'fE.r PVNGS ER"OL LIST OF EFFECTIVE PAGES This List of Effective Pages identifies those text pages and figures that are currently effective in the ER-OL.Pa e or'Fi ure No.Title Page ivA-ivB Chapter 1 Tab 1-ii-iv 1-iva-ivB 1 1.1 Tab 1.1-1-1.1"3 1.1-4-1.1-4A 1.1-4B 1.1~5'..1"9 1.1'-9A F 1"9B 1.1-8 vA-vB vi Fig.F-1 (Sht 1 of 2)Fig.F-1 (Sht 2 of 2)vii Vl.il ix xi xll xiii xiv Issue Original Original Sup 4 Sup 4 Sup 3 Sup 3 Sup 3 Original Original Original Sup 2 Original Sup 4 Sup 2 Sup 4 Original Original Sup 2 Sup 3 Sup 4 Original Original Original Sup 4 Sup 3 Original Sup 2 Sup 3,.Sup 2 Pa e or Fi ure No.1.1-10-, 1.1"186 1.1"187" 1.1'-190 1.1"190A-1.1-190H 1.1-191-1.1-222 1.1-223-1.1-239 1.1-240-1.1"242 Fig.1.1-1-1.1"8 1.2 Tab 1.2-1 1.3 Tab 1.3-1-1.3-2 1.3-3, 1.3"4-,.1.3.-23 1.3-24-1.3-38 1.3-39 1'-40-1.3-45 1.3-46 1.3-47-1.3-73 1.3-74 1A Tab Appx 1A Title Page 1A-i 1A"1-1A-2, 1A"3 1B Tab Appx 1B Title Page 1B-1" 1B-7 Fig.1B-1 1C Tab Issue Original Sup 2 Sup 1 Original Sup 3 Sup 4 Original Original Original Original Sup 2 Sup~4 Sup 3 Sup 2 Sup 3 Sup 2 Sup 3 Sup 2 Sup 4 Original Original Sup 3 Sup 2 Sup 3 Original Original Original Original Original December 1981 A Supplement 4 PVNGS ER-OL'Pa e or Fi ure No.Issue Pa e or Fi ure No.Issue Appx 1C Title Page Subtitle Page Contents Page 1C-1-1C-31 Fxhibits Title Page 1C"A-1" 1C-A-8 1D Tab Appx 1D Title Page 1D"1-1D-4 1E Tab Appx 1E Title Page lE-1 1F Tab Appx 1F Title Page 1F"1-1F"3 1G Tab 1G Title Page IG-1-1G"14 Fig.1G"1" 1G-2 lH Tab Appx 1H Title Page 1H-1-1H-26 1I Tab Appx lI Title Page 1I-1-1I-27 1J Tab Appx 1J Title Page 1J"1" 1J"9 IK Tab Appx 1K Title Page 1K-1-1K-4 1L'Tab""'-'ppx lls<<Title Page Original-Original Original Original Original Original Original.'riginal Original'riginal Origina%Original-" Orig'ina1.u Original~Original Original Originals Original Original/Original Original Original Original Original Original.2-zv 2 viii 2-ix-2-x 2.1 Tab 2.1-1" 2.1-4 2.1-5-2.1-6D 2.1"7 2.1-8-2.1-9 2.1"10 2.1-10A-2.1"10B" 2.1"11-2.1-12 2.1"13" 2.1"14 2.1-15." 2.1-16'2.1"17-2.1"31'2.1-32 2.1"33-2.1-34'2.1-35 Fig.2.1"1-2.1-2 Fig.2.1"2A Fig.2.1-3-2.1-16 2.2 Tab 2.2-1" 2.2"21 Fig.2.2-1-2.2-2 2.3 Tab 2.3"1-2.3"12-2.3-13 Original-2.3-14-2.3-45 Original'.3-46 Original--1L-1-1L-11 Original-1M Tab" Gr'iginal--Appx 1M Title Page On:ginal 1M-1-1M-14-Originals-' Chapter 2 Tab Original-'.2-i-2-ii Original': 2-iii Original Original Original Original Original Sup 2 Original Sup 2 Original Original Original Sup 2 Sup 1 Original Sup 3 Sup 2 Sup 2 Original Sup 1 Original Sup 1 Original Sup 2 Original Sup 2 Original Original Original Original Original Original Sup 1 Original Sup 2 Supplement 4 December 1981 PVNGS ER-OL Fig.2.4"1 Fig.2.4-4 Fig.2.4-4 Fig.2.4"5 Fig.2.4-7 Fig.2.4-7 Fig.2'-7 Fig.2.4-7 Fig.2.4-7 2.5 Tab-2.4-3 (Sht 1)(Sht 2)-2.4-6 (Sht 1)(Sht 2)(Sht 3)(Sht 4)(Sht 5)2.5"1" 2.5-4 Fig.2.5-1-2.5-4 2;6 Tab 2.6-1-2'-4 2.?Tab 2.7"1" 2.7"2 Fig.2.7-1-2.7-3 2A Tab Appx 2A Title Page 2A"i 2A-1-2A"2 2A-3-2A-4 2A"5 M~-6-2A-10 2B Tab Appx 2B Title Page Pa e or Fi ure No.2.3-46A 2.3-46B 2.3-47 2.3-48-2.3-48B 2.3-49-2.3-63 Fig.2.3-1-2.3-22 2.4 Tab'.4-1-2.4-9 Issue Sup 4 Sup 2 Original Sup 2 Original Original Original Original Original Original Original Original Original Original Original Original Original ,Original.Original.Original" Original OriginalOriginal Sup 2 Original Original Original Sup 2 Sup 1'Sup 2 Sup 3 Sup 2 Original Original Pa e or Fi ure No.2B-1';.-2B.-5 2C Tab Appx 2C Title Page 2C-1'.;2C;5 Chapter.3 Tab 3 i*>>.It 3 ii;>>, 3 3.1l.3-iv-3-ivB 3 v 3 vi 3.1 Tab F 1-1-3.1-3 3.1-4 Fig.3.1-1,-3.1-11 3.2 Tab 3.2-1-,.3.2"2 3;3 Tab 3.3".1 3~3,2,'>>'3~3 3 Fig.,"=,$.3-1 (Sht 1)Fig.3.3-1 (Sht 2)Fig.3.3-1 (Sht 3)Fig.3.3-1 (Sht 4)3.4,Tab 3.4-1-3.4-5 3.4-6 3.4-7.--3.4-13 Fig.3.-4-1-3.4-9 3.5 Tab 3.5'-1-3.5-30 3.5-31 3.5-32-3.5-42 Fig,,3.5-1 Fig.'.5-2 (Sht 1)Issue Original Original Original Original Original Original Sup 3 Ori;ginal Sup 2 Original Original'riginal Sup 1 Original Original Sup 2 Original Sup 4 Sup 2 Original Original Original Original Original Original Sup 3 Original Original Original Original Sup 3 Original, Original , Original December 1981 supplement!>> 4 PVNGS ER"OL Pa e or Fi ure No.Issue Pa e or Fi ure No.Issue Fig.3.5-2 (Sht 2)Fig.3.5-2 (Sht 3)Fig.3.5-3 (Sht 1)lig.3.5-3 (Sht 2)Fig.3.5-4-3.5-5 1'ig.3.5-6 (Sht 1)1'ig.3.5-6 (Sht 2)Fig.3.5-7 3.6 Tab 3.6-1 3.6-2 3.6-2A-3'-2B 3.6-3 3.6-3A 3.6-3B 3.6-4 3.6-5 3.6-6-3.6>>6B 3.6-7-3.6-9 3.6-10-3.6"10B 3.6-11 3.6-12 3.6-13 3.6-14 Fig.3.6-1-3.6"5 3.7 Tab 3.7-1 3.7"2-3.7-5 3.8 Tab 3.8"1 3.9 Tab 3.9-1-3'"9 3.9-10 3.9"ll-'3.9-12 Original 0'iiginal'.9-13 3.9"14" 3.9-15 Original" Original Original Original Sup 3 Sup 2 Sup 2 Sup 3 Sup 2 Sup 2 SLlp 4 Sup 2'riginal Sup 2 Original Sup 3 Sup 4 Sup 2 Original Original Original Sup 2 Original Original Original Original" Sup 1 Original'. Fig.3.9-5 3A Tab Appx 3A Title Page 3A-i 3A"1" 3A"4 3A-5 3A-6-3A-13 3A"14-3A-16 Chapter 4 Tab 4-i-4-iv 4.1 Tab 4.1-1-4.1-17 Fig.4.1-1 4.2 Tab 4.2-1-4.2-4 4.3 Tab 4.3-1-4.3-4 4.4 Tab 4.4-1-4.4-2 4.5 Tab 4.5-1-4.5-15 Fig.4.5-1-4.5-2 4A Tab Appx 4A Tz.tie Page Chapter 5 Tab 5-i 5-ii 5 1ii 5 v Original'ig.3.9-1-3.9-2=Original Fig, 3,9 3 Original'ig.3.9-3A-3.9-3B Original Fig.3.9 4 Sup 2 Original Sup 2 Original Sup 1 Original Sup 2 Original Original Sup 3 Sup 2 Sup 4 Sup 2 Sup 3 Original Original Original Original Original Original Original Original Original Original Original Original Original Original Original Original Original Sup 2 Sup 4 Sup 2 Supplement 4 D December 1981 PVNGS ZR-OL Pa e or Fi ure No.5.1 Tab 5.1-1-5.1-10 5'-11-5.1"'4 5.1"15-5.1-16 5.1"17-5.1-19 5.1"20, 5.1-21-5.1-22 5.1-23-5.1"24 Fig.5.1-1-5.1-12 5.2 Tab 5.2-1-5.2-3 5.2"4-5.2-5 5.2-6 5.2"7 5.2-8 5.2"9" 5.2-12 Fig.5.2-1 5.3 Tab 5.3-1" 5.3-4 5.4 Tab 5.4"1 5.'4-2 5.4-3-5.4-4 5.4-5-5.4-6 5.4-7" 5.4-9 5.5 Tab 5.5"1" 5.5-6 Fig.5.5-1-5.5-3 5.6 Tab 5.6-1-5.6-2B 5.6-3-5.6-3B 5.6-4 5.6-5 5.6-6 Issue Original Original Sup 2 Original Sup 2 Original Sup 2 Original Original Original Original Sup 3 Original Sup 3 Original Sup 3 Original Original Original Original Sup 4 Sup 2 Sup 4 Sup 2 Sup 4 Original Sup 2 Sup 2 Original Sup 4 Sup 4 Sup 2 Original Sup 2, 6.1-21 6.1-29 6.1-32-6.1-28 6.1-31B-6..1-34A Pa e or Fi ure No.5.6-7-5'.6-8 5.6"9"-5.6>>14 5.6-15, Fig.5.6.-1 Peleted Fig.5.6-2, 5.7 Tab.5.7-1 5.8 Tab 5.8-1-5.8-2 5A Tab Appx 5A Title Page 5A-.i 5A-1 5A-2-5A-8 5B Tab Appx 5B Title Page 5B-i 5B-1-5B-4 5B-5/5B-6 Blank 5B"7 5B-8-5B-18 5C Tab Appx 5C Title Page 5C-1-5C"8 Chapter 6 Tab 6-i 6-ii 6-iii-6"iv 6.1 Tab..6.1-1-6.1-19 6.1-20-6.1"20D Issue Original Sup 2 Sup 4 Sup 2 Original Original Sup 4 Original Original Original Original Sup 2 Sup 4 Sup 2 Original Original Original Original Sup 3-Original Sup 3 Sup 2 Sup 2 Sup 2 Original Sup 4 Original Sup 4 Original I Original Sup 2 Original Sup 4 Sup 4 Decenber 1981 Supplement 4 PVNGS ZR-OL Pa e or Fi ure No.6.1-34B fi.1-35-6.1-41 6.1"42 Fig.6.1-1 6.2 Tab 6.2-1-6.2"2 6.3 Tab 6.3-1-6.3-6 6.4 Tab 6'-1-6.4-2 6A Tab Appx 6A Title Page 6A-i 6A-1-6A-2 6A-3-6A-5 Chapter 7 Tab l 1 7 111 7.1 Tab 7.1-1-7.1"27 7.2 Tab 7.2-1 7..3 Tab 7.3-1" 7.3-4 7A Tab'ppx 7A Title Page Chapter 8 Tab 8-i-8-ii 8'Tab 8.1-1-8.1-5 8.1-6-8.1-6B 8.1"7" 8.1'-8 8.1-9-8.1-12 8.1-13-8.1"18 8.2 Tab Issue Sup 1 Original Sup'Sup 4 Original Original Original Original Original Original Original Original Sup 2 Sup 1 Sup 2 Original Original Original Original Original Original Original Original Original Original Original Sup 4 Original Original Sup 2 Sup 2 Original Sup 4 Original Pa e or Fi ure No.8.2-1-8.2"4 8A Tab Appx 8A Title Page 8A-i 8A-1-8A-2 Chapter 9 Tab 9-i 9-1 9A Tab Appx 9A Title Page Chapter 10 Tab 10-i 10"1 10A Tab Appx 10A Title Page Chapter ll Tab 11-i 11-1-11-4 llA Tab Appx 11A Title Page Chapter 12 Tab 12-i-12-ii 12-1-12-12 12A Tab Appx 12A Title Page Chapter 13 Tab 13"i 13-1 13A Tab Appx 13A Title Page Issue Original Original Original Sup 2 Sup, 2 Original Original Original Original Original Original Originals Original Original Original Original Original Original Original Original Original Original Original Original Original Original Original Original Original Original Supplement 4 December 1981 PVNGS ER-OL FOREWORD The Environmental Report-Operating License Stage (ER-OL)for the Palo Verde Nuclear Generating, Station (PVNGS)Units 1, 2 S 3 is part of the joint application for licenses authorizing Arizona Public Service Company to construct, operate and main-tain PVNGS on its own behalf and as agent for all other joint applicants. Palo Verde Nuclear Generating Station, including each of Palo Verde Units 1, 2 and 3, is currently jointly owned by the joint-applicants listed below, sometimes referred to as"Parti-cipants," as tenants in common with undivided ownership inter-ests in the respective percentages hereinafter set forth, all in accordance with the Arizona Nuclear Power Project Participa-tion Agreement, dated as of August 23, 1973, as amended by Amendment Nos.1 through 4.Joint A licants Arizona Public Service Company Salt River Project Agricultural Improvement and Power District (APS)(SRP)Undivided Interest 29.1%29 1%Southern California Edison Company'SCE)15.8%El Paso Electric Company (EPE)15.8%Public Service Company of New Mexico (PNM)10.2%However, pursuant.to an agreement dated August 18, 1977, between SRP and the Department of Water and Power of the City of Los Angeles (LADWP), SRP will transfer to LADWP, and LADWP will acquire from SRP, a 5.7%undivided ownership interest as a tenant in common with the other Participants in the Palo Verde Nuclear Generating Station, including each of Palo Verde Units 1, 2 and 3, at such time as Palo Verde Unit 1 is placed into commercial operation (i.e., when it is deemed to be available PVNGS ER-OL FOREWORD as a reliable source of electric generation). For this reason, LADWP has been included in.the descriptions of the need for PVNGS (Chapter 1)and the benefits derived from PVNGS (Chapter 8).In addition, pursuant to an assignment, agreement executed as of August 14, 1981 by SRP-and the Southern California Public Power Authority (SCPPA);.SRP will transfer to SCPPA, and SCPPA will acquire from SRP, a 5.91%undivided ownership interest as a tenant in common with the other Participants in the Palo Verde Nuclear Generating Station, including each.of Palo Verde Units 1, 2 and 3, following (a)receipt of the approval of such transfer and acquisition by the Commission and (b)the sale by SCPPA of revenue bonds or notes, or any combination thereof, in an aggregate principal amount at least sufficient to make the payment required under the terms of the Assignment Agreement. SCPPA is a public entity created pursuant to Section 6500 et~se.of the California Government Code and the Joint Powers Agreement among its members dated as of November 1, 1980.The members of SCPPA are the California Cities of Anaheim, Azusa, Banning, Burbank, Colton, Glendale, Los Angeles, Pasadena, Riverside and Vernon, and the Imperial Irrigation District.Because of the transfer to SCPPA, load, resource and energy mix data applicable to the members of SCPPA have been included in the descriptions of the need for PVNGS (Chapter 1).In accordance with an assignment agreement executed as.of December 1, 1981 by EPE and the M-S-R Public Power Agency (MSR), EPE will transfer to MSR, and MSR will acquire from EPE, a 3.95%undivided ownership interest as a tenant in common with the other Participants in the Palo Verde Nuclear Generating Station, including each of Palo Verde Units 1, 2 and 3, following (a)receipt of the approval of such transfer and acquisition by the Commission and any other state or federal agencies as required and (b)the sale by MSR of revenue bonds Supplement 4 iv December 1981 PVNGS ER-OL FOREWORD or notes, or any combination thereof, in an aggregate principal amount at least sufficient to make the payment required under the terms of the Assignment Agreement and (c)execution of a contract for transmission services.MSR is a public entity created pursuant to Section 6500 et~se.of the California Government Code and the Joint Powers Agreement among its members dated as of April 29, 1980.The members of MSR are the California Cities of Santa Clara and Redding and the Modesto Irrigation District.Because of the transfer to MSR, load, resource, and energy mix data applicable to the members of MSR have been included in the descriptions of the need for PVNGS (Chapter 1).The PVNGS Units 1, 2 and 3 are scheduled for commercial opera-tion in May 1983, May 1984, and May 1986, respectively. The ER-OL presents a description of PVNGS and its environmental impacts, as well as changes to the description since the Envi-ronmental Report-Construction Permit Stage (ER-CP), Docket Numbers STN-50-528, 529, and 530 and Final Environmental State-ment (FES)NUREG-75/078. For those instances in which there December 1981 ivA Supplement 4 PVNGS ER-OL FOREWORD This page intentionally blank Supplement 4 ivB December 1981 PVNGS ER-OL FOREWORD have been no changes, the redder is so informed and the ER-CP is briefly summarized.- The ER-OL adheres to the format, content, style, composition, and physical specifications required by NRC Regularory Guide 4.2, Revision 2, as modified by the August 24, 1976 Errata sheet,.This environmental report incorporates by reference applicable portions of the PVNGS Final Safety Analysis Report (FSAR)to the extent allowed by Regulatory Guide 4.2 for reference to the FSAR or the Preliminary Safety Analysis Report (PSAR).All text pages are numbered by chapter and section as required by Regulatory Guide 4.2.Tables and illustrations are numbered in a similar manner;e.g.table 1.1-1 is the first table in section 1.1.Each table is placed in the text following the page on which it is first referenced. Figures are placed at the end of each section.The engineering symbols used on piping and instrumentation dia-grams (PAID's)are shown on figure F-1.Standards used for editorial abbreviations and symbols are the latest editions of the following American National Standards Institute publica-tions: ANSI-Y1.1, Abbreviations; ANSI-Y10.5, Letter Symbols for Quantities used in Electrical Science and Electrical Engi-neering;and ANSI-Y10.9, Letter Symbols for Units used in Science and Technology. The ER-OL includes answers to NRC requests for additional infor-.mation in the NRC letters from Mr.D.G.Eisenhut to Mr.E.E.Van Brunt,, Jr., dated June 18, 1980, and from Mr.R.L.Tedesco to Mr.E.E.Van Brunt, Jr., dated February 13, 1981 and April 17, 1981.The questions and responses or locations of responses are provided in Appendix A of the appropriate chapter July 1981 Supplement 3 PVNGS ER-OL of the ER-OL.The cross-reference list from NRC to ER-OL question number is as noted below:.FOREWORD question number NRC UESTION NUMBER ER-OL VEST ION NUMBER Section 1.1.2 Section 2.1.2.3 Section 2.3 Section 2.3 Section 3.1.3.1 Section 6.1.5.5.3 Section 6.2 240.1 240.2 240.3 240.4 290.1 290.2 290.3 290.4 290.5 290.6 290.7 290'.8 290.9 290.10 291.1 291.2 291.3 291.4 291.5 291.6 291.9 291.10 291.11 291.12-3.7.3.3 lA.l 2A.l 2A.2 2A.3 3A.1 6A.1 6A.2 3Ai2 3A.3 3A.4 3A.5 6A.3 3A.6 6A.4 5A.l.5A.2 5A.3 5A.4 3A.7-5A.5 5A.6 3A.8 3A.9 3A.10 3A.ll 3A.12 3A.13 3A.14 3A.15 3A.16 3A.17 Supplement 3 vA.July 1981 PVNGS ER-OL NRC UESTION NUMBER FOREWORD ER-OL UESTION NUMBER 291.12-5.6.2 291.13 291.15 291.16 291.17 291.18 291.19 291.20 291.21 291.22 291.23 291.24 291.25 291.26 291.27 291.28 291.29 291.30 310.1 310.2 310.3 310.4 310.5 310.6 310.7 310.8 310.9 311.1 311.2 311.3 311.4 311.5 320.1 320.2 5A.7 5A.8 2A.4 2A.5 3A.18 3A.19 3A.20 3A.21 3A.22 3Q.23 3A.24 3A.25 3A.26 3A.27 3A.28 3A.29 3A.30 3A.31'A.9 5A.10 2A.6 2A.7 2A.8 2A.9 5A.ll 8A.1 8A.2 2A.10 2A.ll 2A.12 2A.13 2A.14 1A.2 lA.3 July 1981 vB Supplement 3 PVNGS ER-OL NRC UESTION NUMBER FOREWORD ER-OL UESTION NUMBER 320.3 320.4 320.5 320.6 320.7 320.8 450.1 lA.4 1A.5 lA.6 lA.7 1A.S 1A.9 2A.15 Supplement 3 V3.July 1981 PVNGS ER-OL NEED FOR POWER Table 1.1-1 LOADS AND RESOURCES

SUMMARY

1964 THROUGH 1992 (Sheet 1 of 7)PVNGS-1, 283 PARTICIPANTS 1964 1965 1991 1992 1990 Year 1966 1967 1968 1969 1970 1989 1971 1986 1988 1972 1973 1979 1980 1981 1982 1983 1984 1985 1987 1977 1974 1975 1976 1978 25090 26179 27255 742 764 26123 26943 27997 1036 777 25346 26166 26961 127155 133201 139499 7457 8005 136781 141206 146956 618 618 136163 140588 146338 31575 32044 33661 178 178 174 108 31570 32114 33665 670LI 5948 24.6 22-7 24 9 28339 776 29115 1036 28079 145536 7377 152913 618 152295 34103 56 34159 6080 21.7 29390 30488 810 848 30200 31336 1036 1036 29164 30300 151921 157945 7707 7592 159628 165537 618 618 159010 164919 35674 36699 56 56 35730 36755 6455 6566 22.5 21-3 31528 886 3241LI 1036 31378 163581 7423 171004 618 170386 38603 56 170 7111 38489 22.7 35411 33111 34217 430 447 414 33525 34647 35858 1036 1036 1036 32489 33611 34822 185974 171117 179747 4839 4948 4457 190922 177574 184586 618 618 618 176956 183968 190304 39417 40854 41661 56 56 56 300 300 202 7195 7397 6984 39473 41008 42017 20.7 21.5 22.0 36630 464 37094 1036 36058 192750 5170 197920 618 197302 42881 56 600 43537 7479 20.7 PRO APERTURE CARD 1.1-15/16 Blank 1.1.1 Load characteristics, demand (MW)11020 120LI9 12907 10351 9602 Company peak demand Firm sales outside PVNGS-1,2 6 3(a)Annual peak demand (PVNGS+FSO)Firm purchases outside PVNGS-1,2 8 3(a)Adjusted annual peak demand (APD-FPO)129 65 46 60 50 9/31 10416 11066 12099 12967 87 157 205 293 741 9644 10259 10861 11806 12226 1.1.1 Load characteristics, energy (GWh)56702 52426 61913 66207 71455;ompany energy Firm energy sales outside PVNGS (a)Annual energy (PVNGS+FES)Firm energy purchases outside PVNGS (a)Adjusted annual energy (AE-FEP)1620 784 685 860 834 540 LI6 57486 62598 67067 72289 81 254 306 405 577 53965 57232 62292 66662 71712 1~1.2 Power supply (MW)12611 11853 Installed resources Nonfirm purchases (a)Noncommitted purchases (a)Nonfirm sales (a)Nonfirm sales-Layoff (a)Capability (IR+NFP-NFS) 13582 15084 15464 47 147 1LI8 140 135 13727 15221 15596 11897 12755 1.1.3 Capacity requirement Reserve (C-AAPD)(MW)Reserve margin (/I)3415 3370 2496 2866 2253 23.4 24.3 26.4 28.9 27.6 a.Sales and purchases to Companies other than the PVNGS-1,263 participants. 13869 68 13937 660 13277 77109 1201 78310 844 77 LI6 6 16579 130 16706 3429 25.8 14793 16441 17677 69 171 151 14862 16592 17848 801 780 741 14061 15812 17107 82305 87412 93411 2640 1318 1962 83623 89374 96051 908 1372 825 82715 88002 95226 18108 18591 20660 124 123 348 18229 18712 21006 4168 2900 3899 29.6 18.3 22.8 18444 284 18728 806 17922 97298 3323 100621 965 101586 22403 17$22571 4649 25.9 18442 18620 19999 345 384 369 18787 19004 20368 926 792 773 17861 18212 19595 94151 96141 100248 3163 4667 3653 97314 99794 104915 739 672 634 96575 99122 104281 23653 24515 25433 365 369 179 24016 24884 25612 6017 6672 6155 34.5 36.6 30.7 20375 917 21292 910 20382 103779 7719 111498 786 110712 26271 179 26LI50 6068 29.8 21706 22210 22803 830 726 551 22257 22936 23633 862 989 777 21268 22084 22856 107236 110699 116294 8466 5296 7988 112532 118687 124760 1098 618 1198 11133LI 117589 124142 26817 27067 28289 179 339 239 16 15 17 26981 27290 28611 5755 5206 5713 26.9 23.6 25.2 24091 931 25022 989 24033 121807 8955 130762 618 130144 29007 419 16 100 29310 5277 22.0 1033 777 9626 618 178 183 6224 PVNGS ER-OL NEED FOR POWER 1983 1984 1985 3051 3384 3215 411 0 423 0 439 0 411 423 439 3462 3823 3638 (6)~231)(6)(6)~241)~251)(218)(228)(237)(247)(257)3225 3566 3391 15772 16721 13032 13863 14881 2773 17654 (32)2879 18651 (32)2991 19712 (32)18619 19680 15629 16569 17622 4242 4142 3786 15 62 15 62 0 62 62 77 77 0 0 0 4304 4219 3863 738 20.7 828 24.4 638 19.8 1986 1987 3547 3728 455 0 472 0 455 472 4002 4200 (6)(6)~262)~273)(268)(279)3734 3921 17564 18485 3109 20673 (32)3244 21729 (32)20641 21697 4598 4598 0 62 0 62 62 62 4660 4660 739 18.8 926 24.8 1988 1989 3905 4595 489 0 489 4394 4595 (6)~284)(6)~296)(290)(302)4104 4293 19490 24068 3379 22869 (32)24068 (32)22837 24036 5076 5076 0 62 0 62 62 62 0 0~170)(170)4968 5138 845 19.7 864 21.1 1990 1991 1992 4787 4970 5151 4787 4970 5151 (6)~307)(6)~331)(6)~319)(313)(325)(337)4474 4645 4814 25333 25992 26983 25992 (32)25333 (32)26983 (32)25301 25960 26951 5554 5554 5854 0 62 0 62 0 62 62 62 62 0 0~202)(202)5916 5414 5616 1102 22.9 940 21.0 971 20.9 LOADS AND RESOURCES

SUMMARY

1964 THROUGH 1992 (Sheet 2 of 7)Table 1.1-1 PRC APERTUpp CARD 1.1-17/18 Blank ARIZONA PUBLIC SERVICE COMPANY Year 1.1.1 Load characteristics, demand (MW)Company peak demand Firm sales outside PVNGS 1,2&3 Firm sales within PVNGS 1, 2&3 Total firm sales (TFS)Annual peak demand (CPD+TFS)Firm purchases outside PVNGS 1, 2&3 Firm purchases within PVNGS 1,2&3 Total firm purchases (TFP)Adjusted annual peak demand (APD-TFP-ID) 1.1.1 Load charact~~istics, energy (GWh)Company energy Firm energy sales outside PVNGS 1,2&3 Annual Energy (CE+FES)Firm energy purchases outside PVNGS 1,2&3 Adjusted annual energy (AE-FEP)1.1.2 Power supply (MW)Installed resources Nonfirm purchases outside PVNGS 1,2&3 Nonfirm purchases within PVNGS 1,2&3 Total nonfirm purchases Nonfirm sales outside PVNGS 1, 2&3 Nonfirm sales within PVNGS 1,2&3 Nonfirm sales-Layoff Total nonfirm sales Capability (IR+NFP-NFS)1.1.3 Capacity requirement Reserve (C-AAPD)(MW)Percent margin (100xR/AAPD) (%)1964 775 100 0 100 875 0~67)(67)808 4063 927 4990 4990 1267 0 62 62 (3)0 0 (3)1326 518 64.1 1965 1966 875 805 13 0 32 0 13 32 888 837 0 0~59)~42)(42)(59)846 778 4507 4134 276 4410 72 4579 4579 4410 1262 1270 0 62 0 62 62 62 (3)0 0 (3)(3)0 0 (3)1321 1329 475 56.1 551 70.8 1967 888 12 0 12 900 0~58)(58)842 4609 63 4672 4672 1255 0 62 (3)0 0 (3)1314 472 56.1 1968 969 13 0 13 982 0~54)(54)928 4869 73 4942 4942 1255 0 62 62 (3)0 0 (3)1314 386 41.6 1969 1130 13 0 13 1143 0~56)(56)1087 5405 82 5487 5487 1381 0 62 62 (3)0 0 (3)1440 353 32.5 1970 1260 13 0 13 1273 0~92)(92)1181 5835 83 5918 5918 1501 0 62 62 (3)0 0 (3)1560 379 32.1 1971 1972 1349 1587 58 0 72 0 58 72 1407 1659 0~96)0 (113)(113)(96)1546 1311 6394 7470 358 6752 468 7938 7938 6752 1540 1734 175 62 0 62 237 (2)0 0 (2)(2)0 0 (2)1969 1600 423 27.4 289 22.0 1973 1703 108 0 108 1811 0 (142)(142)1669 8207 576 8783 8783 1981 0 62 62 (2)0 0 (2)2041 372 22.3 1974 1898 134 0 134 2032 0 (171)(171)1861 8795 702 9497 9497 2139 127 62 189 (2)0 0 (2)2326 465 25.0 1975 1976 1977 1912 2083 1987 156 0 204 0 290 0 204 156 290 2068 2191 2373 (6)~152)(6)(152)(158)0~171)(171)(158)1897 2033 2215 8596 9651 9019 1269 9865 1586 10605 (32)1885 11536 (32)9865 10573 11504 2565 2560 2235 16 62 100 62 16 62 162 78 78 2643 2638 2397 610 30.0 423 19.1 500 26.4 1978 2212 337 0 337 2549 (6)~183)(189)2360 10459 1691 12150 (32)12118 2795 16 62 78 2873 513 21.7 1979 1980 2343 2541 346 0 372 0 346 372 2913 2689 (6)(195)(201)(6)~203)(209)2488 2704 10905 11907 2243 13148 (32)2507 14414 (32)13116 14382 2795 3037 1.6 62 16 62 78 78 3115 287 3 411 15.2 385 15.5 1982 1981 2736 2874 385 0 400 0 400 385 3121 3274 (6)(6)~212)~222)3046 2903 2629 15661 (32)2738 16601 (32)3384 3740 15 62 77 16 62 78 0 0 0 0 0~100)(100)3817 3362 771 25.3 459 15.8 PVNGS ER-OL NEED FOR POWER 1983 4488 4488 4488 22134 103 22237 0 22237 5707 5707 1219 27.2 1984 1985 1986 4923 4772 4618 4923 4618 4772 0 4923 4772 4618 22902 23733 24596 0 24596 0 0 23733 0 0 22902 0 22902 23733 24596 6090 6167 6094 6090 6094 6167 1167 23.7 1322 27.7 1549 33.5 1987 5077 5077 5077 25481 0 25481 0 25481 6336 6336 1259 24.8 1990 1991 1988 1989 1992 5537 5691 5230 5846 5383 5691 5846 5537 5230 5383 5846 5691 5537 5230 5383 29040 30015 26436 27260 28149 0 0 28149 29040 0'0 30015 0 0 26436 0 0 27260 0 26436 27260 28149 29040 30015 7350 7360 6976 7222 6582 0 0 7350 7360 7222 6976 6582 1504 25.7 1669 29.3 1586 30.4 1593 29.6 1352 25.8 LOADS AND RESOURCES

SUMMARY

1964 THROUGH 1992 (Sheet 3 of 7)Table 1.1-1 PRC APERTURE CARD 1.1-19/-20 Blank LOS ANGELES DEPARTMENT OF WATER AND POWER Year 1.1.1 Load characteristics, demand (MW)Company peak demand Firm sales outside PVNGS 1,2&3 Firm sales within PVNGS 1,2&3 Total firm sales (TFS)Annual peak demand (CPD+TFS)Firm purchases outside PVNGS 1,2&3 Firm purchases within PVNGS 1,2&3 Total firm purchases (TFP)Adjusted annual peak demand (APD-TFP-ID) 1.1.1 Load characteristics, energy (GWh)Company energy Firm energy sales outside PVNGS 1,2&3 Annual Energy (CE+FES)Firm energy purchases outside PVNGS 1, 2&3 Adjusted annual energy (AE-FEP)1.1.2 Power supply (MW)Installed resoures Nonfirm purchases outside PVNGS 1,2&3 Nonfirm purchases within PVNGS 1, 2&3 Total nonfirm purchases Nonfirm sales outside PVNGS 1,2&3 Nonfirm sales within PVNGS 1, 2&3 Total nonfirm sales Noncommitted Capability (IR+NFP-NFS) 1.1.3 Capacity requirement Reserve (C-AAPD)(MW)Percent margin (100xR/AAPD) (%)1964 2123 2123 2123 11063 0 11063 0 11063 2475 2475 352 16.6 1965 2303 2303 2303 12037 0 12037 0 12037 2895 2895 592 25.7 1967 1966 2407 2679 2407 2679 2407 2679 13093 14091 0 0 13093 14091 13093 14091 2800 3486 3486 2800 393 16.3 807 30.1 1968 1969 1970 2772 2935 3107 2775 2938 3110 2775 2938 3110 16158 17049 15123 0 15123 0 21 16179 0 18 17067 0 15123 16179 17067 4027 3683 3820 4027 3683 3820 917 29.5 882 30.0 908 32.7 1971 3439 3442 3442 17803 41 17844 0 17844 3915 3915 473 13.7 1972 1974 1973 3630 3679 3500 78 0 78 78 0 78 3633 3757 3578 3633 3757 3578 18800 18879 16818 166 18966 0 286 19165 0 282 17100 0 18966 19165 17100 4130 4759 5311 4130 4759 5311 1733 48.4 1002 26.7 497 13.7 1975 3594 78 0 78 3672 3672 17652 455 18107 0 18107 5435 5435 1763 48.0 1976 1977 1978 3809 3778 4144 75 0 11 0 75 3812 3853 4155 3812 3853 4155 18800 18497 19462 385 19185 0 87 18584 0 445 19907 0 19185 18584 19907 5672 5720 5716 5672 5720 5716 1517 36.5 1863 48.4 1908 50.1 1979 4016 100 0 100 4116 4116 19711 652 20363 0 20363 5702 5702 1586 38.5 1980 1981 1982 4157 4259 4366 120 0 120 0 120 0 120 120 120 4277 4379 4486 4277 4379 4486 20536 20966 21499 764 22263 0 685 21221 0 692 21658 0 21221 21658 22263 5707 5707 5707 5707 5707 5707 1221 27.2 1328 30.3 1425 33.3 PVNGS ER-OL NEED FOR POWER 1983 932 52 0 52 984 984 4,206 4,591 4,924 276 5, 200 4,442 4,845 5,200 1,033 1,178 1,174 0 0 0 0 0 0 1,033 1,178 1,174 190 19.3 1984 984 54 0 54 1,038 0 0 0 1,038 5,274 283 5,557 5, 557 1,348 0 0 0 0 0 0 1,348 310 29.9 1985 1986 1987 1,057 1,108 1,163 58 0 58 60 0 60 56 0 56 1,113 1,166 1,223 0 0 0 0 0 0 1,113 1,166 1,223 5, 610 6, 350 6, 617 327 6, 944 310 6,660 296 5,906 5, 906 6, 660 6, 944 1,348 1,548 1,559 0 0 0 0 0 0 0 0 0 0 0 0 1,348 1,548 1,559 336 27.5 382 32.8 235 21.1 1988 1,212 63 0 63 1,275 1, 275 6,536 338 6,874 6, 874 1, 609 0 0 0 0 0 0 1, 609 334 26.2 1991 1990 1989 1, 271 1,322 1,377 68 0 68 67 0 67 65 0 65 1,336 1,389 1.445 0 0 0 0 0 0 1,336 1,389 1,445 6,846 7,125 7,423 349 7, 195 366 7,789 363 7,488 7,195 7,488 7,789 1,609 1,745 1,745 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1,609 1,745 1,745 300 20.8 356 25.6 273 20.4 1992 1,431 70 0 70 1,501 0 0 0 1,501 7.713 375 8,088 8,088 1,836 0 0 0 0 0 0 1,836 335 22.3 Table 1.1-1 LOADS AND RESOURCES

SUMMARY

1964 THROUGH 1992 (Sheet 4 of 7)PRC APERTURE CARD 1.1-21/22 Blank EL PASO ELECTRIC COMPANY Year 1.1.1 Load characteristics, demand (MW)Company peak demand Firm sales outside PVNGS 1, 2&3 Firm sales within PVNGS 1,2&3 Total firm sales (TFS)Annual peak demand (CPD+TFS)Firm purchases outside PVNGS 1,2&3 Firm purchases within PVNGS 1,2&3 Total firm purchases (TFP)Adjusted annual peak demand (APD-TFP-ID)1.1.1 Load characteristics, energy (GWh)Company energy Firm energy sales outside PVNGS 1,2&3 Annual energy (CE+FES)Firm energy purchases outside PVNGS 1,2&3 Adjusted annual energy (AE-FEP)1.1.2 Power supply (MW)Installed resources Nonfirm purchases outside PVNGS 1,2&3 Nonfirm purchases within PVNGS 1,2&3 Total nonfirm purchases Nonfirm sales outside PVNGS 1,2&3 Nonfirm sales within PVNGS 1,2&3 Total nonfirm sales Noncommitted Capability (IR+NFP-NFS) 1.1.3 Capacity requirement Reserve (C-AAPD)(MW)Percent margin (100xR/AAPD) (%)1964 272 29 0 29 301 0 0 0 301 1,520 81 1,601 1,601 419 0 0 0 0 0 0 419 118 39.2 1967 1965 1966 322 323 297 33 0 33 33 0 33 38 0 38 330 355 361 0 0 0 0 0 0 0 0 0 330 355 361 1,606 1,708 1,823 122 1,945 88 1,694 102 1,810 1,694 1,810 1,945 419 530 530 0 0 0 0 0 0 0 0 0 0 0 0 419 530 530 169 46.8 175 49.2 89 27.0 1968 356 44 0 44 400 0 0 0 400 1,938 232 2,170 2, 170 495 0 0 0 495 95 23.8 1971 1970 1969 396 416 446 55 0 55 52 0 52 53 0 53 469 501 448 0 0 0 0 0 0 448 469 501 2, 135 2, 252 2,422 240 2, 662 326 2, 461 254 2,506 2,461 2,506 2,662 536 642 642 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 536 642 642 141 28.1 88 19.6 173 36.9 1972 482 61 0 61 543 0 0 0 543 2, 643 319 2, 962 2, 962 756 0 0 0 756 213 39.2 1973 1974 1975 546 554 555 72 0 72 84 0 84 85 0 85 618 638 640 0 0 0 0 0 0 618 638 640 2,866 2,901 2,996 403 3,269 455 3, 356 454 3,450 3,269 3,356 3,450 740 716 840 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 740 716 840 200 31.3 78 12.2 122 19.7 1976 595 82 0 82 677 0 0 0 677 3,160 392 3, 552 3,552 940 0 0 0 940 263 38.8 1977 1978 1979 599 654 680 58 0 58 36 0 36 38 0 38 657 690 718 0 0 0 0 0 0 0 0 0 657 690 718 3,299 3,424 3,616 173 3,472 193 3,809 165 3, 589 3,472 3,589 3,809 890 900 885 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 890 900 885 167 23.3 210 30.4 233 35.5 1980 745 40 0 40 785 0 0 0 785 3,913 217 4,130 4, 130 977 0 0 0 977 192 24.5 1981 800 45 0 45 845 845 236 4,442 0 0 0 188 22.2 1982 861 48 0 48 909 0 0 0 909 254 4,845 0 0 0 269 29.6 PVNGS ER-OL NEED FOR POWER 1983 1, 076 241 0 241 1, 317 1,317 6, 321 2, 038 8,359 8, 359 1,656 76 0 76 1,580 1,317 263 20 1985 1986 1984 1,165 1,265 1,352 221 0 221 237 0 237 205 0 205 1,370 1,486 1,589 0 0 0 1, 370 1,486 1, 589 6,871 7,459 7,996 1, 642 9, 101 1,760 9, 756 1,706 8,577 9,101 8,577 9, 756 1, 786 1, 786 1, 916 0 0 0 0 0 0 0 0 0 142 0 142 1,644 1,786 1,916 1,370 1,486 1,589 327 21 300 20 274 20 1987 1,445 256 0 256 1, 701 0 0 0 1,701 8, 575 1,883 10,458 10, 458 2, 055 2, 055 1,701 354 21 1990 1988 1989 1, 565 1, 659 1, 783 303 0 303 289 0 289 274 0 274 1, 839 1, 948 2, 086 0 0 0 1, 839 1, 948 2, 086 9,269 9,958 10,713 2, 127 12, 085 2, 015 11, 284 2, 230 12, 943 11 284 12 085 12 943 2, 405 2, 405 2, 405 0 0 0 0 0 0 300 2,405 2,405 2,705 1,839 1, 948 2, 086 619 30 457 23 566 31 1991 1, 928 319 0 319 2, 247 0 0 0 2, 247 11, 514 2, 347 13, 861 13,861 2,405 300 2, 705 2, 242 458 20 1992 2, 089 334 0 334 2,423 2,423 12, 387 2, 458 14,845 14,845 2, 405 0 0 0 600 2,945 2,423 522 22 Table 1.1-1 LOADS AND RESOURCES

SUMMARY

1964 THROUGH 1992 (Sheet 5 of 7)PRC APERTURE)CARD 1.1-23/24 Blank PUBLIC SERVICE COMPANY OF NEW MEXICO Year 1.1.1 Load characteristics, demand (MW)Company peak demand Firm sales outside PVNGS 1,2&3 Firm sales within PVNGS 1,2&3 Total firm sales (TFS)Annual peak demand (CPD+TFS)Firm purchases outside PVNGS 1,2&3 Firm purchases within PVNGS 1,2&3 Total firm purchases (TFP)Adjusted annual peak demand (APD-TFP-ID) 1.1.1 Load characteristics, energy (GWh)Company energy Firm energy sales outside PVNGS 1,2&3 Annual Energy (CE+FES)Firm energy purchases outside PVNGS 1, 2&3 Adjusted annual energy (AE-FEP)1.1.2 Power supply (MW)Installed resources Nonfirm purchases outside PVNGS 1,2&3 Nonfirm purchases within PVNGS 1,2&3 Total nonfirm purchases Nonfirm sales outside PVNGS 1, 2&3 Nonfirm sales within PVNGS 1,2&3 Total nonfirm sales Noncommitted Capability (IR+NFP-NFS) 1.1.3 Capacity requirement Reserve (C-AAPD)(MW)Percent margin (100xR/AAPD) (%)1964 1965 1966 268 303 316 0 0 0 0 0 0 316 268 303 0 0 0 0 0 0 303 268 316 1,474 1,577 1,682 0 1,474 0 1,577 0 1, 682 1,474 1,577 1,682 333 333 333 0 0 0 0 0 0 333 333 333 268 303 316 30 10 17 5 65 24 1967 316 316 0 0 0 316 1,779 0 1,779 1,779 333 0 0 0 333 316 17 5 1968 1969 1970 341 372 399 0 0 0 0 0 0 341 372 399 0 0 0 0 0 0 372 341 399 1,919 2,094 2,272 0 1, 919 0 2, 094 0 2.272 1, 919 2, 094 2, 272 437 333 541 0 35 35 0 50 50 0 0 0 0 0 0 368 487 541 341 372 399 115 31 142 36 27 8 1971 455 0 0 0 455 455 2,534 0 2, 534 2, 534 541 541 455 86 19 1972 1973 1974 486 533 566 18 0 18 0 0 0 486 533 584 0 0 0 0 0 0 0 0 0 486 533 584 2,771 2,914 3,060 0 2,771 0 2, 914 54 3,114 2, 771 2, 914 3, 114 541 561 726 17 42 59 17 10 27 17 57 74 0 0 0 0 0 0 600 635 753 486 533 584 102 19 169 29 114 23 1975 556 30 0 30 586 586 3,369 152 3,521 3,521 726 0 85 85 0 0 0 811 586 225 38 1976 1977 1978 584 620 683 126 0 126 49 0 49 95 0 95 633 715 809 75 0 75 0 0 0 715 734 633 3,417 3,480 3,740 448 3,865 1, 039 4, 519 1, 063 4, 803 412 3,865 4,519 4,391 720 858 842 0 60 60 0 115 115 0 95 95 0 0 0 918 815 957 734 633 715 223 30 203 28 182 29 1979 745 164 0 164 909 75 0 75 834 4, 253 1,376 5, 629 480 5, 149 842 60 0 60 0 0 0 902 834 68 8 1981 1982 1980 814 883 979 275, 0 275 252 0 252 212 0 212 1, 026 1, 135 1, 254 0 0 0 1,026 1,135 1,254 4,691 5,118 5,690 1, 905 7,023 2, 145 7,835 1,586 6, 277 6,277 7,023 7,835 1,071 1,071 1,656 240 0 240 160 0 160 151 0 151 0 0 0 1,231 1,311 1,505 1,026 1,135 1,254 251 20 176 16 205 20 1983 2, 541 60 229 289 2,830 (160)0 (160)2, 670 335 12,776 (586)12,190 3,615 163 0 163 0 (202)(202)3, 576 2, 670 906 33.9 1984 2, 652 60 239 299 2,951 (160)0 (160)2,791 12,441 13,050 335 13,385 (586)12, 799 3, 912 163 0 163 0~13 2 (132)3, 943 2, 791 1,152 41.3 1985 2,790 60 251 311 3,101 (160)0 (160)2, 941 13,853 336 14,189 (586)13,603 3, 906 56 0 56 0~132)(132)3, 830 2, 941 889 30.2 1986 1987 1988 2,909 3, 024 3,103 60 260 320 60 271 331 60 282 342 3,229 3,355 3,445 (160)0 (160)0 (160)0 (160)(160)(160)3,195 3, 069 3, 285 14,545 15,307 15,850 336 15,643 336 16,186 (586)15,600 336 14,881 (586)14, 295 (586)15, 057 4, 203 4, 203 4, 203 56 0 56 56 0 56 56 0 56 0~62)(62)0~62)(62)0~62)(62)4,197 3,285 4,197 3,195 1,002 31.4 4,197 3, 069 1, 128 36.8 912 27.8 1989 1990 3, 178 3, 276 60 302 362 60 292 352 3,530 3,638 (160)0 (160)0 (160)(160)3, 370 3,478 16,375 17,057 336 17,393 (586)16, 807 336 16,711 (586)16,125 4, 203 4, 203 56 0 56 56 0 56 0~62)(62)0~62 (62)4,197 3,478 4, 197 3, 370 719 20.7 827 24.5 1991 1992 3,376 3,474 60 312 372 60 322 382 3,748 3,856 (160)0 (160)0 (160)(160)3,696 3, 588 17,795 18,552 336 18,131 (586)17,545 336 18,888 (586)18,302 4, 503 4, 323 56 0 56 56 0 56 0~(6 2 (62)0~62)(62)4, 317 3,588 4,497 3,696 801 21.7 729 20.3 PVNGS ER-OL NEED FOR POWER Table 1.1-1 LOADS AND RESOURCES

SUMMARY

1964 THROUGH 1992 (Sheet 6 of 7)P R.C APERTURE GARO 1.1-25/26 Blank SALT RIVER PROJECT 1965 1964 1968 1967 1966 1970 1969 1972 1971 Year 197 3 1974 1.1.1 Load characteristics, demand (MW)(a)Company peak demand 1,055 1,120 1,360 1,448 944 762 679 652 609 547 1,645 26 140 31 169 0 111 0 94 0 55 55 0 90 0 53 53 0 56 56 0 38 38 0 56 56 0 61 61 Firm sales outside PVNGS 1, 2&3 Firm sales within PVNGS 1, 2&3 Total firm sales (TFS)90 166 200 1,145 1,214 1,471 1,614 999 815 735 690 665 608 Annual peak demand (CPD+TFS)1,845 (205)0 (87)0 (87)(293)0 (157)0 Firm purchases outside PVNGS 1,2&3 Firm purchases within PVNGS 1, 2&3 Total firm purchases (TFP)(404)0 (423)0 (400)0 (378)0 (365)0 (430)0 (409)0 (423)(404)(365)(430)(378)(400)(157)(205)(409)(293)Adjusted annual peak demand (APD-TFP-ID)1,436 810 1,106 1,184 722 599 437 442 485 508 521 1.1.1 Load characteristics, energy (GWh)Company energy (includes interruptible energy)3, 313 3,518 4,364 4,936 5,419 6,119 6,586 2,849 3,102 2.777 7,464 178 7, 642 (739)6, 903 114 6, 700 0 6, 119 0 4,936 0 5,419 0 4,364 0 3, 518 0 3,313 0 2, 849 0 2.777 0 3, 102 Firm energy sales outside PVNGS 1, 2&3 Annual energy (CE+FES)Firm energy purchases outside PVNGS 1,2&3 Adjusted annual energy (AE-FEP)(577)2, 941 (405)2, 908 (306)2,796 (254)2, 595 (81)2, 696 (965)5, 735 (825)5, 294 (908)(1,372)4,028 4,047 (844)3, 520 1.1.2 Power supply (MW)681 610 610 611 608 607 845 1,155 1,336 1,627 758 Installed resources Nonf irm purchases outside PVNGS 1, 2&3 Nonfirm purchases within PVNGS 1,2&3 Total nonfirm purchases 147 0 147 47 0 47 148 0 148 130 0 130 135 0 135 140 0 140 124 0 124 156 0 156 123 80 203 153 0 153 221 0 221 0~62)(62)0~62)(62)0~62)(62)0~62)(62)0~62 (62)0~62)(62)0~62 (62)0~62)(62)0~62)(62)0~62)(62)0~62 (62)Nonfirm sales outside PVNGS 1,2&3 Nonfirm sales with in PVNGS 1,2&3 Total nonfirm sales Noncommitted Capability (IR+NFP-NFS) 1, 786 1,436 749 820 683 693 688 697 592 986 1,249 1,427 810 599 437 442 508 485 521 1.1.3 Capacity requirement 1,106 1,184 722 350 24.4 143 12.9 243 20.5 98 13.6 176 21.7 246 56.3 150 25.0 246 55.7 185 36.4 212 43.7 Reserve (C-AAPD)(MW)Percent margin (100xR/AAPD) (%)71 13.6 (a)SRP carries some interruptible load on its system, but this load is assumed to be zero at the time of SRP's annual peak demand.Interruptible demand is not included in the peak load forecast and no generation is planned to supply interruptible demand.1975 1976 1977 1978 1979.1 634 1 732 1 731 1,854 2,065 31 158 35 169 141 150 41 236 46 193 239 204 291 277 1, 838 1, 921 2, 022 2, 131 2, 304 (162)0 (181)0 (299)0 (297)0 (160)0 (181)(162)(299)(297)(160)1,657 1,759 1,723 1,834 2,144 7, 667 7, 936 8, 226 8, 591 9, 555 284 9,839 363 8,589 306 8,897 171 7, 838 236 8,172 (602)7, 570 (754)8, 143 (586)9, 253 (672)7,166 (754)7,835 2, 152 2, 241 2,449 2,450 2, 468 163 0 163 269 0 269 163 0 163 163 0 163 163 0 163 0~62 (62)0~62 (62)0~62)(62)0~62 (62)0~62)(62)2, 359 2, 342 2, 550 2, 551 2, 569 1,657 1,759 1,723 1,834 2,144 425 19.8 827 48.0 717 39.1 583 33.1 702 42.4 1980 1981 1982 2,185 2, 312 2,429 46 201 247 50 210 260 55 220 275 2, 572 2, 704 2,432 (160)0 (160)0 (160)0 (160)(160)(160)2,412 2, 544 2~272 10 432 11 275 11 792 357 11,632 320 12, 112 346 10,778 (586)10,192 (586)11,526 (586)11,046 3, 190 3, 074 3, 618 163 0 163 163 0 163 163 0 163 0~62)(62)0~62 (62)0~202)(202)3, 175 2~272 3, 291 2,412 3, 579 2, 544 1,035 40.7 879 36.4 903 39.7 ER-OL NEED FOR POWER 1983 13101 13581 14091 13180 13716 14091 (611)0 67210 69720 72500 2480 74980 0 70346 73125 74980 14622 15676 16106 0 0 0 32 0 32 14606 15644 16074 2594 19.2 1984 14621 14621 (870)0 (823)(611)(611)12357 13105 13480 (870)13751 75630 2254 77884 0 77884 16306 32 0 32 16274 2523 18.4 1985 1986 1987 15071 15551 16051 15071 15551 16051 (870)0 (870)0 (870)0 (870)(870)(870)14201 14681 15181 78160 80870 83480 2112 80272 0 1802 85282 0 2192 83062 0 80272 83062 85282 16727 17319 17948 16727 17319 17948 2638 18.0 2526 17.8 2767 18.2 1988 16515 16515 (870)0 (870)15645 86000 1355 87355 0 87355 18728 18728 3083 19.7 1989 1990 1991 17025 17509 18069 17025 17509 18069 (870)0 (870)(870)0 (870)(870)(870)16155 16639 17199 86610 91370 94210 1645 90255 0 1910 93280 0 1899 96109 0 90255 93280 96109 19148 19725 20274 19148 19725 20274 2993 18.5 3086 18.6 3075 17.9 1992 18639 18639 (870)0 (870)17769 971.00 2001 99101 0 99101 20933 20933 3164 17.8 Table 1.1-1 LOADS AND RESOURCES

SUMMARY

1964 THROUGH 1992 (Sheet 7 of 7)PRO APERTUpp CARD 1.1-27/28 Blank SOUTHERN CALIFORNIA EDISION COMPANY Year 1.1.1 Load characteristics, demand (MW)Company peak demand Firm sales outside PVNGS 1,2&3 Firm sales within PVNGS 1,2&3 Total firm sales (TFS)Annual peak demand (CPD+TFS)Firm purchases outside PVNGS 1,2&3 Firm purchases within PVNGS 1,2&3 Total firm purchases (TFP)Adjusted annual peak demand (APD-TFP-ID)1.1.1 Load characteristics, energy (GWh)Company energy Firm energy sales outside PVNGS 1,2&3 Annual Energy (CE-FES)Firm energy purchases outside PVNGS 1,2&3 Adjusted annaul energy (AE-FEP)1.1.2 Power supply (MW)Installed resources Nonfirm purchases outside PVNGS 1,2&3 Nonfirm purchases within PVNGS 1,2&3 Total nonfirm purchases Nonfirm sales outside PVNGS 1,2&3 Nonfirm sales within PVNGS 1,2&3 Total nonfirm sales Noncommitted Capability (IR+NFP-NFS) 1.1.3 Capacity requirement Reserve (C-AAPD)(MW)Percent margin (100xR/AAPD) (%)1964 5617 5617 5617 31529 612 32141 0 32141 6752 6752 1135 20.2 1965 6034 6034 6034 34499 420 34919 0 34919 7086 7086 1052 17.5 1968 1967 1966 7164 7707 6448 7164 7707 6448 (363)0 (363)7344 7164 6448 37821 40592 44088 675 41267 0 529 44617 0 511 38332 0 38332 41267 44617 9088 8046 8870 9088 8046 8870 1744 23.7 1706 23.8 1598 24.8 1969 8092 8092 (260)0 (260)7832 46953 772 47725 0 47725 97 24 9724 1892 24.2 1970 1972 1971 8556 9632 10132 35 150 35 150 185 185 9817 10317 8556 (376)0 (376)(376)0 (378)0 (378)(376)9441 9941 8178 49961 52840 55608 963 50924 0 1323 54163 0 1687 57295 0 50924 54163 57295 10639 11108 12344 0 0 10639 11108 12344 1667 17.6 2461 30.1 2403 24.2 1973 1974 1975 10535 10279 10369 10535 10279 10369 (517)0 (376)0 (611)0 (376)(517)(611)10159 9762 9758 57846 55113 55861 1944 59430 0 1492 56605 0 1152 57013 0 59430 56605 57013 13026 13134 13127 13026 13134 13127 2867 28.2 3372 34.6 3369 34.5 1976 11292 11292 (611)0 (611)10681 57916 1620 59536 0 59536 13247 13247 2566 24.0 1977 1978 1979 11564 12159 12361 258 32 0 258 32 11822 12159 12393 (611)0 (611)0 (611)0 (611)(611)(611)11211 11548 11782 60626 61560 62659 1626 63186 0 3 240 65899 0 4172 64798 0 64798 63186 65899 13798 14158 14375 15 0 16 0 15 16 13798 14143 14359 2595 22.5 2577 21.9 2587 23.1 1980 12361 40 0 40 12671 (611)0 (611)12060 64815 3125 67940 0 67940 14423 17 0 17 14486 2346 19.5 1981 79 0 79 (823)0 3136 70346 0 16 0 16 2249 18.2 1982 135 0 135 (611)0 3405 73125 0 32 0 32 2539 19.3 PVNGS ER-OL PVNGS PARTICIPANTS (1 of 8)YEAR: 1981 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total Energy NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 1 of 56)PVNGS PARTICIPANTS Page 1 of 8 1.1.1 Load characteristics, demand (MW)Company monthly peak demand Firm sales Monthly peak demand (PVNGS-1,2&3+FS) 18024 794 18818 17509 790 18299 17316 17549 19817 688 637 701 18004 18186 20518 22180 912 23092 23645 23998 23205 929 928 793 24574 24926 23998 19723 700 20423 13468 18858 738 742 19206 19600 Firm Purchases (a)67 65 74 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand (MPD-FP)1.1.1 Load characteristics, energy (GWh)Company monthly energy (a)Firm energy sales Firm energy purchases Monthly energy requirement (PVNGS-1,2&3+FES-FEP) 18751 9806 756 28 10534 18234 8741 692 29 9404 17930 18059 20370 9631 9392 9907 612 586 752 36 59 66 10207 9919 10593 22926 10556 788 77 11267 24408 14760 23832 859 868 780 88 82 71 12343 12564 11489 11572 11778 10780 20355 10252 737 28 10961 19143 19532 9491 9900 121806 732 775 8937 25 28 617 10198 10647 130126 PRg APppg~~CAPg (a)Sales and purchases to Companies other than the PVNGS-1, 2&3 participants. 1.1-29/30 Blank PVNGS ER-OL NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 2 of 56)PVNGS PARTICIPANTS Page 2 of 8 PVNGS PARTICIPANTS (2 of 8)YEAR: 1982 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total Energy 1.1.1 Load characteristics, demand (MW)Company monthly peak demand 18742 18215 18002 18257 20648 23111 24629 25001 24165 20530 19216 19625 Firm sales 805 801 799 742 809 1014 1031 1030 895 796 832 836 Monthly peak demand (PVNGS-1,2&3+FS) 19547 19016 18801 18999 21457 24125 25660 26031 25060 21326 20048 20461 Firm Purchases ()67 65 74 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand (MPD-FP)19480 18951 18727 18872 21309 23959 25494 25865 24894 21258 19985 20393 1.1.1 Load characteristics, energy (GWh)Company monthly energy Firm energy sales (a)Firm energy purchases Monthly energy requirement (PVNGS 1 f 2&3+FES PEP)800 744 28 29 11006 9827 10234 9112 10052 771 36 10787 9786 10343 11023 738 779 809 59 66 77 10465 11056 11755 12088 869 88 12869 898 842 798 82 71 28 13121 12024 11472 12305 11253 10702 9917 775 25 10667 803 9626 28 617 11114 136163 10339 127154 PRG APERTURE CARD (a)Sales and purchases to Companies other than the PVNGS-1, 2&3 participants. 1.1-31/32 Blank PVNGS ER-OL NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 3 of 56)PVNGS PARTICIPANTS Page 3 of 8 PVNGS PARTICIPANTS (3 of 8)YEAR: 1983 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total Energy 1.1.1 Load characteristics, demand (MW)Company monthly peak demand 19540 18978 18754 19019 21531 24124 25685 26074 25197 21408 20023 20456 Firm sales 706 702 700 644 714 745 762 761 745 644 678 682 Monthly peak demand (PVNGS-1,2&3+F8)20246 19680 19454 19663 22245 24869 26447 26835 25942 22052 20701 21138 (a)Firm Purchases 67 65 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand 20179 (MPD-FP)19615 19380 19536 22097 24703 26281 26669 25776 21984 20638 21070 1.1.1 Load characteristics, energy (GWh)Company monthly energy (a)Firm energy sales Firm energy purchases Monthly energy requirement (PVNGS-1,2&3+FES -FEP)10717 762 28 11451 9542 706 29 10219 692 36 626 59 624 66 11171 10809 11392 10515 10242 10834 11561 635 77 12119 674 88 701 82 640 71 13257 13527 12373 12671 12908 11804 11205 648 28 11825 630 25 657 28 7995 617 10980 11457 140580 10375 10828 133202 PRC APERTURE CARD (a)Sales and purchases to Companies other than the PVNGS-1, 2&3 participants. 1 1 33/34 Blank PVNGS ER-OL NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 4 of 56)PVNGS PARTICIPANTS Page 4 of 8 PVNGS PARTICIPANTS (4 of 8)YEAR: 1984 1.1.1 Load characteristics, demand (MW)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total Energy Company monthly peak demand Firm sales Monthly peak demand (PVNGS-1,2&3+FS) 20327 681 21008 19748 19514 19787 677 675 622 20425 20189 20409 22426 693 23119 25128 722 25850 26752 27155 26242 740 738 722 27492 27893 26964 22295 618 22913 909 914 21736 22183 20827 21269 Firm Purchases (a)65 74 128 148 166 166 166 166 68 63 68 Adjusted monthly peak demand (MPD-FP)1.1.1 Load characteristics, energy (GWh)Company monthly energy ()Firm energy sales Firm energy purchases Monthly energy requirement (PVNGS-1,2&3+FES-FEP) 20941 11214 667 28 11853 10161 10995 10703 589 631 607 29 36 59 10721 11590 11251 20360 20115 20281 22971 11329 593 66 11856 25684 12101 601 77 12625 27326 27727 26798 646 664 615 88 82 71 13828 14089 12890 13270 13507 12346 22845 11714 609 28 12295 21673 22115 583 25 644 28 7449 617 11400 11930 146328 10842 11314 139496 PRC APERTURE CARD (a)Sales and purchases to Companies other than the PVNGS-1, 2&3 participants. 1.1-35/36 Blank PVNGS ER-OL PVNGS PARTICIPANTS (5 of 8)NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 5 of 56)PVNGS PARTICIPANTS Page 5 of 8 YEAR: 1985 1.1.1 Load characteristics, demand (MW)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total Energy Company monthly peak demand 21103 20532 20253 20548 23313 26156 27814 28223 27278 23181 21620 22087 Firm sales 916 910 908 855 671 755 774 772 756 648 937 941 Monthly peak demand (PVNGS-1,2&3+FS) 22019 21442 21161 21403 23984 26911 28588 28995 28034 23829 22557 23028 Firm Purchases (a)67 65 74 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand (MPD-FP)1.1.1 Load characteristics, energy (GWh)Company monthly energy Firm energy sales (a)21952 21377 639 566 11705 10424 21542 21276 23836 601 589 558 11469 11169 11831 26745 12641 603 28422 28829 27868 667 679 608 13875 14134 12909 23761 12239 620 22494 22960 593 650 7373 11326 11813 145535 Firm energy purchases 28 29 36 59 66 77 88 82 71 28 25 28 617 Monthly energy requirement (PVNGS-1,2&3+FES-FEP) 12316 10961 12034 11699 12323 13167 14454 14731 13446 (a)sales and purchases to companies other than the PvNGs-l, 2&3 participants. 12831 11894 12435 152291 PRC--APEpyg~~CAPg 1.1-37/38 Blank PVNGS ER-OL PVNGS PARTICIPANTS (6 of 8)YEAR: 1986 1.1.1 Load characteristics, demand (MW)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total Energy NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 6 of 56)PVNGS PARTICIPANTS Page 6 of 8 Company monthly peak demand Firm sales Monthly peak demand (PVNGS-1,2&3+FS) 21873 942 22815 21299 21025 937 935 22236 21960 21309 884 22193 24185 27151 28863 703 788 808 24888 27939 29671 29279 806 30085 788 676 963 29095 24741 23379 28307 24065 22416 22894 968 23862 Firm Purchases (a)67 65 74 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand (MPD-FP)22748 22171 21886 22066 24740 27773 29505 29919 28929 24673 23316 23794 1.1.1 Load characteristics, energy (GWh)Company monthly energy Firm energy sales (a)Firm energy purchases Monthly energy requirement (PVNGS-1,2&3+FES-FEP) 12183 662 28 12817 595 633 29 36 11414 12526 10848 11929 11624 606 59 12171 583 66 637 77 694 88 12828 13730 15058 12311 13170 14452 14729 708 82 15355 13455 12743 11788 648 641 617 71 28 25 14032 13356 12380 12290 673 28 12935 151522 7697 617 158602 PRC APERTURE)CARD (a)Sales and purchases to Companies other than the PVNGS-1, 2&3 participants. 1.1-39/40 Blank PVNGS ER-OL NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 7 of 56)PVNGS PARTICIPANTS Page 7 of 8 PVNGS PARTICIPANTS (7 of 8)YEAR.19 87 1.1.1 Load characteristics, demand (MW)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total Energy Firm sales 969 Monthly peak demand (PVNGS-1,2&3+FS) 23604 Company monthly peak demand 22635 21985 965 22950 962 913 734 22719 22957 25798 21757 22044 25064 28192 825 29017 29947 30372 29366 846 844 826 30793 31216 30192 24969 710 25679 23232 23695 1622 1627 24854 25322 Firm Purchases (a)67 65 74 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand (MPD-FP)23537 22885 22645 22830 25650 28851 30627 31050 30026 25611 24791 25254 1.1.1 Load characteristics, energy (GWh)Company monthly energy (a)Firm energy sales Firm energy purchases Monthly energy requirement (PVNGS-1,2&3+FES-FEP) 12663 708 28 13343 11260 644 29 11875 12433 12066 12797 669 649 611 36 66 13066 12656 13342 13708 674 77 14305 725 643 567 88 82 71 15690 15894 14503 15053 15333 14007 13257 551 28 13780 12263 12826 157666 7575 617 529 25 12767 13403 16462,4 605 28 P R C'-':-'PERTURE CARD (a)Sales and purchases to Companies other than the PVNGS-1, 2 a 3 participants. 1.1-41/42 Blank PVNGS ER-OL PVNGS PARTICIPANTS (8 of 8)NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 8 of 56)PVNGS PARTICIPANTS Page 8 of 8 YEAR: 1988 1.1.1 Load characteristics, demand (MW)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total Energy Company monthly peak demand Firm sales Monthly peak demand (PVNGS-1,2&3+FS) 23429 1625 25057 22755 22474 22781 1624 1621 1666 24379 24095 24447 25918 767 26685 29168 862 30030 30977 31408 30409 884 882 863 31861 32290 31272 25826 743 26569 24006 24518 1651 1657 25657 26175 Firm Purchases (a)67 65 74 127 148 166 166 166 166 65 68 Adjusted monthly peak demand (MPD-FP)1.1.1 Load characteristacs, energy (GWh)Company monthly energy (a)Firm energy sales 24990 13150 631 11877 12846 12488 565 596 598 24314 24021 24320 26537 13253 562 29864 14220 625 15618 15910 14537 676 703 607 31695 32124 31106 26501 13735 620 25594 26107 588 648 7419 12700 13257 163591 Firm energy purchases 28 29 36 59 66 77 88 82 71 28 25 28 617 Monthly energy requirement (PVNGS-1,2&3+FES-FEP) 13753 12413 13406 13027 13749 14768 16206 16531 15073 (a)Sales and purchases to Companies other than the PVNGS-1, 2&3 participants. 14327 13263 13877 170393 PRC APERTURE CARD 1.1-43/44 Blank PVNGS ER-OL SALT RIVER PROJECT Year 1986 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total Energy NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 46 of 56)l.l.1 Load characteristics, demand (MW)Company peak demand (a)1,776 1,716 1,710 1,813 2,461 2,849 2,909 2,855 2,775 2, 170 1,710 1,824 SALT RIVER PROJECT Page 6 of 8 Firm sales outside PVNGS 1,2&3 Firm sales within PVNGS 1,2&3 Total firm sales (TFS)60 251 311 60 251 311 251 311 60 251 311 60 251 311 60 260 320 60 260 320 60 260 320 60 260 320 60 260 320 60 260 320 60 260 320 Monthly peak demand (CPD+TFS)Firm purchases outside PVNGS 1,2&3 Firm purchases within PVNGS 1,2&3 Total firm purchases (TFP)Ad3usted monthly peak demand (MPD-TFP-ID) 2,087 2,027 (63)(62)(63)(62)2,024 1,965 2,021 (71)(71)1,950 2,124 2,772 3,169 (123)(143)(160)(123)(143)(160)2,001 2,629 3,009 3,229 (160)(160)3,069 3,175 3,095 2,490 (160)(160)(64)0 0 (160)(160)(64)3,015 2,935',426 2,030 2,144 (59)(64)(59)(64)1,971 2,080 l.l.1 Load characteristics, energy (GWh)Company monthly energy (includes interruptible energy)1,170 1,007 1,006 960 1,051 1,285 1,510 1 603 1 600 I 1 322 1,027 1,004 14,545 Firm energy sales outside PVNGS 1,2&3 Firm energy purchases outside PVNGS 1,2&3 35 33 (26)(27)37 (34)20 26 28 (57)(63)(74)34 (84)20 (78)(68)(26)Monthly energy requirement (CME+FES-FEP) 1,179 1,013 1, 009 923 1,014 1,239 1,460 1,559 1,558 1,316 (a)Interruptible demand is not included in the peak load forecast, and no generation is planned to supply interruptible demand.16 27 336 (23)(26)(586)1,020 1,005 14,295 PRC APERTURE CARD 1.1-119/120 Blank PVNGS ER-OL SALT RIVER PROJECT NEED FOR POWER Year 1987 1.1.1 Load characteristics, demand (MW)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total Energy Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 47 of 56)SALT RIVER PROJECT Company peak demand (a)1,845 1,729 1,777 1,884 2,558 2,962 3,024 2,968 2,884 2,255 1,777 1,895 Page 7 of 8 Firm sales outside PVNGS 1,2&3 Firm sales within PVNGS 1,2&3 Total firm sales (TFS)60 260 320 60 260 320 60 260 320 60 260 320 60 260 320 60 271 331 60 271 331 60 271 331 60 271 331 60 271 331 60 271 331 60 271 331 Monthly peak demand (CPD+TFS)2,165 2,049 2,097 2,204 2,878 3,293 3.355 3,299 3,215 2,586 2,108 2,226 Firm purchases outside PVNGS 1,2&3 Firm purchases within PVNGS 1,2&3 Total firm purchases (TFP)Adjusted monthly peak demand (MPD-TFP-ID) l.1.1 Load characteristics, energy (GWh)Company monthly energy (includes interruptible energy)(63)(62)(63)(62)2,102 1,987 1,232 1,060 (71)(71)2,026 1,059 (123)(143)(160)(123)(143)(160)2,081 2,735 3,133 1,009 1,106 1,350 (160)(160)3,195 1, 589 (160)(160)(160)(160)3,139 3,055 1,687 1,683 (64)(64)2.522 1,393 (59)(64)(59)(64)2,049 2,162 1,082 1,057 15,307 Firm energy sales outside PVNGS 1,2&3 Firm energy purchases outside PVNGS 1,2&3 35 33 (26)(27)37 (34)20 26 28 (57)(63)(74)34 (84)34 26 (78)(68)Monthly energy requirement (CME+FES-FEP) 1,441 1,066 1,062 972 1,069 1,304 1,539 1,643 1,641 (a)Interruptible demand is not included in the peak load forecast, and no generation is planned to supply interruptible demand.20 (26)1,387 16 27 336 (23)(26)(586)1,075 1,058 15,057 PRC APERTURE..CARD 1.1-121/122 Blank PVNGS ER-OL ARIZONA-NEW MEXICO&SOUTHERN CALIFORNIA -NEVADA Year 1.1.1 Load Characteristics, demand (MW)(AZ-NM)system peak demand (SoCA-NV)system peak demand Combined system peak demand Firm sales outside combined system Combined system annual peak demand Firm purchases outside combined system Combined system interruptible demand Combined system adjusted annual peak demand 1.1.1 Load characteristics, energy (GWh)(AZ-NN)system annual energy (SoCA-NV)system annual energy Combined system annual energy Firm energy sales outside combined system Firm energy purchases outside combined system Combined system interruptible energy Combined system annual energy requirement 1.1.1 Power supply (MW)(AZ-NN)system installed resources (SoCA-NV)system installed resources Combined system installed resources Nonfirm sales outside combined system Nonfirm purchases outside combined system Combined system maintenance and force outage Combined system capability 1.1.1 Capacity requirement Reserve (MW)Percent margin (%)1972 5,590 16,807 22,397 0 22,397 2,084 0 20,313 27,252 90,841 118,093 (b)(b)(b)6, 678 18,635 25,313 (b)(b)1,868 23,445 3 132 15.4 1973 6,104 17,201 23,305 0 23,305 2,214 0 21,091 30,082 94,214 124,296 (b)(b)(b)7,170 19,764 26,934 (b)(b)3,569 23,365 2,274 10.8 1974 6,502 16,817 23,319 0 23,319 2,471 0 20,848 31,878 90,394 122,272 (b)(b)(b)8,365 20,259 28,624 (b)(b)3,480 25,144 4,296 20.6 1975 6,565 17,009 23,574 0 23,574 2,316 0 21,198 30,082 91,025 121,107 (b)(b)(b)9,922 20,954 30,876 (b)(b)2,954 27,922 6,724 31.7 1976 6,958 18,580 25,538 0 25, 538 2,311 11 23,216 34, 034 95,716 129,750 753 2,985 148 127,370 10,685 21,151 31,836 (b)(b)4, 058 27,778 4, 562 19.7 1977 7,110 18,815 25,925 605 26,530 2, 349 28 24,153 35,787 96,666 132,453 9, 599 8, 716 233 133, 103 11, 027 22, 197 33, 224 (b)(b)3, 288 29,936 5, 783 23.9 1978 7,383 20,150 27,533 148 27,681 2,537 42 25,102 37,387 102,317 139,704 2, 993 18, 025 258 124,414 9, 605 24,771 34,376 (b)(b)6, 266 28,110 3,008 12.0 1979 8, 329 20, 807 29,136 316 29,452 2,593 129 27,730 40,973 103,347 144,320 4, 934 3,541 290 145,423 10, 284 25, 638 35,922 (b)(b)378 35, 544 7,814 28.2.1980 8,948 21,463 30,411 197 30,608 2,762 179 27,667 44,973 103,969 148,942 4, 590 6, 282 326 146,920 11, 607 25,760 37,367 (b)(b)534 36,833 9, 166 33.1 1981 9, 569 22,350 31,919 25 31,944 2,963 183 28,798 49,211 110, 660 159,871 4,327 6,959 414 156,825 11,854 26,104 37,958 (b)(b)507 37,451 8, 653 30.0 1982 10, 200 23, 265 33,465 28 33,493 2,623 187 30, 683 52,989 115,047 168,036 4, 450 5, 874 414 166,198 13,386 27,447 40,833 (b)(b)329 40, 504 9,821 32.0 1983 10,803 23,810 34,613 31 33, 644 2, 312 191 32,141 56, 606 118,304 174,910 4, 085 5, 579 414 173,002 13,528 28,405 41,933 (b)(b)353 41, 580 9,439 29.4 1984 11,421 24,749 36,170 35 36, 205 2, 347 195 33,663 60, 204 122, 977 183,181 3,919 5, 395 414 181, 291 14,780 29,182 43,962 (b)(b)199 43,763 10, 100 30.0 1985 12,267 25,631 37,898 38 37,936 2,365 465 35,106 64,570 127, 383 191,953 3, 927 5, 559 1,300 189, 021 15,562 29,627 45,189 (b)(b)178 45, 011 9, 905 28.2 1986 12, 921 26,543 39,464 358 39,822 1,878 569 37,375 68,439 132,220 200,659 4,399 5,573 1,987 197,498 16,680 30,739 47,419 (b)(b)427 46,992 9,617 25.7 1987 13,650 27,521 41,171 927 42, 098 1,231 713 40, 146 72,675 316,963 209,638 5, 979 5, 592 2, 730 207, 295 17,149 32,320 49,469 (b)(b)532 48,937 8,791 21.9 1988 14,262 28,450 42,712 1,496 44,208 1,184 718 42, 306 76, 377 141,910 218,287 8, 267 5, 644 2, 730 218,180 18,210 33,790 52,000 784 51,216 8,910 21.1 NEED FOR POWER Table 1.1-3 LOAD AND RESOURCES

SUMMARY

COMBINED ARIZONA-NEW MEXICO (AZ-NM)AND SOUTHERN CALIFORNIA-NEVADA (SoCA-NV)SYSTEMS AS REPORTED TO THE WSCC (a)(1972 THROUGH 1987)PRC APERTURE CARD a.Western Systems Coordinating Council Summary of Estimated Loads and Resources-1972 Report, 1973 Report, 1974 Report, 1975 Report, 1976 Report, 1977 Report, and 1978 Report.b.Data not available. 1.1-141/142 Blank/r ARIZONA-NEW MEXICO&SOUTHERN CALIFORNIA -NEVA Year: 1982 1.1.1 Load characteristic, demand (MW)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec PVNGS ER-OL NEED FOR POWER Table 1.1-4 LOADS

SUMMARY

BY MONTH COMBINED ARIZONA-NEW MEXICO (AZ-NM)AND SOUTHERN CALIFORNIA-NEVADA (SoCA-NV)SYSTEMS AS REPORTED TO THE WSCC (AZ-NM)system peak demand (SoCA-NV)system peak demand Combined system peak demand Firm sales outside combined system Combined system monthly peak demand Firm purchases outside combined system Combined system interruptible demand 6, 923 18,263 25,186 125 25,311 2,455 177 6, 671 17,750 24, 421 125 24,546 2,407 177 6, 726 17,397 24,123 125 24,248 2,415 177 7,248 17,116 24, 364 28 24,392 2, 471 177 8,707 18,916 27, 623 28 27,651 2,631 177 9, 975 20,960 30,935 28 30, 963 2, 683 187 10,221 22,684 32, 905 28 32,933 2,675 187 10, 200 23, 265 33, 465 28 33,493 2,623 187 9, 869 22,374 32, 243 28 32, 271 2, 592 187 8, 023 19,354 27 377 28 27,405 2, 375 187 6, 980 18,937 25,917 128 26, 045 2, 321 177 7,300 19,294 26, 594 128 26,722 2, 390 177 1982 THROUGH 1987 Sheet 1 of 3 Combined system adjusted monthly peak demand 22, 679 21,962 21,656 21, 744 24,843 28, 093 30, 071 30,683 29,492 24,843 23,547 24,155 Year: 1983 1.1.1 Load characteristic, demand (MW)(AZ-NM)system peak demand (SoCA-NV)system peak demand Combined system peak demand Firm sales outside combined system Combined system monthly peak demand Firm purchases outside combined system Combined system interruptible demand Combined system adjusted monthly peak demand 7~377 18, 732 26,109 128 26,237 2,438 181 23, 618 7, 110 18,194 25,304 128 25,432 2,422 181 22, 829 7,164 17,833 24,997 128 25,125 2, 398 181 22, 546 7,707 17,519 25, 226 31 25, 257 2, 159 181 22,917 9, 253 19,317 28,570 31 28,601 2,315 181 26,105 10,599 21,370 31,969 31 32, 000 2, 304 191 29,505 10, 835 23,148 33,973 31 34,004 2, 345 191 31,468 10,803 23,810 34,613 31 34,644 2, 312 191 32,141 10, 450 22,894 33,344 31 33,375 2,318 191 30,866 8,500 19,731 28,231 31 28, 262 2, 128 191 25,943 7, 403 19,339 26,742 131 26,873 2, 123 181 24,569 7, 741 19,647 27,388 131 27,519 2,156 181 25,182 PRC APERTURE CARD 1.1-143/144 Blank PVNGS ER-OL ARIZONA-NEW MEXICO&SOUTHERN CALIFORNIA NEVADA Jan Year: 1984 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec NEED FOR POWER Table 1.1-4 LOADS

SUMMARY

BY MONTH COMBINED ARIZONA-NEW MEXICO (AZ-NM)AND SOUTHERN CALIFORNIA-NEVADA (SoCA-NV)1.1.1 Load characteristic, demand (MW)(AZ-NM)system peak demand (SoCA-NV)system peak demand Combined system peak demand Firm sales outside combined system Combined system monthly peak demand Firm purchases outside combined system Combined system interruptible demand Combined system adjusted monthly peak demand 7,780 19,387 27,167 131 27,298 2,101 185 25, 012 7,494 18,836 26,330 131 26,461 2,119 185 24,157 7, 552 18,445 25,997 131 26, 128 2, 056 185 23,887 8,121 18,137 26,258 35 26, 293 2, 140 185 23,968 9, 746 20,207 29,953 35 29,988 2,406 185 27,397 11,204 22,290 33,494 35 33,529 2,394 195 30,940 11,444 24,107 35,551 35 35, 586 2,396 195 32, 995 11,421 24,749 36,170 35 36,205 2,347 195 33,663 11,045 23,800 34,845 35 34,880 2,330 195 32,355 8, 995 20, 492 29, 487 35 29, 522 2, 103 195 27,224 7, 845 20, 148 27,993 135 28,128 2,129 185 25,814 8, 219 20,408 28, 627 135 28,762 2,103 185 26,474 SYSTEMS AS REPORTED TO THE WSCC 1982 THROUGH 1987 Sheet 2 of 3 Year: 1985 1.1.1 Load characteristic, demand (MW)(AZ-NM)system peak demand (SoCA-NV)system peak demand Combined system peak demand Firm sales outside combined system Combined system monthly peak demand Firm purchases outside combined system Combined system interruptible demand Combined system adjusted monthly peak demand 8, 326 20,070 28,396 135 28,531 2,102 277 26, 152 8,083 19,485 27,568 135 27,703 2, 077 339 25, 287 8, 238 19,085 27 323 135 27,458 2,061 439 24,958 8,842 18,762 27,604 38 27,642 2,111 449 25,082 10,541 20, 881 31,422 38 31,460 2,398 451 28,611 12, 040 23,065 35,105 38 35,143 2,411 465 32, 267 12, 294 24,911 37,205 38 37, 243 2, 341 465 34,437 12, 267 25, 631 37,898 38 37,936 2,365 465 35,106 11, 854 24,575 36,429 38 36,467 2, 362 445 33,660 9, 637 21, 248 30,885 38 30, 923 2, 097 375 28,451 8, 362 20,775 29,137 38 29,175 2,118 289 26,768 8, 738 21, 045 29, 783 38 29, 821 2, 110 279 27,432 PRG APERTURP CARD 1,1-145/146 Blank ARIZONA-NEW MEXICO&SOUTHERN CALIFORNIA -NEVADA PVNGS ER-OL NEED FOR POWER Year: 1986 1.1.1 Load characteristic, demand (MW)(AZ-NM)system peak demand (SoCA-NV)system peak demand Combined system peak demand Firm sales outside combined system Combined system monthly peak demand Firm purchases outside combined system Combined system interruptible demand Combined system adjusted monthly peak demand Jan 8,744 20,724 29,468 138 29,606 2,090 313 27, 203 Feb 8,492 20,101 28,593 138 28,731 2,020 383 26, 328 Mar 8, 638 19,701 28,339 138 28, 477 1, 984 473 26, 020 Apr 9,260 19,386 28,646 42 28,688 2I 132 473 26, 083 May 11, 094 21,621 32,715 42 32,757 2,385 538 29, 834 Jun 12, 678 23,973 36,651 42 36, 693 2, 404 565 33, 724 Jul 12,949 25,804 38,753 358 39,111 2, 388 569 36, 154 Aug 12,921 26,543 39,464 358 39,822 1,878 569 37, 375 Sep 12,460 25,490 37,950 358 38,308 1,840 523 35, 945 Oct 10, 107 22, 020 32, 127 358 32,485 1,620 413 30, 452 Nov 8,764 21,481 30,245 458 30, 703 1,644 308 28, 751 Dec 9, 163 21,822 30,985 458 31,443 1,611 303 29, 529 Table 1.1-4 LOADS

SUMMARY

BY MONTH COMBINED ARIZONA-NEW MEXICO (AZ-NM)AND SOUTHERN CALIFORNIA-NEVADA (SoCA-NV)SYSTEMS AS REPORTED TO THE WSCC 1982 THROUGH 1987 Sheet 3 of 3 Year: 1987 1.1.1 Load characteristic, demand (MW)(AZ-NM)system peak demand (SoCA-NV)system peak demand Combined system peak demand Firm sales outside combined system Combined system monthly peak demand Firm purchases outside combined system Combined system interruptible demand Combined system adjusted monthly peak demand 9,330 21,481 30,811 458 31,269 1,555 489 29,225 9, 052 20,724 29,776 458 30,234 1,404 549 28,281 9, 258 20,412 29, 670 458 30,128 1,470 698 27,960 9, 902 20,080 29,982 362 30,344 1,583 698 28,063 11,759 22,391 34,150 362 34,512 1,816 703 31,993 13,400 24,812 38,212 362 38,574 1, 792 713 36,069 13,677 26,712 40,389 677 41,066 1,801 713 38,552 13,650 27,521 41, 171 677 41,848 1, 239 713 39,896 13, 105 26,411 39,516 677 40,193 1,215 603 38,375 10, 672 22,807 33,479 677 34, 156 980 515 32,661 9, 327 22, 336 31, 663 777 32, 440 1, 031 461 30,948 9, 760 22,520 32, 280 777 33,057 990 472 31,595 PRC APERTURE CARD 1.1-147/148 Blank PVNGS ER-OL Month 1972 1973 Change (%)1974 PVNGS-1, 2 F 3 PARTICIPANTS Change (5)1975 Change (%)1976 MONTHLY PEAK DEMAND (MW)Change (g)1977 Change (){)1978 Change (I)NEED FOR POWER Table 1.1-7 COMPARISON OF MONTHLY PEAK DEMANDS Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 13457 13097 12826 13406 15130 15873 17468 17368 15992 14942 13957 15104 14558 13910 13918 14094 15941 18312 17806 17495 16735 15472 14509 13806 8.2 6.2 8.5 5.1 5.4 15.4 1.9 0.7 4.6 3.5 4.0-8.6 13607 12566 12553 13464 14409 17875 18227 17319'7852'6033 13853 14252-6.5-9.7-9.8-4 5-9.6-2.4 2.4-1.0 6.7 3.6-4.5 3.2 14478 13786 13348 13319 14898 15903 18192 18586 18398 16205 14315 14749 6.4 9.7 6.3-1.1 3.4-11.0-0.2 7.3 3.1 1.1 3.3 3.5 14431 14433 14527 14483 17038 19990 19480 19895 18795 16051 15849 15394-0.3 4.7 8.8 8.8 14.4 25.7 7.1 7.0 2.2-1.0 10.7 4.4 15503 14786 14695 14973 16709 18307 20346 20186 20405 16251 15191 15594 7.4 2.4 1.2 3.4-1.9-8.4 4.4 1.5 8.6 1.2-4.2 1.3 15664 15262 14700 14764 18076 20084 21243 20690 21588 18216 15950 17162 1.0 3.2 0.0-l.4 8.2 9.7 4.4 2.5.8 12.1 5.0 10.1 AND ENERGY REQUIREMENTS 1972 THROUGH 1978 (Sheet 1 of 7)MONTHLY ENERGY REQUIREMENTS (GWH)Month 1972 1973 Change (g)1974 Change ()l)1975 Change (%)1976 Change{)()1977 Change ()l)1978 Change (5)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 7242.8 6719.5 7306.4 7017.8 7633.3 7944.1 8774.2 8814.8 7861.9 7564.0 7270.3 7780.0 7855.9 6910.7 7688.4 7359.2 8078.3 8564.8 9045.4 9212.7 8098.3 8086.8 7512.2 7292.1 8.5+2.8 5.2 4.9 5.8 7.8 3.1 4.5 3.0 6.9 3.3-6.3 7286.9 6487.3 7115.6 7003.7 7680.2 8347.6 8992.2 8835.4 8398.7 7838.2 7163.1 7644.7-7.2-6.1-7.5-4.8-4.9-2.5-0.6-4.1 3.7-3.1-4.6 4.8 7757.7 6906.0 7500.7 7347.5 7702.4 7974.8 8990.6 8942.1 8484.5 7953.5 7403.5 7869.5 6.5 6.5 5.4 4.9 0.3-4.5-0.0 1.2 1.0 1.5 3.4 2.9 7918.4 7299.4 7996.8 7682.6 8252.7 8931.2 9545.9 9378.3 8548.4 8240.2 7834.7 8264.6 2.1 5.7 6.6 4.6 7.1 12.0 6.2 4.9 0.8 3.6 5.8 5.0 8263.9 7351.4 8334.6 7998.0 8208.6 9060.8 9827.4 10263.3 8982.0 8489.6 7950.9 8296.6 4.4 0.7 4.2 4.1-0.5 1.5 2.9 9.4 5.1 3.0 1.5 0.4 8375.5 7501.5 8210.1 7943.6 8794.6 9654.1 10378.3 10289.8 9505.4 9154.6 8443.2 8982.7 l.4 2.0-1.5-0.7 7.1 6.5 5.6 0.3 5.8 7.8 6.2 8.3 PRC APERTURE CARD 1.1-151/152 Blank PVNGS ER-OL NEED FOR POWER Month 1972 1973 Change (/)ARIZONA PUBLIC SERVICE COMPANY 1974 Change (/o)1975 Change (/)1976 Change (/)Monthly Peak Demand (MW)1977 Change (/)1978 Change (/)Table 1.1-7 COMPARISON OF MONTHLY PEAK DEMANDS AND ENERGY REQUIREMENTS Sheet 2 of 7 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 944 928 1002 1053 1301 1514 1633 1659 1549 1283 963 1087 1052 1037 1028 1211 1554 1786 1809 1813 1728 1432 1127 1065 11.4 11.7 2.6 15.0 19.4 18.0 10.8 9.3 11.6 11.6 17.0-2.0 1099 1068 1149 1302 1601 2032 1936 1873 2008 1683 1112 1236 4.5 3.0 11.8 7.5 3.0 13.8 7.0 3.3 16.2 17.5-1.3 16.1 1264 1147 1174 1144 1563 1790 2008 2068 1903 1646 1244 1232 15.0 7.4 2.2-12.1-2.4-11.9 3.7 10.4-5.2-2.2 11.9-0.3 1304 1295 1354 1449 1758 2114 2191 2121 2070 1466 1399 1354 3.2 12.9 15.3 26.7 12.5 18.1 9.1 2.6 8.9-10.9 12.5 9.9 1397 1361 1373 1651 1955 2286 2346 2373 2372 1775 1360 1430 7.1 5.1 1.4 13.9 11.2 8.1 7.1 11.9 14.6 21.1-2.8 5.6 1531 1490 1370 1533 2020 2356 2549 2373 2359 2015 1480 1726 9.6 9.5-0.2-7.1 3.3 3.1 8.7-0.4-0.5 13.5 8.8 20.7 Monthly Energy Requirements (GWh)Month Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1972 499.9 477.4 521.1 502.0 595.7 692.4 829.4 786.2 679.8 549.8 498.5 566.9 1973 572.9 496.0 559.1 546.6 692.7 797.2 910.4 944.0 752.7 667.7 579.0 581.4 Change (/)14.6 3.9 7.3 8.9 16.3 15.1 9.8 20.1 10.7 21.4 16.1 2.6 1974 584.4 536.9 604.5 602.5 714.0 919.6 951.3 949.6 856.5 713.5 585.7 673.8 Change (/)2.0 8.2 8.1 10.2 3.1 15.4 4.5 0.6 13.8 6.9 1.2 15.9 1975 680.8 596.2 651.8 619.9 700.4 798.9 985.0 983.3 867.5 701.9 630.9 676.0 Change (/o)16.5 11.0 7.8 2.9-1.9-13.1 3.5 3.5 1.3-1.6 7.7 0.3 1976 697.7 632.9 710.1 673.4 792.1 925.6 1063.9 1068.4 882.1 728.5 680.6 751.4 Change (/)2.5 6.2 8.9 8.6 13.1 15.9 8.0 8.7 1.7 3.8 7.9 11.2 1977 753.9 680.8 773.4 766.0 791.4 1051.7 1184.3 1215.5 995.7 796.6 718.4 754.1 Change (/)8.1 7.6 8.9 13.8-0.1 13.6 11.3 13.8 12.9 9.3 5.6 0.4 1978 776.1 687.7 740.4 745.6 881.8 1099.0 1250.3 1189.4 1035.2 873.6 764.0 869.5 Change (/)2.9 1.0-4.3-2.7 11.4 4.5 5.6-2.1 4.0 9.7 6.3 15.3 PRC APERTURE CARD 1.1-153/154 Blank PVNGS ER-OL LOS ANGELES DEPARTMENT OF WATER AND POWER Monthly Peak Demand (MW)NEED FOR POWER Table 1.1-7 COMPARISON OF MONTHLY PEAK DEMANDS Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2899 2799 2800 2776 3215 3249 3630 3565 3294 3155 3021 3174 Month 1972 1973 3097 2914 2968 2823 3165 3679 3561 3492 3293 3141 3014 2827 Change (%)6.8 4.1 6.0 1.7-1.6 13.2-1.9-2.0 0-0.4-0.2-10.9 1974 2586 2356 2381 2543 2539 3292 3500 3259 3304 3095 2681 2727 Change (%)-16.5-19.1-19.8-10.2-19.8-10.5-1.7-6.7 0.3-1.5-11.0-3.5 1975 2755 2658 2634 2636 2826 2930 3466 3531 3594 3231 2781 2903 Change (%)6.5 12.8 10.6 3.6 11.3-11.0-0.8 8.3 8.8 4.4 3.7 6.4 1976 2790 2806 2758 2783 3264 3809 3634 3744 3597 3232 3168 2928 Change (%)1.3 5.6 4,7 5.6 15.5 30.0 4.8 6.0 0.1 0 13.9 0.9 1977 2961 2798 2707 2677 2974 3189 3778 3700 3769 3012 3064 3000 Change (%)6.1-0.3-1.8-3.8-8.9-16.3 4.0-1.2 4.8-6.8-3,3 2.4 1978 2998 2910 2826 2767 3398 3680 3912 3814 4144 3422 2949 3044 Change (%)1.2 4.0 4.4 3.4 14.2 15.4 3.5 3.1 9.9 13.6-3.8 1.5 AND ENERGY REQUIREMENTS Sheet 3 of 7 Monthly Energy Requirements (GWh)Month 1972 1973 Change (%)1974 Change (%)1975 Change (%)1976 Change (%)1977 Change (%)1978 Change (%)Jan Feb Mar Apr May Jun Ju 1 Aug Sep Oct Nov Dec 1530 1413 1532 1449 1562 1592 1723 1757 1559 1552 1519 1612 1621 1439 1590 1483 1562 1642 1696 1734 1540 1624 1521 1427 5.9 1.8 3.8 2.3 0 3.1-l.6-1.3-1.2 4.6 0.1-11.5 1343 1189 1323 1281 1355 1442 1622 1554 1506 1457 1348 1424-17.1-17.4-16.8-13.6-13.2-12.2-4.4-10.4-2.2-10.3-11.5-0.2 1438 1302 1429 1407 1442 1429 1611 1563 1555 1519 1429 1528 7.1 9.5 8.0 9.8 6.4-0.9 0.7 0.6 3.2 4.2 6.0 7.3 1531 1424 1526 1470 1532 1643 1714 1680 1617 1609 1500 1554 6.5 9.3 6.8 4.5 6.2 15.0 6.4 7.5 4.0 5.9 5.0 1.8 1549 1363 1534 1438 1469 1527 1687 1761 1567 1556 1486 1560 1.2-4.3 0.5-2.2-4.1-7.1-l.6 4.8-3.1-3.3-0.9 0.4 1574 1422 1554 1499 1624 1693 1784 1764 1735 1681 1534 1598 1.6 4.3 1.3 4.2 10.6 10.9 5.7 0.2 10.7 8.0 3.2 2.4 PRC PARTURE CARD 1.1-155/156 Blank PVNGS ER-OL EL PASO Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 426 418 417 431 466 513 538 543 501 498 447 472 Month 1972 462 471 455 458 526 618 607 586 585 525 485 466 8.5 12.7 9.1 6.3 12.9 20.5 12.9 7.9 16.8 5.4 8.5 (1.3)1973 Change (8)Monthly Peak Demand (MW)1974 Change (%)1975 Change (%)1976 Change (%)457 448 438 504 587 638 635 629 600 518 478 505 (1.1)(5.1)(3-9)10.1 11.6 5.1 4.6 7.3 2.6 (1.4)(1.5)8.4 492 466 471 480 550 630 635 640 615 520 490 506 7.7 4.0 7.5 (5.0)(6.7)(1.3)0 1.8 2.5.4-2.5.-2 495 489 486 520 590 677 637 666 595 504 537 529.6 4.9 3.2 8.3 7.3, 7.5.3 4.1 (3-3)(3-2)9.6 4.5 Monthly Energy Requirements (GWh)486 473 468 497 601 655 636 657 622 527 490 502 (1.9)(3-4)(3.8)(4.6)1.9 (3.3)(-2)(1.4)4.5 4.6 (9-6)(5-4)1977 Change (%)513 492 510 546 614 688 690 651 617 527 509 549 5.6 4.0 9.0-9.9 2.2 5;0 8.5 (-9)-'-8);0 3.9 9.4 1978 Change (%)NEED FOR POWER Table 1.1-7 COMPARISON OF MONTHLY PEAK DEMANDS AND ENERGY REQUIREMENTS Sheet 4 of 7 Month 1972 1973 Change (8)1974 Change (%)1975 Change (%)1976 Change (%)1977 Change (0)1978 Change (%)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 226.4 215.5 229.4 225.2 245.6 259.6 288.2 282.0 251.6 252.7 239.2 248.0 257.5 233.0 253.2 247.7 271.0 297.6 316.4 322-7 296.5 273.7 257.6 255.9 13.7 8.1 12.4 10 10.3 14.6 9.8 14.4 17.9 8.3 7.7 3.2 258.5 231.9 246.6 251.4 295.1 324.5 323.5 321.6 285.5 274.3 259.0 278.4.4 (-5)(2.7)1.5 8.9 9.4 2.2 (-3)(3.7).2.5 8.8 278.0 242.5 259.5 258.0 280.1 321.9 336.6 344.8 299.2 281.6 264.1 278.4 7.5 4.6 5.2 2.6 (5-4)(.8)4.1 7.2 4.8 2.7 2.0 0 281.8-259.6 276.4 273.8 295.6 340.0 341.5'59.3 298.1 277.0 271.7 277.8 1.4 7.1 6.5 6.l.5.5 5.6 1.5 4.2 (-4)(1;7)2.9 (-2)273.0 241.0 269.0 262.0 289.0 330.0 329.0 353.0 320.0 274.0 262.0 271.0 (3.2)(7-7)(2-8)(4.5)(2-3)(2-9), (3.7)(1.8)7.4'l.l)(3.7)(2.5)278.3 250.0 274.0 275.0 305.0 349.0 369.0 345.0 290.0 286.0 269.0 291.0 1.9 3.7 1.9 5.0 5.5 5.8 (2.3)., (9.4): 4.4 2.7 7.4 PR(;APERTURE CAR'0...-l.1-157/158 Blank

lii Il lI II V t.C G~

PVNGS ER-OL PUBLIC SERVICE COMPANY OF NEW MEXICO Monthly Peak Demand (MW)NEED FOR POWER Table 1.1-7 COMPARISON OF MONTHLY PEAK DEMANDS Month 1972 1973 Change (%)1974 Change (0)1975 Change (%)1976 Change (%)1977 Change (0)1978 Change (%)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 438.0 417.2 403.2 405.0 422.4 467.4 491.7 489.5 434.4 441.0 460.9 475.4 461.5 465.8 436.2 428.7 424.0 528.0 533.0 510.0 479.0 442.0 464.0 481.0 5.4 11.6 8.2 5.9 0.4 13.0 8.4 4.2 10.3 0 7 0.7 1.2 463 452 423 437 502 583.4 564 548 548 476 480 508 0.3-3.0-3.0 1.9 18.4 10.5 5.8 7.5 14.4 7.7 3.4 5.6 520 500 455 460 483 566 579 586 582 489 537 547 12.3 10.6 7.6 5.3-3.8-3.0 2.7 6.9 6.2 2.7 11.9 7.7 529 527 525 499 543 624 633 627 581 538 608 632 1.7 5.4 15.4 8.5 12.4 10.2 9.3 7.0 0.2 10.0 13.2 15.5 605 607 575 564 646 687 694 715 664 595 620 648 14.4 15.2 9.5 13.0 19.0 10.1 9.6 14.0 14.3 10 6 2.0 2.5 666 649 602 600 641 787 809 787 742 688 705 741 10.1 6.9 4.7 6.4-0.8 14.6 16.6 10.1 11.7 15.6 13.7 14.4 AND ENERGY REQUIREMENTS Sheet 5 of 7 Monthly Energy Requirements (GWh)Month 1972 1973 Change (%)1974 Change (%)1975 Change (%)1976 Change (%)1977 Change (%)1978 Change (%)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 222.5 207.6 221.9 210.6 229.0 236.1 251.6 250.0 226.5 231.5 235.6 248.1 251.5 218.7 240.1 227.9 244.6 248.0 271.6 275.0 241.1 224.4 232.6 237.8 13.D 5.3 8.2 8.2 6.8 5.D 7.9 10.9 6.k-3.1-l.3-4.2 251.0 226.5 237.5 230.8 258.1 288.5 292.4 284.2 259.7 255.4 252.4 276.5-0.2 3.6-1.1 1.3 5.5 16.3 7.7 3.3 7.7 13.8 8.5 16.3 297.9 264.3 285.4 262.6 266.9 307.0 328.0 354.0 273.8 299.0 271.5 310.1 18.7 16.7 20.2 13.8 3.4 6.4 12.2 24.6 5.4 17.1 7.6 12.2 293.9 277.9 307.3 285.4 307.0 332.6 353.5 349.6 316.2 325.7 335.4 379.4-1.3 5.1 7.7 8.7 15.0 8.3 7.8-1.2 15.5 8.9 23.5 22.3 369.0 328.6 399.2 375.0 397.2 396.1 402.1 414.8 362.3 354.0 343.5 376.5 25.6 18.2 29.9 31.4 29.4'9.1 13.7 8.6 4.6 8.7 2.4-0.8 408.1 350.8 352.7 354.0 374.8 411.1 469.0 445.4 394.2 401.0 403.2 438.2 10 6 6.8-11 6-5.6-5.6 3.8 16.6 7.4 8.8 13.3 17.4 16.4 PRC APERTURE",, CARD 1.1-159/160 Blank PVNGS ER-OL SALT RIVER PROJECT SYSTEM REQUIREMENTS AT SOURCE (Excludes Interruptible) NEED FOR POWER Month 1972 1973 Change (I)1974 Change (%)1975 Change (%)1976 Monthly Peak Demand (MW)Change (%)1977 Change (%)1978 Change (8)Table 1.1-7 COMPARISON OF MONTHLY PEAK DEMANDS Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 778 763 809 839 1040 1253 1360 1357 1251 1004 740 901 830 787 812 940 1271 1448 1446 1435 1378 1086 838 842 7 3 0 12 22 16 6 6 10 8 13-7 908 909 852 975 1366 1645 1595 1510 1602 1306 872 1012 9 16 5 4 7 14 10 5 16 20 4 20 1058 993 955 931 1300 1460 1598 1634 1511 1242 921 995 17 9 12-5-5-13 0 8-6-5 6-2 1045 904 1075 1081 1436 1685 1732 1668 1579 1090 1066 1102-1-10 13 16 10 15.8 2 5-14 16 ll 1213 1066 1104 1244 1514 1681 1675 1683 1731 1366 952 1089 16 18 3 15 5 0-3 0 10 25-12-1 1207 1115 971 1032 1510 1747 1854 1728 1729 1503 1108 1469-1 5-14-21 0 4 ll 3 0 10 16 35 AND ENERGY REQUIREMENTS Sheet 6 of 7 Monthly Energy Requirements (GWh)Month 1972 1973 Change (%)1974 Change (%)1975 Change (%)1976 Change (%)1977 Change (%)1978 Change (%)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 428 401 440 429 506 604 716 669 585 441 408 468 469 395 449 434 570 662 762 775 629 508 450 484 10-2 2 1 13 10 6 16 8 15 10 3 495 456 494 503 634 796 818 807 738 583 482 583 6 15 10 16 ll 20 7 4 17 15 7 20 605 523 545 532 612 702 840 840 725 553 494 545 22 15 10 6-4-13 3 4 2-5 2-7 572 497 570 537 657 770 893 874 723 564 530 603-6-5 5 0 7 10 6 4 0 2 7 ll 612 533 613 588 612 823 884 914 771 622 526 580 7 7 8 10-7 7-1 5 7 10 0-4 599 534 553 553 672 855 952 941 814 678 577 692-2 0-ll-6 lo 4 8 3 6 9 10 19 P R G'-'""'"'-: APERTURE CARD 1.1-161/162 Blank V I%1/'I P PVNGS ER-OL Month 1972 1973 Change (%)1974 Change (0)1975 Change (%)1976 SALT RIVER PROJECT SYSTEM REQUIREMENTS AT SOURCE (Excludes Interruptible) Monthly Peak Demand (MW)Change (%)1977 Change (8)1978 Change (8)NEED FOR POWER Table 1.1-7 COMPARISON OF MONTHLY PEAK DEMANDS Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 778 763 809 839 1040 1253 1360 1357 1251 1004 740 901 830 787 812 940 1271 1448 1446 1435 1378 1086 838 842 7 3 0 12 22 16 6 6 10 8 13-7 908 909 852 975 1366 1645 1595 1510 1602 1306 872 1012 9 16 5 4 7 14 10 5 16 20 20 1058 993 955 931 1300 1460 1598 1634 1511 1242 921 995 17 9 12-5-5-13 0 8-6-5 6-2 1045 904 1075 1081 1436 1685 1732 1668 1579 1090 1066 1102-1-10 13 16 10 15 8 2 5-14 16 ll 1213 1066 1104 1244 1514 1681 1675 1683 1731 1366 952 1089 16 18 3 15 5 0-3 0 10 25-12-1 1207 1115 971 1032 1510 1747 1854 1728 1729 1503 1108 1469-1 5-14-21 0 4 11 03 0 10 16 35 AND ENERGY REQUIREMENTS ,Sheet 6 of 7 Monthly Energy Requirements (GWh)Month 1972 1973 Change (%)1974 Change (8)1975 Change (8)1976 Change (%)1977 Change.(%)1978 Change (8)Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 428 401 440 429 506 604 716 669 585 441 408 468 469'395 449 434 570 662 762 775 629 508 450 484 10-2 2 1 13 10 6 16 8 15 10 3 495 456 494 503 634 796 818 807 738 583 482 583 6 15 lo 16 11 20 7 4 17 15 7 20 605 523 545 532 612 702 840 840 725 553 494 545 22 15 10 6-4-13 3 4 2-5 2-7 572 497 570 537 657 770 893 874 723 564 530 603-6-5 5 0 7 10 6 4 0 2 7 ll 612 533 613 588 612 823 884 914 771 622 526 580 7 7 8 10-7 7-1 5 7 10 0-4 599 534 553 553 672 855 952 941 814 678 577 692-2 0-ll-6 10 4 8 3 6 9 10..19 PR(APE-R TURp CAqg 1.1-161/162 Blank I 1 j,'Q G~~G-Cr-P PVNGS ER-OL NEED FOR POWER Table 1.1-8A RANGE OF CAPACITY FACTORS FOR INTERMEDIATE AND BASE LOADED UNITS (Sheet 1 ARIZONA PUBLIC SERVICE of 8)Power Plant and Unit Four Corners 1 Four Corners 2 Four Corners 3 Cholla 1 Ocotillo 1 Ocotillo 2 Saguaro 1 Saguaro 2 Type Steam Steam Stea'm Steam Steam Steam ,Steam , Steam Function Base Base Base Base Intermediate Intermediate Intermediate Intermediate Range of Capacity Factors (%)59-72 57-74 59-72 61-75 15-27 15-27 5-16 5-16 Yucca 1 Four Corners 4 Four Corners 5 Navajo 1 Navajo 2 Navajo 3 Steam S tealll Steam Steam Steam Steam Base Base Base Base Base 40-69(,)43-69(')58 78 c 58-78 c 58-79')Intermediate 34-47 West, Phoenix CC 1 West Phoenix CC 2 West.Phoenix CC 3 Cholla 2 Cholla 3 Cholla 4 Palo Verde 1 Palo Verde 2 Palo Verde 3 ,Comb.Cycle Comb.Cycle Comb.Cycle Steam Steam SteamSteam Steam Steam Intermediate Intermediate Intermediate Base Base Base Base Base Base 2-13 2-13 2-13 62-78 68-81 63-74(')58-84()58-84()58-84(Future Coal Steam Intermediate 33-57 (a)Person Units 162 reclassified as peaking units in 1980-no capacity factor data available.(b)Projects delayed-no data available.(c)Range represents a composite of the individual ranges calculated by the joint owners of these units.September 1980 l.1-190A Supplement 1 PVNGS ER-OL NEED FOR POWER Table 1.1-8A RANGE OF CAPACITY FACTORS FOR INTERMEDIATE AND BASE LOADED UNITS (Sheet, 2 of 8)LOS ANGELES DEPARTMENT OF WATER AND POWER (Page 1 of 2)Power Plant and Unit Owens Valley Aqueduct Harbor 1 Harbor 2 Harbor 3 Harbor 4 Harbor 5 Valley 1 Valley 2 Valley 3 Valley 4 Scattergood 1 Scattergood 2 Scattergood 3 Haynes 1 Haynes 2 Haynes 3 Haynes 4 Haynes 5 Haynes 6 Mohave 1 Mohave 2 Navajo 1 Navajo 2 Navajo 3 Coronado 1 Coronado 2 Type Hydro Hydro Hydro Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Function Base Base Base Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Base Base Base Base Base Base Base Base Base Base Base Base Base Base Base Base Range of Capacity Factors (%)52 83 0 0 1 1-2 0-1 1-6 1-6 5-14 11-24 25-50 34-59 26-81 37-68 39-74 54-68 49-69 55-79 56-77 42-65()38-65(c)58-78()58-78()55-79 71-81 72-80 Supplement 1 1,.1-190B September 1980 ,PVNGS'ER-OL NEED FOR POWER Table 1.1-8A RANGE OF CAPACITY FACTORS FOR INTERMEDIATE AND BASE LOADED UNITS (Sheet 3 of 8)LOS ANGELES DEPARTMENT OF WATER AND POWER (Page 2 of 2)Power Plant and Unit Intermountain 1 Intermountain 2 Intermountain 3 Intermountain 4 Palo Verde 1 Palo Verde 2 Palo Verde 3 il Type Steam Steam Steam Steam Steam Steam Steam Function Base Base Base Base'ase Base Base Range of Capacity Factors (%)62-67 59-68 58-67 58-69 58-84 5S-S4'8-84(')W September 1980, 1: 1-190C Supplement 1 PVNGS ER-OL NEED FOR POWER Table 1.1-8A RANGE OF CAPACITY FACTORS FOR INTERMEDIATE AND BASE LOADED UNITS (Sheet 4 of 8)EL PASO ELECTRIC COMPANY Power Plant and Unit Rio Grande Newman 1 Newman 2 Newman 3 Newman 4 Four Corners 4 Four Corners 5 Palo Verde'1 Palo Verde 2 Palo Verde 3 Type Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Function Base Base Base Base Base Base Base Base Base Base Range of Capacity Factors (%)33 36 46 60 62 40-69 ()(c)~43-69 5S-S4 5S-S4(')5S-84 Supplement 1 1.1-190D September 1980 PVNGS ER-OL NEED FOR POWER Table 1.1-8A RANGE OF CAPACITY FACTORS FOR INTERMEDIATE AND BASE LOADED UNITS (Sheet 5 of 8)PUBLIC SERVICE COMPANY OF NEW MEXICO Power Plant and Unit Person 1 Person 2 Person 3 Person 4 Reeves 1 Reeves 2 Reeves 3 Four Corners 4 Four Corners 5 San Juan 1 San Juan 2 San Juan 3 San Juan 4 Palo Verde 1 Palo Verde 2 Palo Verde 3 Type Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Function Peaking Peaking Intermediate Intermediate Base Base , Base I Base I Base I I Base i Base Base Base Base Base Base Range of Capacity Factors (%)(a)(a)13-22 20-30 20-48 29-49 32-52 40-69(')43-69 62-74 56-73 64-74 61-7,5 58 84(c)58-84 ()(c)58-84 Pumped Storage 1 S 2 Hydro Intermediate (b)New Mexico Station Steam Base (b)September 1980 1.1-190E Supplement 1.I> PVNGS ER-OL NEED FOR POWER RANGE OF CAPACITY FACTORS FOR INTERMEDIATE AND BASE LOADED UNITS (Sheet 6 of')SALT RIVER PROJECT Power Plant, and Unit Agua Fria 1 Agua Fria 2 Agua Fria 3 Kyrene 1 Kyrene 2 Four Corners 4 Four Corners 5 Mohave 1 Mohave 2 Navajo 1 Santan 1 Santan 2 Santan 3 Santan 4 Navajo 2 Hayden 2 Navajo 3 Craig 1 Coronado 1 Craig 2 Coronado 2 Palo Verde 1 Palo Verde 2 Palo Verde 3 Type Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Comb.Cycle Comb.Cycle Comb.Cycle Comb.Cycle Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Function Intermediate Intermediate Intermediate Intermediate Intermediate Base Base Base Base Base Intermediate Intermediate Intermediate Intermediate Base Base Base Base Intermediate Base Intermediate Base Base Base Range of Capacity Factors (%)6-25 4-17 20-38 0-2 2-6 40-69<<)43-69 (c)42-65()38-65(c)58-78 (c)1-5 1-5 1-5 1-5 58-78 75-86 55-79 67-78 39>>58 66-78 38-58 58-84()58-84 5S-S4(')Supplement 1 1.1-190F September 1980 PVNGS ER-OL NEED FOR POWER Table 1.1-8A RANGE OF CAPACITY FACTORS FOR INTERMEDIATE AND BASE LOADED UNITS (Sheet'of 8)SOUTHERN CALIFORNIA EDISON (Page 1 of 2)Power Plant and Unit Type Function Range of Capacity Factors{%)Southern Hydro Bishop Hydro Northern Hydro Redondo 1-4 Redondo 5,6 Highgrove 1-4~t Etiwanda 1,2 Etiwanda 3,4 El Segundo 1,2 El Segundo 3,4 Alamitos 1,2 Alamitos 3,4 Alamitos 5,6 Hydro Hydro Hydro Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Int/Base Int/Base Int/Base Intermediate Intermediate 62-69 49-56 58<<73 8-28 3-38 Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate 8-28 38-.62 3-38 38-62 3-38 38-62 43-64 Intermediate 43-64 San Bernardino 1,2 Steam Huntington Beach 1,4 Steam Intermediate 8-28 Intermediate 21-50 Mandalay 1,2 Cool Water 1,2 Garden State San Onofre 1 Long Beach 10 Long Beach ll Four Corners 4 Four Corners 5 Steam Steam Comb.Turb.Nuclear Steam Steam Steam Steam Base Intermediate Intermediate Base Base 65-75 8-28 8-28 40-69)43-69 Intermediate 21-50 Intermediate 8-28 Intermediate N/A September 1980 1'.1-190G Supplement 1 PVNGS ER-OL NEED FOR POWER Table 1.1-8A RANGE OF CAPACITY FACTORS FOR INTERMEDIATE.AND BASE ZOADED UNITS (Sheet 8 of 8)SOUTHERN CALIFORNIA EDISON (Page 2 of 2)Power Plant and Unit Type Function Range of Capacity Factors (%)Mohave 1 Mohave 2 Ormond Beach 1 Ormond Beach 2 Long Beach 1-9 Cool Water 3,4 Co-Generation San Onofre 2 San Onofre 3 Axis Steam Palo Verde 1 Palo Verde 2 Palo Verde 3 Steam Steam St.earn Steam Base Base Intermediate Intermediate Co-Gen.Nuclear Nuclear Steam Nuclear Nuclear Nuclear Base Base Base Intermediate Base Base Base Comb.Cycle Intermediate Comb.Cycle Intermediate 42>>65 38-65 39-57 39<<57 34 25-45 N/A'0-70 60-70 N/A 5s-s4()5s-s4(')58-84 Geothermal 1-4 Geothermal Base 75 Combined Cycle Comb.Cycle Intermediate California Coal 1 California Coal 2 Steam Steam Base Base Combustion Turbines Comb.Turb., Peaking 1<<3 Supplement 1 1.1-190H September 1980 PNVGS ER-OL Table l.l-ll NEED FOR POWER COMPARISON OF PARTICIPANTS GENERATING CAPACITY, LOAD, AND ENERGY GENERATION (Sheet 1 of 6)ARIZONA PUBLIC SERVICE Year 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Total Resources Minus Firm Purchases (MW)3412 3311 3573 3808 3816 3923 4163 4368 4610 4850'otal Projected Load Minus Firm Purchases (MW)2715 2860 2962 3068 3182 3474 3676 3847 4011 Inter-ruptible Load (MW)13 17 27 30 30 Energy Generation (GWH)12656 13754 14304 14985 15670 16087 17331 18601 19511 20541 July 1981 1.1-223 Supplement 3 PNVGS ER-OL NEED FOR POWER Table 1.1-11 COMPARISON'F PARTICIPANTS GENERATING CAPACITY, LOAD, AND ENERGY GENERATION (Sheet 2 of 6)LOS ANGELES DEPARTMENT OF WATER AND POWER Year 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Generating Capacity (MW)5684 5684 5971 5974 6051 6019 6231 6485 6632 6988 Peak Demand (MW)4220 4351 4223 4292 4382 4453 4536 4636 4737 4862 Energy Generation (GWH)14317 14932 16068 16486 16488 16576 16811 17148 17383 17723 Supplement 3 1.1-224 July 198l PNVGS ER-OL NEED FOR POWER Table l.l-ll COMPAR I SON OF PART I C I PANTS GENERAT I NG CAPAC I TY g LOAD, AND ENERGY GENERATION..(Sheet 3.of 6)EL PASO ELECTRIC Year 1981 1982 1983 1984 , 1985 1986 1987 1988 1989 1990 Generating Capacity (MW)895 920 1095 1289 1283 1477 1502 1502 1484 1468 Peak Demand-(MW)742 776 809 847 892 936 983 1030 1085 1141 Energy Generation (GWH)4139 4217 4346 4566 4804 5053 5313 5591 5884 6191 July 1981 1.1-225 Supplement 3 PNVGS ER-OL NEED FOR POWER Table 1.1-11 COMPARISON OF PARTICIPANTS GENERATING CAPACITY, LOAD, AND ENERGY GENERATION (Sheet 4 of 6)PUBLIC SERVICE OF NEW MEXICO Year 1981 1982 1983 1984 1985 1986 1987 1988 ,1989 1990 Generating Capacity', (MW)1235 1273 1342 1331 1465 1560 1665'785 1855 2068 Peak., Demand (MW)997 1061 1086 1109 1187 1257 1344 1441 1518 1599 Energy Generation (GWH)6563 8015 9126 9961 10127 10295 10424 10362 10240 10475 Supplement 3 1.1-226 C July 1981 PNVGS ER-OL Table 1.1-11 NEED FOR POWER COMPARISON OF PARTICIPANTS GENERATING CAPACITY, LOAD, AND ENERGY GENERATION (Sheet 5 of 6)SALT RIVER.PROJECT Year 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Generating Capacity (MW)3300 3221 3576 3932 3869 4179 4179 4179 4179 4179 Peak Demand, (MW)2263 2360 2462 2605 2703, 2822 2905 3015 3121 3225 Energy Generation (GWH)10368 11579 12510 13243 13572 13782 14080 14399 14744 15193 July 1981 l.l-227 Supplement 3 PNVGS ER-OL NEED FOR POWER Table l.l-ll COMPARISON OF PARTICIPANTS GENERATING CAPACITY, LOAD, AND ENERGY GENERATION (Sheet 6 of 6)SOUTHERN CALIFORNIA EDISON Year 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Generating Capacity (MW)15471 16184 17446 17837 17535 17889 18491 18941 19582 20232 Peak Demand~(MW)13274 13647 13895 14305 14735 15185 15635 16125 16599 17129 Energy Generation (GWH)62970 64300 66980 68590 70380 72210 74290'6440 78720 81110 Supplement 3 l.1-228.July 1981 Table 1.1-12 SCPPA MEMBERS LOADS AND RESOURCES (Sheet 1 of ll)CITY OF ANAHEIM ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)Actual 1980 Pro ected 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)...Peak Load (MW).............. Resources: 1826 1948 2055 2163 2270 2359 2443 2516 2588 2658 2721 407.5 428.0 449.8 472.9 495.6 515.3 532.2 547.4 562 2 576.4 589.9 San Onofre Units¹2&¹3 IPP Units¹1-¹4.......SCPPA-Palo Verde Units¹1-¹3...--..-- Purchases. 407.5 428.0 34.8 422.3 69.5 5.6 413.5 69.5 11.3 431.8 69.5 11.3 451.5 69.5 76.7 16.9 406.2 69.5 153.4 16.9 363.5 69.5 230.1 16.9 320.4 69.5 306.8 16.9 276.8 69.5 306.8 16.9 290.3.Total.~~~~Margin for Reserves/Losses.. 7.3 15.7 17.0 17.0 37.1 55.9 74.7 93.6 93.6 407.5 428.0 457.1 488.6 512.6 532.3 569.3 603.3 636.9 670.0 683.5'ercent Margin.............. 1.6 3.3.3.4 3'7.0 10.2 13.3 16.2 15.9 5 0 0 Table 1.1-12 SCPPA MEMBERS LOADS AND RESOURCES (Sheet 2 of 11)CITY OF AZUSA ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)Actual 1980 Pro ected 1 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)...Peak Load (MW).............. 39.0 42.4 43.8 45.2 46.7 48.1 49.8 51.5 53.2 55.0 56.9 166.0 183.8 190.0 196.1 202.4 208.6 215.7 223.1 230.7 238.5 246.6 Peak Resources: SCPPA: l Palo Verde.............. o SCE Purchases (2)....~~....8'.5 39.0 42.4 43.8 44.6 45.5 1.5 2.3 2.3 46.9 48.0 49.7 2.3 2.3 2.~3 51.4 53.2 55.1 Total Resources (MW)........ -39.0 Margin for Reserves/Losses.. Percent Margin.............. 42.4 43.8 0 0 45.4 0.2 0.4 47.0 0.3 0.6 48.4 0.3 0.6 50.3 0.5 1.0 52.0 0.5 1.0 53.7 0.5 0.9 55.5 0.5 0.9 57.4 0.5 0.9~1 Loa-Forecast prepared June 18, 1980.(2)-Southern California Edison provides for reserves and losses.5 0 0 4 C Table l.l-l2 SCPPA MEMBERS LOADS AND RESOURCES (Sheet 3 of ll)CITY OF BANNING ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)Actual 1980 Pro'ected 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)...Peak Load (MW).............. 65.6 18.1 68.5 16.9 70.3 17.4 70.4 18.0 74.7 18.5 76.6 19.1 78.7 19.6 80.7 82.9 85.0 87.1 20.2 20.7 21.3 21.9 Peak Resources: SCPPA: I tV Palo Verde........'...... 4)SCE Purchases (1)......... .8 1.5 1.5 2.3 2.3 17.3 17.9 17.8 18.4 18.1 16.9 17.4 17.4 2.3 2.3 2.3 3 18.9 19.5 20.1 Total Resources (MW)........ Margin for Reserves~osses 18.1 16.9 17.4 18.2 0.2 18.8 0.3 19.4 0.3 20.1 0.5 20.7 0.5 21.2 0.5 21.8 0.5 22.4 0.5 Percent Margin.............. 1.6 1.6 ,2.6-2.5 2.4 2.3 2.3~1-southern california Edison provides for reserves and losses.U 0 XI 0 Table 1.1-12 SCPPA MEMBERS LOADS AND RESOURCES (Sheet 4 of ll)CITY OF BURBANK ELECTRIC UTILITY SYSTEM ,(CALENDAR YEAR)Actual 1980 Pro ected 1 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Reguirenents (GWh)...Peak Load (ÃW).............. Resources: On-Site: 875 203 901 209 928 215 956 222 228 235 241 247 253 259 266 985 1014 1040 1066 1092 1120 1148 Nagnolia Unit 03..~.~..~Magnolia Unit 84........ Olive Unit 81........ ~-~Olive Unit<<2...~~~~~~~~)(agnolia Unit 85"~.~~.~Olive Unit 83........... Olive Unit 84........... Subtotal.............. Off-Site: BPA.20 28 42 58 22 19 33 222 5.1 42.0 20 28 42 58 22 19 33 222 S.l 42.0 20 28 42 58 22 19 33 222 5.1 42.0 20 28 42 58 22 19 33 222 5.1 42.0 28 42 58 22 19 33 202 5.1 42.0 28 42 58 22 19 33 202 5.1 42.0 28 42 58 22 19 33 202 5.1 42.0 28 42 58 22 19 33 202 5.1 42.0 42 58 22 19 33 174 5.1 42.0 42 58 22'19 33 174 5.1 42.0 42 58 22 19 33 174 5.1 42.0 Subtotal...... Projects: 47.1 47.1 47'47.1 47.1 47.1 47.1 47.1 47.1 47'47.1)nteaaountain Coal...... SCPPA-Palo Verde........ White Pine Coal......... AEPCO Coal.............. 3.0 6.0 6.0 9.0 12.8 9.0 25.6 9.0 25.0 38.3 9.0 25.0 51,1 9.0 9.7 50.0 Subtotal............ 0 21.8 59.6 72.3 119.8 Total Resources (RW)Nargin for Reserves/Losses.. 269 66 269 60 269 54 272 50 27 20 25S 255 258 17 271 24 281 28 293 341 75 Percent Nargin.............. 32.5 28.7 25.1 22.5 11.8 8.5 7.1 9.7 11.1 13~1 28~2~r-rp rr r*t prep r d I!r rt.rprr Table l.l-l2 SCPPA MEMBERS LOADS AND RESOURCES (Sheet 5 of ll)CITY OF COLTON ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)Actual Pro'ected 1 Energy Requirements (GWh)...Peak Load (MW).............. 28.6 29.2 31.0 32.9 34.8 36.8 38.7 40.5 42.3 44.0 45.6 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 113.5 120.3 127.8 135.5 143.2 151.4 159.2 166'174.2 181'187.7 Peak Resources: SCPPA: Palo Verde.............. .8 1.5 1.5 2.3 2.3 2.3 2.3 2~3 3 SCE Purchases (2)......... 28.6 29.2 31.0 32'33.6 35.6 36.9 38.7 40.5 42.2 43.8 Total Resources (MW)........ Margin for Reserves/Losses.. Percent Margin.............. 28.6 0 29.2 0 0 31.0 33.1 0.2 0.6 35.1 0.3 0.9 37.1 0.3 0.8 39.2 0.5 1.3 41.0 0.5" 1.2 42.8 0.5 1.2 44'0.5 46.1 0.5~(1 L-oad Forecast prepared Case 13, 1esc: (2)-Southern California Edison provides for reserves and losses.5 txj 0 0 SCPPA Table l.l-l2 MEMBERS LOADS AND RESOURCES (Sheet, 6 CITY OF GLENDALE ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)of ll)Actual 1980 Pro ected (1)1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)...Peak Load (MW).............. 774 189 789 195 818 201 841 207 865 213 890 220 915 226 940 233 967 240 248 2/5 994 1022 I l M 4)Resources: (2)Grayson Power Plant No.3.Grayson Power Plant No.4.Grayson Power Plant No.5.Grayson Power Plant No.6.Grayson Power Plant No.7~Grayson Power Plant No.8.Hoover (3)................ BPA Peaking Exchange (4)..Intermountain Power Proj..Excess IPP~~~~~~~~~~~~~~~Arizona Electric Power Cooperative Project..... White Pane................ SCPPA-Palo Verde (5)......21 47 49 23 30 98 18 50 0 0 0 0 0 21 47 49 23 30 98 18 50 0 0 0 0-'0 21 47 49 23 30 98 18 50 0 0 0 0 0 21 47 49 23 30 98 18 50 0 0 0 0 3 21 47 49 23 30 98 18 50 0 0 0 0 6 21 47 49 23 30 98 18 50 0 0 0 0 6 21 47 49 23 30 98 18 50 11 3 0 0 9 21 47 49 23 30 98 18 50 23 6 0 0 9 0 47 49 23 30 98 18 50 35 9 25 0 9 0 47 49 23 30 98 18 50 47 12 25'9 9'0 47 , 49 23 30 98 18 50 47 12 50 18 9 Total Resources (MW)....Margin for Reserves/Losses.. Percent Margin.............. 336 147 78 336 141 72 336 135 67 339 132 64 342 129 61 342 122 55 359 133 59 374 393 417 61 64 68 141'53 169 451 196 77~1-Forecast prepared June 1, 19el.=*(2)-Capacity reduced by transmission losses.(3)-Hoover contract subject to renewal in 1987.(4)-BPA contract subject to renewal in 1986.m (5)-Does not include transmission losses.5 0 0 Table l.l-l2 SCPPA MEMBERS LOADS AND RESOURCES (Sheet 7 of ll)CITY OF PASADENA ELECTRIC UTXLXTY SYSTEM (CALENDAR YEAR)Actual 1980 1981 1982 Energy Requirements (GWh)...844 982 1009 Pro'ected 1 1983 1984 1985 1986 1987 1988 1989 1990 1030 1086 1126 1163 1202 1246 1292 1341 Peak Load (MW).............. 197 215 215 218 225 232 239 246 254 263 272 Resources: (2)Broadway l.Broadway 2 Broadway 3.Glenarm 9.Gas Turbine l........... Gas Turbine 2........... Hoover Azusa.BPA.Intermountain Power Proj White Pine.Arizona Electric Power Cooperative Project... IPP Excess Power........ SCPPA-Palo Verde........ 45 45 71 45 26 26 ll 15 30 45 45 45 45 71 71 45 45 26 26 26 26 11 ll 15 15 30 30 45 45 71 0 26 26 ll 15 30 45 45 71 0 26 26 ll 15 30 45 45 45 45 71 71 0 0 26 26 26 26 ll 11 15 15 30 30 45 45 71 0 26 26 ll 15 30 23.19 8 45 45 71 0 26 26 ll 15 30 46 29 8 45 45 71 0 26 26 ll 15 30 70 23 39 8 0 45 71 0 26 26 11 15 30 94 8 23 38 8 Total 314 314 314 Percent Margin.............. 59 46 46 Margin for Reserves/Losses.. 117 99 99 271 274 53 49 24 22 274 42 277 38 16 319 73 30 352 98 39 409 146 56 395 123~1Janu-ary 16, 1981 forecast.Revision currently in progress.(2)-Capacity reduced by transmission losses. Table 1.1-12 SCPPA MEMBERS LOADS AND RESOURCES (Sheet 8 of ll)CITY OF RIVERSIDE ELECTRIC UTILITY SYSTEM (CALENDAR YEAR}Actual 1980 Pro ected 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)...1079 1137 1186 1218 1256 1294 1332 1373 1413 1461 1505 Peak Load (0).............. 312-8 315.0 325.0 330.0 339.0 352.0 363.0 375.0 389.0 405.0 424.0 Resources: San Onofre Units¹2 6<<3..IPP Units¹1-<<4....~.~~~SCCPA-Palo Verde Units<<1<<3~~~~~~~~~~Purchases. 312.8 315.0 19.7 309.5 39.4 3.8 296.0 39.4 7.5 302.2 39.4 7.5 315.2 39.4 51.1 11.3 284.5 39.4 102.3 11.3 257.9 39.4 153.4 11.3 233.1 39.4 204.5 11.3 210.6 39.4 204.5 11.3 229.6 Total 312.8 315.0 329.2 339.2 349.1 362.1 386.3 410.9 437.2 465.8 484.8 Margin for Reserves/Losses.. Percent Margin.............. 4.2 1.3 9.2 2.7 10.1 2.9 10.1 2.9 23.3 6.4 35.9 9.6 48.2 12.4 60.8 15.0 60.8 14.3 0 0 Table 1.1-12 SCPPA MEMBERS LOADS AND RESOURCES (Sheet 9 of 11)CITY OF VERNON ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)Actual 1980 Pro ected 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)...1222 1200 1200 1200'200 1200 1200 1200 1200 1200 1200 Peak Load (MW).............. '36 230 230 230 230 230 230 230 230 230 230 I I I M 4)Resources: Diesel<<1.Diesel<<2 Diesel<<3 Diesel¹4.Diesel¹5~~~~~~~~~~SCPPA-Palo Verde 1.SCPPA-Palo Verde 2.SCPPA-Palo Verde 3~SCE<<Purchase (1)...~~~~~~236 226 5 5 222 5 5 5 5 5 3 207 5 5 5 5 5 3 4 204 5 5 5 5 5 3 4 204 5 5 5 5 5 5 5 5 5 5 5 5 5-5 5 3 3'4 4 4 3 3 3 201 201 201 5"5 5 5 5.-3 4 3 201 5 5 5 5 5 3 4 3 201 Total.Margin for Reserves/Losses.. 236 231 232 235'36 236-236 236 236 6 236 6 236~1-Southern California Edison provides for reserves and losses.M C d.'8 8 ff'a 0 a 0 Table 1.1-12 SCPPA MEMBERS LOADS AND RESOURCES{SheeQ lp of 11)IMPERIAL IRIGATION DISTRICT ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)Page 1 of 2 Actual 1980 Energy Requireaents (ash)...1439 Pro ected 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1540 1601 1665 1732 1801 1873 1948 2026 2107 2191 Peak Load (HW).............. 368 391 421 464 482 502 522 543 565 587 Resources: Steans Unit 1 e~~~~~~~Unit 2........... Unit 3~~~~~~~~Unit 4 o~~~~Das Turbine: Bradley C.T.1...Bra@lay C.T.2...Coachella C.T.l.Coachella C.T.2.Coachella C.T.3.Coachella C.T.4.RocJwood C.T.1..Rockwood C.T.2..Unnaned C.T......~~~~~~~\~~~~~~0~~~\~~~~~~~~~~~~~~~\~~~~Subtotal.............. 20 32 48 80 180 9 9 20 20 20 20 25 20 32 48 80 180 9 9 20 20 20 20 25 25 20 32 48 80 180 9 9 20 20 20 20 25 25 20 32 48 80 180 9 9 20 20 20 20 25 25 50 20 32 48 80 180 9 9 20 20 20 20 25 25 50 20 32 48 80 180 9 9 20 20 20 20 25 25 50 20 32 48 80 180 9 9 20 20 20 20 25 25 50 20 32 4s 80 180 9 9 20 20 20 20 25 25 50 20 32 48 80 180 9 9 20 20 20 20 25 25 50 20 32 48 80 180 9 9 20 20 20 20 25 25 50 20 32 48 80 180 9 9 20 20 20 20 25 25 50 Subtotal.............. 123 148 148 198 198 198 198 198 198 198 198 Diesel: Bradley l..Bravley 2..Bradley 3..Brasley 4..Brasley 5..Bradley 6..Bradley 7..Bra@lay 8..~~~~~~\~~~~~~.75.75.75 1.50 1.50 1.5 2.625 2 625.75.75.75 1.50 1.50 1.5 2.625 2.625.75.75.75 1.50 1.50 1.5 2.625 2.625.75.75.75 1.50 1.50 1.5 2.625 2.625.75.75.75 1.50 1.50 1.5 2.625 2.625.75.75~75 1.5D 1.50 1.5 2.625 2.625.75.75.75 1.5D 1.50 1.5 2.625 2.625~75 75 75 1 5D 1.50 1.5 2.625 2.625.75.75~75 1.50 1.50 1.5 2.625 2.625.75.75.75 1.50 1~50 1.5 2.625 2.625.75.75.75 1.50 1.50 1.5 2.625 2.625 Subtotal.............. 12 12 12 12 12 12 12 12 12 12 12 Table 1.1-12 SCPPA MEMBERS LOADS AND RESOURCES (Sheet ll of 11)IMPERIAL IRIGATION DISTRICT ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)Page 2 of 2 Actual 1980 Pro ected 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Nydro: Drop No.4 Drop No.4 Drop No.3 Drop No.3 Drop No.2 Drop No.2 Pilot Knob Unit 1.......Unit 2.......Unit l.......Unit 2.......Unit 1.......Unit 2.......Unit 1.......7.5 7.5 3.75 3.75 3.75 3.75 9.0 7.5 7.5 3.75 3.75 3.75 3.75 9.0 7.5 7.5 3.75 3.75 3.75 3.75 9.0 7.5 7.5 3.75 3.75 3.75 3.75 9.0 7.5 7.5 3.75 3.75 3.75 3.75 9.0 7.5 7.5 3.75 3.75 3.75 3.75 9.0 7.5.7.5 3.75 3.75 3.75 3.75 9.0 7.5 7.5 3.75 3.75 3.75 3.75 9.0 7.5 7.5 3.75 3.75 3.75 3.75 9.0 7.5 7.5 3.75 3.75 3.75 3.75 9.0 7.5 7.5 3.75 3.75 3.75 3.75 9.0 Subtotal... 39 39 39 39 39 39 39 39 39 Geothernal: Additions{1)...12 15 18 Nucleary Palo Verde 1...Palo Verde 2...Palo Verde 3...Subtotal.......... 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 3.5 3.5 3.5 3.5 Other: WAP-Parker-Davis.. SCE-Axis Plant....Purchases......... 33~25 40 33 25 40 33 25 40 33 25 40 33 25 40 33 25 100 33 25 100 33 25 100 33 33 25 25 250 250 33 25 261 Subtotal Total...Nargin for Reserves/Losses.. Percent Nargin...98 452 23 98 477 86 22 98 477 56 13 98 531 19 98 534 70 15 158 597 115 158 604 102 20 158 607 85 16 308 760 217 308 763 198 35 319 777 190 32~t-n*p tdt h thyprtiipti in r rth rii ingp i t:.Ilh'd th i.nr iy nii d.0 0 Table 1.1-13 M-S-R MEMBER LOADS AND RESOURCES (Sheet 1 of 3)MODESTO IRRIGATION DISTRICT ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)Actual Pro ected Energy Requirements (Gwh)a~~~~~~~~~~~~~~1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1268 1358 1400 1446 1492 1539 1595 1652 1712 1773 1837 Peak Load (NW).......... 351.7 344 398 414 431 447 465 483 503 523 544 Resources: (MW)Existing Hydro~~~~~~~~Gas Turbine...Proposed Small hydro(Geothermal Harry Allen...ANP P~~~~~~~~~~Purchases........ 54.4 39.0 258.3 54.2 53.4 236.4 49.5 98.0 0.5 272'49.5 98.0 6.0 41.7 248.1 49.5 98.0 49.5 98.0 19.4 30.8 83.4 83.4 218 2 224 6 49.5 98.0 32.8 82.5 30.0 125.0 152.0 49.5 98.0 32.8 82.5 60.0 125.0 151.0 49.5 98.0 32.8 82.5 90.0 125.0 149.0 49.5 98.0 32.8 82.5 120.0 125.0 148.0 49.5 98.0 32.8 82.5 120.0 125.0 144.0 4'ot a 1~~~~~~~~~~~~~351.7 344.0 420.2 443.3 468.5 486.3 569.8 598.8 626.8 655.8, 651.8 Margin for Reserve/Losseso~~~~Percent Margin.......... '0 0 0 22.2 29.3 37.5 39'104.8 115.8 123.8 132.8 107.8 0 5.6 7.1 8;7 8.8 22.5 24.0 24.6 25.4 19.8 a.Consists of at least seven separate small hydroelectric projects.b.Addition of additional geothermal, cogeneration, wind, hydroelectric, and coal resources is under study.0 0 Table 1.1-13 M-S-R MEMBER LOADS AND RESOURCES (Sheet 2 of 3)CITY.OF SANTA CLARA ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)Actual Pro'ected Energy Requirements (Gwh)Peak Load (MW)....... Resources: (MW)Thermal Geothermal, NCPA.Gas Turbine-Cogen Small Hydro Black Butte...... Stony Gorge...... Large Hydro Calaveras........ Purchases.......... o'tal o~~~~~~~~~~~T Margin for Reserve/Losses................ 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1609 1754 1858 1959 2052 2142 2234 2326 2415 2516 2612 265.6 297 314 331 347 262 378 394 409 426 442 5.8 60.4 5.8 60.4 5.8 60.4 45.8 60.4 45.8 6.8 3.9 60.4 45.8 6.8 3.9 78.4 45.8 6.8 3.9 78.4 45.8 6.8 3.9 78.4 45.8 6.8 3.9 78.4 45.8 6.8 3.9 265.6 291.2 261.0 278.0 266.6 62.0 224.8 62.0 255.6 62.0 253.6 62.0 268.6 62.0 62.0 345.1 345.1 13.2 13.2 25.8 41.7 56.5 56.5 56.5 116.0 100.0 265.6 297.0 327.2 344.2 372.8 403.7 434.5 450.5 465.5 542.0 542.0 Percent Margin.......... 4.2 4.0 7.4 11.5 14.9 14.3 13.8 27.2 22.6 4 8 0 Table 1.1-13 M-S-R MEMBER LOADS AND RESOURCES (Sheet 3 of 3)CITY OF REDDING.ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)Actual Pro'ected Energy Requirements (Gwh).~~~~~~~~~Peak Load (NW).......... 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 444.6 481.4 511.2 536.8 562.4 587.9 609.2 630.5 651'673.1 690.2 105 113 120 126 132 138 143 148 153 158 162 Resources: (MW)Thermal ANP P~~~~~~~~~~~Harry Allen....Geothermal..... Small Hydro Whiskeytown.... Saeltzer....... Lake Redding... Lake Red Bluff.North Fork.....Cottonwood..... Large Hydro Calaveras...... Purchases........ 105 113 120 4.0 4.0 0.9 117 115.4 18.8 115.4 8.3 16.6 16.6 25.0 5.0 16.5 4.0 0.9 14.0 14.0 18.8 115.4 4.0 0.9 14.0 14.0 6.0 4.0 0.9 14.0 14.0 6.0 18.8 115.4.18.8 115.4 25.025.0 10.0 15.0 16.5 16.5 25.0 20.0 16.5 4.0 0.9 14.0 14.0 6.0 25.0 20.0 16.5 4.0 0.9 14.0 14.0 6.0 9.0 18.8 18.8 115.4 115.4 otal............... T Margin for Reserve/Losses'~.o~~..~.....Percent Margin.......... 105 113 120 126 136.0 155.7 213.6 224.6 229.6 234.6 243.6 4.0 17.7 70.6 76.6 76.6 76.6 81.6 3.0 12.8 49.4 51.8 50.1 48.5 50.4 100 90 LOAD FACTOR 60.3%80 70 YEAR 1987 I988 MAXIMUM LOAD 31,336 MW 32,414 MW 60 50 O cL 40 30 20 10 500 1000 2000 3000 4000 HOURS 5000 6000 7000 8000 9000 Palo Verde Nuclear Generating Station ER-OL PVNGS Units 1, 2&3 Participants 1987-88 Coincident Load Duration Curve Figure 1.1-1

90 LOAD FACTOR 59 3%%d 80 70 YEAR 1987 1988 MAXIMUM LOAD 4,200 MW 4,394 MW I-O 50 Z 0 40 30 20 10 0 500 1000 4000 HOURS 5000 6000 8000 9000 Palo Verde Nuclear Generating Station ER-OL Arizona Public Service 1987-88 Coinciden Load Duration Curve Figure 1.1-2 I I 1 J!j~'I 90 LOAD FACTOR 61 4%%d 80 70 YEAR 1987 1988 MAXIMUM LOAD 1,223 MW 1,275 MW 60 W I o 50 z a.40 30 20 10 0 500 1000 2000 3000 4000 HOURS 5000 6000 7000 8000 9000 Palo Verde Nuclear Generating Station ER-OL t I Bl Paso Electric 1987-88 Coincident Load Duration Curve Figure 1.1-3 C pM Wa f 90 LOAD FACTOR 57 4~80 70 YEAR 1987 1988 MAXIMUM LOAD 5,077 MW 5230 MW 60 I-O 50 Z IL 40 30 20 10 0 500 1000 2000 3000 4000 HOURS 5000 6000 8000 9000 Palo Verde Nuclear Generating Station ER-OL Los Angeles Department of Water and Power 1987-88 Coincident Load Duration Curve Figure 1.1-4 ,J ~r i l')1 4 1 1 100 90 LOAD FACTOR 70 2%%d 80 70 YEAR 1987 1988 MAXIMUM LOAD 1,701 MW 1839 MW 60 50 O 4 40 30 20 10 0 500 1000 2000 3000 4000 HOURS 5000 6000 7000 8000 9000 Palo Verde Nuclear Generating Station ER-OL Public Service Company of New Mexico 1987-88 Coincident Load Duration Curve Figure 1.1-5 g 1 90 LOAD FACTOR 61%80 70 YEAR 1987 1988 MAXIMUM LOAD 16,051 MW 16515 MW 60 I O 50 Z 40 30 20 10 0 500 1000 2000 3000 4000 HOURS 5000 6000 7000 8000 9000 Palo Verde Nuclear Generating Station ER-OL Southern California Edison 1987-88 Coincident Load Duration Curve Figure 1.1-7 -J 90 LOAD FACTOR 58 5%80 70 YEAR 1987 1988 MAXIMUM LOAD 2870 MW 3,049 MW so I-o so Z 40 30 20 10 500 1000 2000 fi 3000 HOURS 5000 6000 7000 8000 9000 Palo Verde Nuclear Generating Station ER-OL Salt River Project 1987-88 Coincident Load Duration Curve Figure 1.1-6 ~0 f l l 1~~4 C A Rhl r e+LICe O'<I*0 BRITISII l y.JORN j+uosoR OA WsoN CRZCK PRINCC r+ORCC COLUMBIA WESTERN SYSTEMS COORDINATING COUNCIL GENERAL LOAD AREAS I Northwest Power Pool Area II Rocky Mountain Power Area I I I Arizona-New Mexico Power Area I V So.California-Nevada Power Area V No.California-Nevada Power Area VANCOUVER 0 100 200 300 Miles I'AUHLH+O>ohI I~S<~y S"OR'>rg SCALE 1 I P ORT/espy No A I Shl)f<uC/O'NC/ONTANA 8"S<<hI4 I g I NORTH PAKOTA II l 1 t+uyyc I r---I/~SOUTH OAKOTA I Wy OREC r I I.BoIss 8 ULU I t CHEVY/(.,.S4CR4~OhICIry 8 t C4RS 4hssNrd N NNE ll(--((~~NEBRASKA r WRAL y 80ehIVeR COL.O S4I r I.4Ire c l/Xx~UTAH/IV XQ',"*UALLTURH X J I RLILcs~RaOO MOTATR COLORApp KANSAS V f III~'~RCs~ARIZONA SgR OI COO 8~OShlIX MEXICO I I I I TEXAS S4, T4 Fe g I---0/I I OKLAHOMA I NEW Palo Verde Nuclear Generating Station ER-OL GEOGRAPHICAL BOUNDARIES OP WSCC SUBAREAS Figure 1.1-O

PVNGS ER-OL NEED FOR POWER Month 1972 1973 Change (%)SOUTHERN CALIFORNIA EDISON 1974 Change (%)1975 Change (%)1976 Monthly Peak Demand (MW)Change (%)1977 Change (%)1978 Change (%)AND ENERGY REQUIREMENTS Sheet 7 of 7 Table 1.1-7 COMPARISON OF MONTHLY PEAK DEMANDS Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 7972 7772 7812 7902 8686 8877 9815 9754 8963 8561 8325 8995 8655 8235 8209 8233 9001 10253 9850 9659 9272 8846 8581 8125 8.6 6.0 5.1 4.2 3.6 15.5 0.4 (1.0)3.4 3.3 3.1 (9.7)8094 7333 7310 7703 7814 9685 9997 9500 9790 8819 8230 8264 (6-5)(11.0)(11.0)(6.4)(13.2)(5-5)1.5 (1.6)5.6 (0-3)(4.1)1.7 8389 8022 7659 7668 8176 8527 9906 10127 10193 9077 8342 8566 3.6 9.4 4.8 (0-5)4.6 (12.0)(0-9)6.6 4.1 2.9 1.4 3.7 8268 8412 8329 8151 9447 11081 10653 11069 10373 9221 9071 8849 (1.4)4.9 8.7 6.3 15.5 30.0 7.5 9.3 1.8 1.6 8.7 3.3 8841 8481 8468 8340 9019 9809 11217 11058 11247 8976 8705 8925 6.9 0.8 1.7 2.3 (4.5)(11.5)5.3 (0.1)8.4 (2.7)(4.0)0.9 8749 8606 8421 8286 9893 10826 11429 11337 11997 10061 9199 9633 (1.0)1.5 (0.6)(0.6)9.7 10.4 1.9 2.5 6.7 12.1 5.7 7.9 Monthly Energy Requirements (GWh)Month Jan Feb Mar Apr'ay Jun Jul Aug Sep Oct Nov Dec 1972 4336 4005 4362 4202 4495 4560 4966 5069 4560 4537 4370 4637 1973 4684 4129 4597 4420 4738 4918 5089 5162 4639 4789 4472 4306 Change (%)(8.0)3.1 5.4 5.2 5.4 7.9 2.5 1.8 1.7 5.6 2.3 (7.1)1974 4355 3847 4210 4135 4424 4577 4985 4919 4753 4555 4236 4409 Change (%)(7.0)(6.8)(8.4)(6')(6.6)(F 9)(2.0)(4.7)2.5 (4.9)(5.3)2.4 1975 4458 3978 4330 4268 4401 4416 4890 4857 4764 4599 4314 4532 Change (%)2.4 3.4 2.9 3.2 (0.5)(3')(1.9)(1.3)0.2 1.0 1.8 2.8 1976 4542 4208 4607 4443 4669 4920 5180 5047 4712 4736 4517 4699 Change (%)1.9 5.8 6.4 4.1 6.1 11.4 5.9 3.9 (1.1)3.0 4.7 3.7 1977 4707 4205 4746 4569 4650 4933 5341 5605 4966 4887 4615 4755 Change (%)3.6 (0.1)3.0 2.8 (0.4)0.3 3.1 11.1 5.4 3.2 2.2 1.2 1978 4740 4257 4736 4518 4937 5247 5554 5605 5237 5235 4896 5094 Change (%)0.7 1.2 (0.2)(1.1)6.2 6.4 4.0 0.0 5.5 7.1 6.1 7.1 PRC APEpygpp C4RD Peak demand is SCE's net main system peak demand.Energy requirement is SCE's net main system transmitted energy.1.1-163/164 Blank PVNGS ER-OL PALO VERDE NUCLEAR GENERATING STATION NEED FOR POWER Year 1.1.2 POWER SUPPLY (MW)(1)PEAKING 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 Table 1.1-8 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 1 of 13)PVNGS 1,2,&3 PARTICIPANTS APS EPE LADWP PNM SCE SRP 311 140 510 44 515 112 3 11 140 510 44 950 104 113 140 545 44 1083 101 151 140 611 44 1106 105 345 139 641 44 1106 345 614 66 971 64 1106 514 649 77 1303 64 1086 642 624 43 1278 64 1188 712 624 109 1331 58 1195 644 619 109 1327 53 1195 644 619 110 1327 53 1195 644 619 110 1327 53 1195 657 619 183 1327 42 1195 657 619 151 1327 42 1235 657 619 151 1327 31 1235 657 669 117 1327 31 935 657 669 125 1327 31 935 657 769 125 1327 31 935 657 769 125 1323 31 969 657 769 157 1313 20 800 657 769 240 1303 20 904 657 TOTAL PEAKING 1632 2059 2026 2157 2620 3335 3821 3909 3961 3947 3948 3961 4023 4031 4020 3736 3744 3844 3874 3716 3893 (2)INTERMEDIATE APS EPE LADWP PNM SCE SRP 254 119 969 114 8266 498 254 111 969 114 8478 498 452 136 969 114 8478 498 452 136 969 114 8478 504 452 206 962 114 9228 504 452 196 972 114 9978 504 452 143 968 114 9978 504 468 301 968 114 9871 796 693 141 968 114 10417 790 693 56 968 96 10777 790 693 213 924 96 10994 790 693 158 924 96 11025 794 693 158 924 96 11050 1284 693 276 924 96 11050 1284 693 390 924 96 11050 1494 693 420 924 96 11050 1494 693 578 924 96 11050 1494 693 492 924 96 11730 1494 693 525 924 96 12040 1494 693 504 924 246 12480 1494 693 271 924 360 12480 1494 (3)BASE LOAD APS EPE LADWP PNM SCE SRP 690 236 2024 175 408 0 816 285 2407 279 408 79 TOTAL BASE LOAD 3533 4274 INSTALLED RESOURCE 15385 16757 TOTAL INTERMEDIATE 10220 10424 10647 936 366 2375 383 1190 159 5409 18082 937 366 2197 383 1616 236 937 411 2377 383 2110 306 915 478 2816 383 2042 318 5735 6524 6952 18545 20610 22503 10653 11466 12216 12159 1038 496 3040 548 2170 481 7773 23753 1143 496 3189 548 2271 644 1248 690 3421 548 2394 807 1248 725 3421 709 2399 1015 8291 9108 9517 24718 26192 26844 12518 13123 13380 13710 1483 577 3421 693 2399 1016 9589 27247 1483 617 3451 693 2399 1017 1725 636 3456 933 2416 1133 2072 606 3456 933 2550 1249 9660 10299 11041 27311 28527 29395 13690 14205 14323 14647 2428 637 3456 1529 1467 13121 31788 14677 14835 15429 2424 637 3456 1529 4314 1464 2780 645 3916 1659 4514 1761 2780 731 3843 1659 4255 1755 13824 15275 15023 32237 33854 34296 15772 3136 898 3483 1789 4503 2052 15861 35507 16341 16222 3136 898 4099 1789 4807 2052 3614 1098 4355 2025 5483 2052 16781 18627 36838 38742 PRC APERTURE CARO NON-FIRM PURCHASES OUTSIDE ANPP NON-FIRM SALES OUTSIDE ANPP 135 130 124 123 331 153 348 369 179 179 179 179 179 179 100 178 178 178 56 56 180 56 170 CAPABILITY 15517 16884 18203 18666 20939 22654 24099 25087 26371 27023 27426 27490 28706 29474 31966 32415 34032 34352 35563 37018 38628 1.1-165/166 Blank PVNGS ER-OL Year 1968 1969 1.1.2 POWER SUPPLY (MW)(1)PEAKING PALO VERDE NUCLEAR GENERATING STATION 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 NEED FOR POWER Table 1.1-8 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 1 of 13)PVNGS 1,2,&3 PARTICIPANTS APS EPE LADWP PNM SCE SRP 311 140 510 44 515 112 311 140 510 44 950 104 113 140 545 44 1083 101 151 140 611 44 1106 105 345 139 641 44 1106 345 61LI 66 971 64 1106 514 649 77 1303 64 1086 6 LI 2 624 43 1278 64 1188 712 624 109 1331 58 1195 644 619 109 1327 53 1195 644 619 110 1327 53 1195 644 619 110 1327 53 1195 657 619 183 1327 42 1195 657 619 151 1327 42 1235 657 619 151 1327 31 1235 657 669 117 1327 31 935 657 669 125 1327 31 935 657 769 125 1327 31 935 657 769 125 1323 31 969 657 769 157 1313 20 800 657 769 240 1303 20 904 657 TOTAL PEAKING (2)INTERMEDIATE 1632 2059 2026 2157 2620 3335 3821 3909 3961 3947 3948 3961 4023 4031 LI 020 3736 3744 3844 3874 3716 3893 APS EPE LADWP PNM SCE SRP 254 119 969 11LI 8266 498 254 111 969 114 8478 498 LI5 2 136 969 114 8478 498 452 136 969 114 8478 504 452 206 962 114 9228 504 452 196 972 114 9978 504 452 143 968 114 9978 5 0 LI 468 301 968 114 9871 796 693 141 968 114 10417 790 693 56 968 96 10777 790 693 213 924 96 10994 790 693 158 924 96 11025 794 693 158 924 96 11050 1284 693 276 924 96 11050 1284 693 390 924 96 11050 1494 693 420 924 96 11050 1494 693 578 924 96 11050 1494 693 492 924 96 11730 1494 693 525 924 96 12040 1494 693 504 9 2 LI 246 12480 1494 693 271 924 360 12480 1494 APS EPE LADWP PNM SCE SRP TOTAL BASE LOAD 690 236 2024 175 L108 0 3533 INSTALLED RESOURCE 15385 NON-FIRM PURCHASES OUTSIDE ANPP NON-FIRM SALES OUTSIDE ANPP CAPABILITY 135 15517 TOTAL INTERMEDIATE 10220 (3)BASE LOAD 10424 816 285 2407 279 408 79 4274 16757 130 16884 10647 10653 936 366 2375 383 1190 159 937 366 2197 383 1616 236 5409 5735 124 123 18203 18666 18082 18545 11466 937 411 2377 383 2110 306 6524 20610 331 20939 12216 915 478 2816 383 2 0 LI 2 318 6952 22503 153 22654 12159 12518 13123 1038 496 3040 548 2170 LI 81 7773 1143 496 3189 548 2271 644 8291 1248 690 3421 548 2394 807 9108 348 369 179 24099 25087 26371 23753 24718 26192 13380 1248 725 3421 709 2399 1015 9517 26844 179 27023 13710 13690 14205 1483 577 3421 693 2399 1016 1483 617 3451 693 2399 1017 1725 636 3456 933 2416 1133 9589 9660 10299 27247 27311 28527 179 179 179 27426 27490 28706 14323 2072 606 3456 933 2550 1249 11041 29395 179 100 29 47 LI 14647 14677 14835 178 2428 637 3L156 1529 1467 2424 637 3456 1529 4314 1464 178 2780 645 3916 1659 4514 1761 178 13121 13824 15275 31788 32237 33854 31966 32415 34032 15L129 2780 731 3843 1659 4255 1755 15023 34296 56 34352 15772 16341 16222 3136 898 3483 1789 4503 2052 3136 898 4099 1789 4807 2052 3614 1098 4355 2025 5483 2052 15861 16781 18627 35507 36838 387LI2 56 180 56 170 35563 37018 38628 PRO APERTURE CARD 1.1-165/166 Blank PVNGS ER-OL Arizona Public Service Company 1.1.2 Power Supply (MW)Plant and Unit Year Type Fuel Function 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 NEED FOR POWER Table 1.1-8 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 2 of 13)ARIZONA PUBLIC SERVICE Childs 1 Childs 2 Childs 3 Irving 1 Total Hydro Four Corners 1 Four Corners 2 Four Corners 3 Cholla 1 Ocotillo 1 Ocotillo 2 Saguaro 1 (b)Saguaro 2 West Phoenix 4 West Phoenix 5(c)West Phoenix 6(c)Yucca 1 Four Corners 4 Four Corners 5 Yuma GT 1 Yuma GT 2 Fairview GT 1 Ocotillo GT 1(d)Saguaro GT 1(d)West Phoenix GT 1(d)Yuma GT 1(d)Ocotillo GT 2(d)Saguaro GT 2(d)West Phoenix GT 2(d)Yuma GT 4(d)Hydr 0 Hydro Hydr 0 Hydro Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Comb.Comb.Comb.Comb.Comb.Comb.Comb.Comb.Comb.Comb.Comb.Turb.Turb.Turb.Turb Turb.Turb.Turb.Turb.Turb.Turb Turb.Coal Coal Coal Coal Oil Oil Oil Oil Oil Oil Oil Oil Coal Coal Oil Oil Oil Oil Oil Oil Oil Oil Oil Oil Oil Base Base Base Base Base Base Base Base Inter.Inter.Pk/Inter.(e) Pk/Inter.(e) Peak Peak Peak Inter.Base Base Peak Peak Peak Peak Peak Peak Peak Peak Peak Peak Peak 1.8 1.8 1.3 5 175 177 213 120 115 114 99 99 33 13 67 25 1.8 1.8 1.3 5 175 177 220 120 115 114 99 99 33 13 67 25 119 1.8 1.8 1.3 5 175 177 220 120 115 114 99 99 33 13 67 25 119 120 1.8 1.8 1.3 5 175 177 220 120 115 114 99 99 33 13 67 25 120 120 19 19 1.8 1.8 1.3 5 175 177 220 120 115 114 99 99 33 13 67 25 120 120 22 22 18 57 56 57 1.8 1.8 1.3 5 175 177 220 116 115 114 99 99 33 13 67 25 120 120 22 22 21 64 60 64 60 64 60 64 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 99 99 33 13 67 25 120 120 22 22 21 57 60 58 60 58 60 58 60 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 13 67 25 120 120 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 13 67 25 120 120 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 120 120 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 120 120 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 120 120 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 120 120 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 120 120 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 120 120 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 118 118 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 118 118 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 118 118 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 118 118 22 22 21 56 55 56 57 56 54 56 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 118 118 22 22 21 56 55 56 57 56 54 56 1.2 1.2 1.2 1.3 5 175 177 220 116 115 114 115 99 33 12 63 25 118 118 22 22 21 56 55 56 57 56 54 56 56 Page 1 of 3 PRC APERTUR CARD (a)(b)(c)(d)(e)Capacity shown includes resources installed as of July 1 of that year.Saguaro 1 upgraded 3/17/75.West Phoenix 5 and 6 downgraded 10/21/76.Gas Turbines downgraded 1975.Saguaro 1 and 2 changed from Peaking to Intermediate in 1970.1.1-167/168 Blank PVNGS ER-OL Arizona Public Service Company 1.1.2 Power Supply (MW)Plant and Unit Year Fuel Function 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 NEED FOR POWER CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 3 of 13)ARIZONA PUBLIC SERVICE Table 1.1-8 Navajo 1 Navajo 2 Navajo 3 West Phoenix CC 1 West Phoenix CC 2 West Phoenix CC 3 Cholla 2 Cholla 3 Choll.a 4 Palo Verde 1 Palo Verde 2 Palo Verde 3 Peaking Unit 1 Peaking Unit 2 Peaking Unit 3 Palo Verde 4 Palo Verde 5 Steam Steam Steam Comb.Cycle Comb.Cycle Comb.Cycle Steam S team Steam S team Steam Steam Comb.Turb.Comb.Turb.Comb.Turb.Steam Steam Coal Coal Coal Oil Oil Oil Coal Coal Coal Nuclear Nuclear Nuclear Oil Oil Oil Nuclear Nuclear Base Base Base Inter.Inter.Inter.Base Base Base Base Base Base Peak Peak Peak Base Base 105 105 105 105 105 105 75 75 75 105 105 105 75 75 75 105 105 105 75 75 75 235 105 105 105 75 75 75 235 105 105 105 75 75 75 235 242 105 105 105 75 75 75 235 242 347 105 105 105 75 75 75 235 242 347 356 105 105 105 75 75 75 235 242 347 356 50 105 105 105 75 75 75 235 242 347 356 356 50 105 105 105 75 75 75 235 242 347 356 356 50 50 50 105 105 105 75 75 75 235 242 347 356 356 356 50 50 50 105 105 105 75 75 75 235 242 347 356 356 356 50 50 50 105 105 105 75 75 75 235 242 347 356 356 356 50 50 50 478 Page 2 of 3 Future Coal (1)Peaking (2)Intermediate (3)Base Load Installed Res.Steam Coal Inter.311 311 254 254 690 816 1255 1381 113 452 936 1501 151 345 614 452 452 452 937 937 915 1540 1734 1981 649 452 1038 2139 619 693 1143 1248 1248 2235 2565 2560 624 468 624 693 619 693 1483 2795 619 619 619 693 693 693 1483 1725 2072 2795 3037 3384 619 693 2428 3740 669 693 669 693 769 693 2424 2780 2780 3786 4142 4242 769 693 3136 4598 769 769 693 693 3136 3614 4598 5076 PRC APERTURE CARO (a)Capacity shown includes resources installed as of July 1 of that year.(b)Saguaro 1 upgraded 3/17/77.(c)West Phoenix 5 and 6 downgraded 10/21/76.(d)Gas turbines downgraded 1975.1.1-169/170 Blank PVNGS ER-OL NEED FOR POWER Arizona Public Service Company 1.1.2 Power Supply (MW)Plant and Unit Nonfirm Purchases Year Fuel Function 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 Table 1.1-8 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 4 of 13)ARIZONA PUBLIC SERVICE Page 3 of 3 Outside ANPP PG&E Peaking Dave Johnston 4 (UP&I,)Huntington Canyon 1 (UP&L)Navajo Layoff-Navajo 1, 2.3 Unknown Pur-chase SRP contingent San Juan 2 (TG&E)Within PVNGS Total Nonfirm Sales Unknown Steam Steam Steam Unknown Steam Steam Coal Coal Coal Oil Coal Peak Base Base Base Base Pk/Inter.(f)Base 62 62 62 62 62 62 50 125 62 237 62 62 100 27 189 100 62 162 16 78 16 62 78 16 62 78 16 62 78 16 62 78 16 62 78 15 62 77 15 62 77 15 62 77 62 62 62 62 124 186 62 62 Outside PVNGS APA (Saguaro 1,2)Layoff Within PVNGS Capability Steam Oil Inter.(3)1314 (3)(3)(2)1440 1560 1600 (2)1969 (2)(2)2041 2326 2397 2643 2638 2873 2873 (100)3115 3362 3817 3863 4219 4304 4660 4784 (170)4968 PRC APERTURE CARD (a)(b)(c)(d)(e)(f)Capacity shown includes resources installed as of July 1 of that year.Saguaro 1 upgraded 3/17/75.West Phoenix 5 and 6 downgraded 10/21/76.Gas Turbines downgraded 1975.Saguaro 1 and 2 changed from Peaking to Intermediate in 1970.SRP contingent changed from Peaking to Intermediate in 1971.1.1-171/172 Blank PVNGS ER-OL LOS ANGELES DEPARTMENT OF WATER AND POWER NEED FOR POWER 1~1.2 Power Supply (MW)(a)Plant and Unit PNW Castaic Hoover Owens Gorge Owens Valley Aqueduct Year Hydro Pumped Strge Hydro Hydro Hydro Hydro Fuel Water Water Water Water Water Water Function Base Peaking Peaking Peaking Base Base 1968 17 0 400 110 9 50 400 0 400 110 9 50 324 0 435 110 9 63 0 0 501 110 9 57 1969 1970 1971 1972 260 24 507 110 9 66 525 228 553 110 9 73 525 560 553 110 9 74 525 535 553 110 9 74 1973 1974 1975 1976 525 630 511 110 9 74 525 630 511 110 9 74 525 630 511 110 9 74 350 630 511 110 9 74 1977 1978]97g 1980 350 630 511 110 9 74 350 630 511 110 9 74 350 630 511'110 9 74 350 630 511 110 9 74 1981 1982 1983 1984 350 630 511 110 9 74 1985 1986 1987 350 630 511 110 9 74 350 630 507 110 9 74 350 630 497 110 9 74 1988 350 630 487 110 9 74 Table 1.1-8 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 5 of 13)LOS ANGELES DEPARTMENT OF WATER AND POWER Page 1 of 2 Harbor 1 Harbor 2 Harbor 3 Harbor 4 Harbor 5 Valley 1 Valley 2 Valley 3 Valley 4 Scattergood 1 Scattergood 2 Scattergood 3 Haynes 1 Haynes 2 Haynes 3 Haynes 4 Haynes 5 Haynes 6 Mohave 1 Mohave 2 Navajo 1 Navajo 2 Navajo 3 Navajo Layoff Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Gas/Oil Coal Coal Coal Coal Coal Coal Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Base Base Base Base Base Base Base Base Base Base Base Base Base Base Base 78 79 96 96 96 99 99 163 163 175 179 0 232 232 222 222 343 343 78 79 96 96 96 99 99 163 163 175 179 0 232 232 222 222 343 343 78 79 96 96 96 99 99 163 163 175 179 0 233 236 232 236 344 344 78 79 96 96 96 99 99 163 163 175 179 0 233 236 232 236 344 344 152 0 78 79 96 96 96 95 99 163 160 179 0 0 232 219 220 232 344 344 152 120 78 79 96 96 96 95 101 171 160 179 179 0 193 219 220 227 344 344 152 152 78 79 92 92 94 101 101 171 160 179 179 0 232 232 220 227 344 344 158 158 159 0 0 0 78 79 92 92 94 101 101 171 160 179 179 0 222 232 220 227 344 344 158 158 159 159 0 0 78 79 92 92 94 101 101 171 160 179 179 0 222 232 220 227 344 344 158 158 159 159 159 73 78 79 92 92 94 101 101 171 160 179 179 0 222 232 220 227 344 344 158 158 159 159 159 73 72 67 86 86 87 94 101 171 160 179 179 0 222 232 220 227 344 344 158 158 159 159 159 73 72 67 86 86 87 94 101 171 160 179 179 0 222 232 220 227 344 344 158 158 159 159 159 73 72 67 86 86 87 94 101 171 160 179 179 0 222 232 220 227 344 344 158 158 159 159 159 73 72 67 86 86 87 94 101 171 160 179 179 0 222 232 220 227 344 344 158 158 159 159 159 73 72 67 86 86 87 94 101 171 160 179 179 0 222 232 220 227 344 344 158 158 159 159 159 73 72 67 86 86 87 94 101 171 160 179 179 0 222 232 220 227 344 344 158 158 159 159 159 73 72 67 86 86 87 94 101 171 160 179 179 460 222 232 220 227 344 344 158 158 159 159 159 73 72 67 86 86 87 94 101 171 160 179 179 460 222 232 220 227 344 344 158 158 159 159 159 0 72 67 86 86 87 94 101 171 160 179 179 460 222 232 220 227 344 344 158 158 159 159 159 0 72 67 86 86 87 94 101 171 160 179 179 460 222 232 220 227 344 344 158 158 159 159 159 0 72 67 86 86 87 94 101 171 160 179 179 460 222 232 220 227 344 344 158 158 159 159 159 0 PRC APERTURE CARD Turbines Coronado Steam Coal Base Comb.Turb.Distillate Peaking 80 80 80 80 76 76 76 205 76 210 76 210 76 140 76 140 76 70 76 70 76 76 76 (a)Power supply is based on net capacity.1.1-173/174 Blank PVNGS ER-OL LOS ANGELES DEPARTMENT OF WATER AND POWER NEED FOR POWER 1.1.2 Power Supply (MW)Plant and Unit IPP 1 IPP 2(IPP 3 IPP 4 Year Type Steam Steam Steam Steam Fuel Coal Coal Coal Coal Function Base Base Base Base 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 256 0 0 0 1988 256 256 0 0 Table 1.1-8 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 6 of 13)LOS ANGELES DEPARTMENT OF WATER AND POWER Page 2 of 2 Palo Verde 1 Palo Verde 2 Palo Verde 3 Steam Steam Steam Nuclear Nuclear Nuclear Base Base Base 70 0 0 70 0 0 70 70 0 70 70 0 70 70 70 70 70 70 70 70 70 Peaking Intermediate Base Load Installed Resources 510 969 2024 510 969 2407 545 969 2375 3503 3886 3889 611 969 2197 3777 641 962 2377 971-972 2816 1303 968 3040 3980 4759 5311 1278 968 3189 5435 1331 968 3421 1327 968 3421 1327 924 3421 5720 5716 5672 1327 924 3451 5702 1327 924 3456 1327 924 3456 1327 924 3456 5707 5707 5707 1327 924 3456 5707 1327 924 3843 1323 924 3483 1327 924 3916 6166 6094 6090 1313 924 4099 6336 1303 924 4355 6582 PRC APERTURE CARD (a)Power Supply is based on net capacity.(b)Based on the date of expected firm power availability, which is approximately one year later than the scheduled commercial operation date.1.1-175/176 Blank EL PASO ELECTRIC COMPANY 1.1.2 Power Supply (MW)Plant and Unit Year Type Fuel Function 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 PVNGS ER-OL NEED FOR POWER Table 1.1-8 CAPABILITY OF RESOURCES Rio Grande¹1((c)Rio Grande¹2((c)(c)Rio Grande¹3 ((c)Rio Grande¹4 (c)Rio Grande¹5 (Rio Grande¹6(Rio Grande¹7, (c)Rio Grande Newman¹1(cI Ic Newman¹2(b)()Newman¹3 (b)Newman¹4 Four Corners¹4 Four Corners¹5 Copper Future¹1 Future¹2 PVNGS¹1 PVNGS¹2 PVNGS¹3 PVNGS¹4 PVNGS¹5 Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Combined Cycle Steam Steam Combustion Turbine Steam Steam Steam Steam Steam Steam Steam Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Coal Coal Nuclear Nuclear Nuclear Nuclear Nuclear Peaking Peaking Peaking Peaking Peaking B/I/P B/I/P Bas e Base Base Base Base Base Base Peaking Base Base Base Base Base Base Base 20 24 22 37 37 32 31 87 93 112 20 24 22 37 37 24 24 87 93 112 56 20 24 22 37 37 49 49 87 93 112 56 56 20 24 22 37 36 49 49 87 93 112 56 56 20 24 22 36 36 28 28 160 86 92 ill 56 56 20 24 22 37 (f)20 20 160 86 92 111 56 56 13 13 17 34 (d)32 (e)42 42 138 82 86 106 56 55 13 13 17 34 (e)32 (e)42 42 138 82 86 106 124 56 55 13 13 17 (d)32 (d)42 42 138 82 86 106 224 56 55 13 13 17 34 32 (d)47 32 93 82 86 106 224 56 55 13 13 18 34 32 (d)47 32 102 82 86 106 224 56 55 13 13 18'4(d)32 47 28 91 82 86 106 224 56 55 13 13 18 34 47 33 105 82 86 106 224 56 55 73 13 13 18 34 32 (e)47 47 147 82 86 106 224 56 55 73 13 13 18 34 32 (e)47 33 106 82 86 106 224 56 55 73 200 13 13 18 34 (e)32 (e)47 33 106 82 86 106 224 54 53 73 200 (d)34 32 (e)47 33 106 82 86 106 224 54 53 73 200 200 18 34(2(e)4'7 3 106 82 86 106 224 54 53 73 200 200 18 34 32(e)47 33 106 82 86 106 224 54 53 73 200 200 200 18 34 32 (d)47 36 114 82 86 106 224 54 53 73 200 200 200 18 32 (d)47 36 114 82 86 106 224 54 53 73 200 200 200 50 1968 THROUGH 1988 (Sheet 7 of 13)EL PASO ELECTRIC COMPANY Total Installed Resources Total Peaking Total Intermediate (e)Total Base Load(Purchase Within ANPP Sale Within ANPP Capability (IR+P-S)495 140 119 236 495 536 140 111 285 536 642 140 136 366 642 642 140 136 366 756 139 206 411 740 66 196 478 756 740 716 77 143 496 716 840 43 301 496 840 940 109 141 690 940 890 109.56 725 890 900 110 213 577 900 885 110 158 617 885 977 183 158 636 977 1033 151 276 606 1033 1178 151 390 637 1178 1174 117 420 637 1174 1348 125 578 645 1348 1348 125 492 731 1348 1548 125 525 898 1548 1559 157 504 898 1559 1609 240 271 1098 1609 PRC APERTURE CARD (a)Adjusted for contingent power to PNM.NEA limitation on natural gas derates unit on oil)Rio Grande Units 1-8 and Newman Units 1-3 summer peak.ratings were adjusted to reflect age of units and increased oil fired operation. Operated as peaking unit.(f)Operated as intermediate unit (e)Operated as base load unit.1.1-177/178 Blank PUBLIC SERVICE COMPANY OF NEW MEXICO Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 PVNGS-ER-OL NEED FOR POWER 1.1.2 Power Supply (MW)Plant and Unit prager 6 Prager 7 Prager 8 Prager 9 Santa Fe 1 Santa Fe 2 Person 1 Person 2 Person 3 Person 4 Reeves 1 Reeves 2 Reeves 3 Four Corners 4 Four Corners 5 Las Vegas GT San Juan 1 San Juan 2 San Juan 3 San Juan 4 PV 1 PV 2 PV 3 Pumped Storage 1-2 Pumped Storage 3-4 New Mexico Station Type Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Comb.Turb.Steam Steam Steam Steam Steam Steam Steam Pumped Storage Pumped Storage Steam Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Fossil Nuclear Nuclear Nuclear PS PS Fossrl Fuel Fossil Fossil Fossil Fossil Function Peaking Peaking Peaking Peaking Peaking Peaking Intermediate Intermediate Intermediate Intermediate Base Load Base Load Base Load Base Load Base Load Peaking Base Load Base Load Base Load Base Load Base Load Base Load Base Load Intermediate Intermediate Base Load 6 7 7 12 22 22 35 35 50 50 75 6 7 7 12.6 6 22 22 35 35 50 50 75 104 6 7 7 12 22 22 35 35 50 50 75 104 104 6 7 7 12 22 22 35 35 50 50 75 104 104 6 7 7 12 22 22 35 35 50 50 75 104 104 6 7 7 12 22 22 35 35 50 50 75 104 104 20 6 7 7 12 22 22 35 35 50 50 75 104 104 20 165 6 7 7 12 22 22 35 35 50 50 75 104 104 20 165 0 7 7 12 22 22 35 35 50 50 75 104 104 20 165 6 5 11 5.5 5.5 18 18 28 32 50 50 75 104 104 20 165 161 6 5 11 5.5 5.5 18 18 28 32 50 50 75 104 104 20 157 153 6 5 11 5.5 5.5 18 18 28 32 50 50 75 104 104 20 157 153 0 0 ll 5.5 5.5 18 18 28 32 50 50 75 104 104 20 157 153 240 5.5 5.5 18 18 28 32 50 50 75 104 104 20 157 153 240 5.5 5.5 18 18 28 32 50 50 75 104 104 20 157 153 234 472 130 5.5 5.5 18 18 28 32 50 50 75 104 104 20 157 153 234 472 130 5.5 5.5 18 18 28 32 50 50 75 104 104 20 157 153 234 472 130 130 5.5 5.5 18 18 28 32 50 50 75 104 104 20 157 153 234 472 130 130 5.5 5.5 18 18 28 32 50 50 75 104 104 20 157 153 234 472 130 130 130 18 18 28 32 50 75 104 104 20 157 153 234 472 130 130 130 150 0 0 28 32 50 50 75 104 104 20 157 153 234 472 130 130 130 150 150 236 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 8 of 13)PUBLIC SERVICE COMPANY OF NEW MEXICO Table 1.1-8 PRC APERTURE CARD 1.1-179/180 Blank PVNGS ER-OL NEED FOR POWER 1984 1985 36 10 10 44 44 33 33 93 93 13 13 180 180 34 34 70 70 32 32 79 79 78 79 79 79 79 51 51 1986 10 44 33 13 180 34 70 32 79 78 79 79 51 1987 36 10 44 33 93 13 180 34 70 32 79 78 79 79 51 1988 36 10 44 33 93 13 180 34 70 32 79 78 79 51 Table 1.1-8 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 9 of 13)SALT RIVER PROJECT Page 1 of 3 PRC APE/j/pe cARD 1.1-181/182 Blank SALT RIVER PROJECT 1.1.2 Power Supply (MW)Plant and Unit Roosevelt Mormon Flat¹1 Mormon Flat¹2 Horse Mesa¹1, 2, 3 Horse Mesa¹4 Stewart Mt.Cross Cut Agua Fria¹1 Agua Fria¹2 Agua Fria¹3 Kyrene¹1 Kyrene¹2 Crosscut¹1, 2, 3, 4 (a)Crosscut Four Corners¹4 Four Corners¹5 Mohave¹1 Mohave¹2 Kyrene¹3 Retired 8/15/68 Year Type Hydro Hydro Pumped Storage Hydro Pumped Storage Hydro Hydro Steam Steam Steam Steam Steam Steam Internal Comb.Diesel Steam Steam Steam Steam Comb.Turb.Function Peaking Peaking Peaking Peaking Peaking Peaking Peaking Intermediate Fuel Oil/Gas Oil/Gas Intermediate Oil/Gas Oil/Gas Oil/Gas Intermediate Intermediate Intermediate Oil/Gas Peaking Peaking Oil Coal Coal Coal Coal Oil/Gas Base Base Base Base Peaking 1968 19 30 10 106 106 182 34 70 34 1969 19 30 10 106 106 182 34 70 34 79 1970 21 10 26 10 106 106 182 34 70 34 80 79 1971 49 10 109 109 182 34 70 34 80 80 76 1972 10 50 33 94 109 109 182 34 70 34 80 80 76 70 56 1973 36 10 50 33 97 13 109 109 182 34 70 34 80 80 79 79 63 1974 36 10 50 33 97 13 109 109 182 70 34 80 80 79 79 63 1975 36 10 50 33 97 13 109 109 182 34 70 34 80 80 79 79 63 1976 36 10 44 33 96 13 109 109 180 34 70 32 80 80 79 79 48 1977 36 10 44 33 96 13 109 109 180 34 70 32 80 80 79 79 48 1978 36 10 33 96 13 109 109 180 34 70 32 80 80 79 79 48 1979 36 10 44 33 93 13 180 70 32 80 80 79 79 51 1980 36 10 44 33 93 13 180 34 70 32 80 80 79 79 51 1981 36 10 44 33 93 13 180 34 70 32 80 80 79 79 51 1982 36 10 44 33 93 13 180 34 70 32 80 80 79 79 51 1983 36 10 33 93 13 180 34 70 79 78 79 79 51 PVNGS ER-OL NEED FOR POWER 1978 1979 1980 48 51 51 42 47 47 42 47 163 163 163 66 64 64 66 64 72 72 72 72 72 72 72 72 72 72 72 72 69 69 163 163 163 209 210 210 163 163 163 116 245 245 1981 51 47 47 163 64 64 72 72 72 72 69 163 210 163 116 245 116 245 1982 51 47 47 163 64 64 72 72 72 163 131 163 116 350 116 350 297 1983 1984 51 51 47 47 47 163 163 64 64 64 64 72 72 72 72 72 72 72 72 69 69 163 163 131 131 163 163 116 116 350 350 116 116 350 350 297 297 297 1985 51 47 47 163 64 64 72 72 72 72 69 163 125 163 116 350 116 350 297 297 1986 1987 1988 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 10 of 13)SALT RIVER PROJECT Table 1.1-8 51 51 51 47 47 47 Page 2 of 3 47 47 163 163 163 64 64 64 64 64 72 72 72 72 72 72 72 72 72 72 72 72 69 69 163 163 163 125 125 125 163 163 163 116 116 116 PRg APppyp~~~ARO 350 350 350 116 116 116 350 350 350 297 297 297 297 297 297 1.1-183/184 Blank 4%%w~wm xm~-Ac)SALT RIVER PROJECT 1.1.2 Power Supply (MW)Plant and Unit Kyrene¹4 Kyrene¹5 Kyrene¹6 Navajo¹1 Agua Fria¹5 Agua Fria¹6 Santan¹1 Santan¹2 Santan¹3 Santan¹4 Agua Fria¹4 Navajo¹2 Hayden¹2 Navajo¹3 Craig¹1 Coronado¹1 Craig¹2 Coronado¹2 Palo Verde¹1 Palo Verde¹2 Year Type Comb.Turb.Comb.Tu rb.Comb.Turb.Steam Comb.Turb.Comb.Turb.Com.Cycle Com.Cycle Com.Cycle Com.Cycle Com.Turb.Steam Steam Steam'team Steam Steam Steam Steam Steam Function Fuel Oil/Gas Peaking Oil/Gas Peaking Oil/Gas Coal Peaking Base Peaking Peaking Intermediate Intermediate Inter'mediate Intermediate Peaking Base Base Base Base Intermediate Base Intermediate Base Oil Oil Oil Oil Oil Oil Oil Coal Coal Coal Coal Coal Coal Coal Nuclear Nuclear Base 1968 1969 1970 1971 1972 56 1973 61 58 57 1974 1975 1976 48 61 61 58 58 42 57 57 42 163 163 163 64 64 66 64 64 66 73 72 73 72 73 72 73 72 70 163 163 163 1977 48 42 42 163 66 66 72 72 72 72 66 163 208 163 PVNGS ER-OL NEED FOR POWER 1976 1977 644 790 807 1,015 2, 152 2, 241 2,449 56 107 0 163 2,359 2,342 2,550 1978 644 790 1, 016 2,450 56 107 163 (62)(62)(62)(62)(62)(62)2,551 1979 1980 1981 657 657 657 794 1,284 1,284 1,017 1,133 1,249 2,468 3,074 3,190 56 56 56 107 107 107 163 163 163 (62)(62)(62)0 0 (62)(62)(62)2,569 3,175 3,291 1982 657 1,494 1,467 3,618 56 107 163 (62)(140)(202)3,579 1983 1984 1985 657 657 657 1,494 1,494 1,494 1,464 1,761 1 755 3 615 3 912 3 906 56 56 56 107 107 0 0 163 163 56 (62)(62)(62)(140)(70)(70)(202)(132)(132)3,576 3,943 3,830 1986 297 657 1,494 2,052 4,203 56 0 56 (62)(62)4,197 1987 1988 297 297 657 657 1,494 1,494 2,052 2,052 4, 203 4, 203 56 56 0 56 56 (62)(62)0 (62)(62)4,197 4,197 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 11 of 13)SALT RIVER PROJECT Table 1.1-8 Page 3 of 3 PRO~~Earuap CARD 1.1-185/186 Blank SALT RIVER PROJECT 1.1.2 Power Supply (MW)Plant and Unit Palo Verde¹3 Total Peaking Total Intermediate Total Base Installed Resources Nonfirm Purchases-Outside ANPP Arizona Power Authority Colorado-Ute Elec.Plains Electric G&T USBR-Navajo Layoff Nonfirm Purchases-Within ANPP Southern California Edison Total Nonfirm Purchases Nonfirm Sales-Outside ANPP Nonfirm Sales-Within ANPP Arizona Public Service Los Angeles Dept.of Water a Power Total Nonfirm Sales Capability (IR+NFP-NFS) Year Type Steam Fuel Nuclear Function Base 1968 112 498 610 50 85 135 (62)(62)683 1969 104 498 79 681 50 80 130 (62)(62)749 1970 101 498 159 758 50 74 124 (62)(62)820 1971 1972 1973 514 345 105 504 504 504 318 236 306 845 1, 155 1, 336 56 55 71 67 30 30 80 153 203 156 (62)(62)(62)0 (62)(62)(62)986 1,249 1,427 1974 642 504 481 1,627 56 50 85 221 (62)(62)1,786 1975 712 796 644 56 50 163 269 (62)(62)644 790 107 163 0 PVNGS ER-OL 1.1.2 Power Supply (MW)Plant and Unit TYpe Southern California Edison Company Year Fuel Function 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 NEED FOR POWER CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 12 of 13)SOUTHERN CALIFORNIA EDISON Table 1.1-8 Page 1 of 2 Big Creek Plant Portal Mammoth Pool Santa Ana Ontario Mill Creek Lytle Creek Kern-Borel Kern River Tule River Kaweah Fontana Sierra San Gorgonio Bishop Creek Lundy Rush Creek Poole Hoover-SCE Hoover-MWD Hydro Oroville-Thermal Edwards AFB Exch Vernon Gabbs Redondo 1-8 Highgrove 1-4 Etiwanda 1-4 El Segundo 1-4 Alamitos 1-6 San Bernardino 1 Huntington Beach Mandalay 1,2 Cool Water 1,2 Garden State San Onofre 1 Long Beach 10 Long Beach 11 Etiwanda 5 Huntington Beach Alamitos 7 r'to ange~2 1-4 Nuclear Steam Steam Comb.Comb.Comb.Turb.Turb.Turb.Hydro Hydro Hydro Hydro HYdro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Hydro Diesel Diesel Steam Steam Steam Steam Steam Steam Steam Steam Steam Comb.Turb.Oil Oil Oil Oil Oil Oil Oil Oil Oil Oil Oil Oil Nuclear Oil Oil Oil Oil Oil Intermediate Intermediate Intermediate Base Base Base Base Base Base Base Base Base Base Base Intermediate Intermediate Intermediate Intermediate Peaking Intermediate Intermediate Peaking Peaking Peaking Peaking Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Intermediate Base Intermediate Intermediate Peaking Peaking Peaking 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 277 310 0 0 0 20 6 1602 154 904 1020 1950 126 870 430 146 12 308 106 106 0 0 0 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 277 310 0 284 0 20 6 1602 154 904 1020 1950 126 870 430 146 12 308 106 106 121 121 121 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 277 310 0 296 0 20 6 1602 154 904 1020 1950 126 870 430 146 12 344 106 106 121 121 121 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 277 310 0 319 0 20 6 1602 154 904 1020 1950 126 870 430 146 12 344 106 106 121 121 121 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 277 310 0 319 0 20 6 1602 154 904 1020 1950 126 870 430 146 12 344 106 106 121 121 121 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 277 310 0 319 0 20 6 1602 154 904 1020 1950 126 870 430 146 12 344 106 106 121 121 121 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 277 310 0 319 0 0 0 1602 154 904 1020 1950 126 870 430 146 12 344 106 106 121 121 121 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 0 319 0 0 0 1602 154 904 1020 1950 126 870 430 146 12 344 50 50 121 121 121 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 0 326 0 0 0 1602 154 904 1020 1950 126 870 430 146 12 344 50 50 121 121 121 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 0 326 0 0 0 1602 154 904 1020 1950 126 870 430 146 12 349 106 50 121 121 121 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 0 326 0 0 0 1602 154 904 1020 1950 216 870 430 146 12 349 106 50 121 121 121 530 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 0 326 0 0 0 1602 154 904 1020 1950 126 870 430 146 12 349 106 106 121 121 121 561 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 0 326 0 0 0 1602 154 904 1020 1950 126 870 430 146 12 349 106 106 121 121 121 561 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 0 326 18 0 0 1602 154 904 1020 1950 126 870 430 146 12 349 106 106 121 121 121 561 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 0 326 18 0 0 1602 154 904 1020 1950 126 870 430 146 12 349 106 106 121 121 121 561 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 0 0 18 0 0 1602 154 904 1020 1950 126 870 430 146 12 349 106 106 121 121 121 561 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 0 0 18 0 0 1602 154 904 1020 1950 126 870 430 146 12 349 106 106 121 121 121 561 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 331 315 140 0 18 0 0 1602 154 904 1020 1950 126 870 430 146 12 349 106 106 121 121 121 561 10 150 7 1 1 10 61 2 9 2 1 2 29 3 10 10 331 315 140 0 0 0 0 1602 154 904 1020 1950 126 870 430 146 12 349 106 106 121 121 121 561 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 0 315 140 0 0 0 0 1602 154 904 561 10 150 7 1 4 1 10 61 2 9 2 1 2 29 3 10 10 0 315 140 0 0 0 0 1602 154 904 1020 1020 1950 126 870 430 146 12 349 106 106 121 121 121 1950 126 870 430 146 12 349 106 106 121 121 121 PRC APppyp~~Ching I2 1.1-187/188 Blank March 1981 Supplement 2 PVNGS ER-OL 1.1.2 Power Supply (MW)Plant and Unit Typ e Southern California Edison Company Year Fuel Function 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 19'79 1980 1981 1982 1983 1984 1985 1986 1987 1988 NEED FOR POWER CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 13 of 13)SOUTHERN CALIFORNIA EDISON Table 1.1-8 Mandalay 3 Four Corners 4 Four Corners 5 Mohave 1 Mohave 2 Ormond Beach 1 Ormond Beach 2 Navajo Layoff Ellwood Long Beach 1-9 Cool Water 3,4 Co-Generation San Onofre 2 San Onofre 3 Axis Steam Axis CT Palo Verde 1 Palo Verde 2 Palo Verde 3 Wind 1-4 Fuel Cells 1-19 Geothermal 1-4 Combined Cycle California Coal 1 California Coal 2 Combustion Turbines Palo Verde 4 Comb.Turb.Steam Steam Steam Steam Steam Steam Steam Comb.Turb.Comb.Cycle Comb.Cycle Co-Generation Nuclear Nuclear Steam Comb.Turb.Nuclear Nuclear Nuclear Wind Fuel Cell Geothez'mal Comb.Cycle Steam Steam Comb.Turb.Nuclear Oil Coal Coal Coal Coal Oil Oil Coal Coal Coal Coal Nuclear Nuclear Oil Oil Nuclear Nuclear Nuclear Oil Oil Coal Coal Oil Nuclear Peaking Base Base Base Base Intermediate Intermediate Base Peaking Intermediate Intermediate Base Base Base Intermediate Peaking Base Base Base Base Peaking Base Intermediate Base Base Peaking Base 121 373 373 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 121 373 373 426 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 121 373 373 426 494 750 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 121 373 373 426 426 750 750 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 121 373 373 442 443 750 750 95 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 121 373 373 442 443 750 750 196 54 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 121 373 373 442 443 750 750 319 54 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.121 373 373 442 443 750 750 319 54 490 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 121 373 373 442 443 750 750 319 54 490 360 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 121 373 373 442 443 750 750 319 54 543 468 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 121 373 373 442 443 750 750 312 54 543 468 24 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 121 373 373 442 443 750 750 266 54 543 468 28 176 0 25 22 0 0 0 0 0 0 0 0 0 0 0 121 366 366 442 443 750 750 263 54 543 468 32 880 176 25 22 187 0 0 0 0 0 0 0 0 0 0 121 366 366 442 443 750 750 263 54 543 468 37 880 880 25 22 187 0 0 1 26 0 0 0 0 0 0 121 366 366 442 443 750 750 263 54 543 468 41 880 880 25 22 187 187 0 1 26 9 0 0 0 0 0 121 366 366 442 443 750 750 0 54 543 468 45 880 880 25 22 187 187 0 1 26 9 540 0 0 0 0 121 366 366 442 443 750 750 0 54 543 468 49 880 880 25 22 187 187 188 3 78 63 850 0 0 0 0 121 366 366 442 443 750 750 0 54 543 468 53 880 880 25 22 187 187 188 8 130 108 1290 250 0 110 0 121 366 366 442 443 750 750 0 54 543 468 57 880 880 25 22 187 187 188 18 234 108 1290 250 250 110 412 Page 2 of 2 I2 Peaking Intermediate Base Load Adverse Year Hydro Derate Installed Resources 515 8266 408 (101)9088 950 8478 408 (112)9724 1083 8478 1190 (112)1106 8478 1616 (92)1106 9228 2110 (100)0639 11108 12344 1106 9978 2042 (100)13026 1086 9978 2170 (100)1188 9871 2271 (203)13134 13127 1195 9871 2394 (213)13247 1195 1195 1195 10417 10777 10994 2399 2399 2399 (213)(213)(213)13798 14158 14375 1195 1235 1235 11025 11050 11050 2416 2550 3604 (213)(213)(213)14423 14622 15676 935 11050 4314 (193)16106 935 935 969 11050 11730 12040 4514 4255 4503 (193)(193)(193)16306 16727 17319 800 12480 4807 (139)17948 904 1 2480 5483 (139)18728 Ppg PPp~Cgq~E 1.1-189/190 Blank March 1981 Supplement 2 ARIZONA Org.AEPC AEPC AEPC AEPC Apache CC 1, Apache CC 1, Apache GT 2, Apache GT 3, Cochise, AZ Cochise, AZ Cochise, AZ Cochise, AZ NEW MEXICO POWER AREA Thermal-Plant Name, Unit No., Location Hydro-Plant Name (No.of Units)Location Unit Type CA CT GT GT Summer Winter 75 10 20 63 75 10 20 63 New Capability (MW)Fuel Type F02 F02 F02 F02 Delivery Methods TK TK TK TK Primary Fuel Fuel Type NG NG MG NG Delivery Methods PL PL PL PL Alternate Fuel Thermal Unit Commercial Operation 1965 1965 1972 1974 Comments PVNGS ER-OL NEED FOR POWER Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 1 of 11 ARIZONA-NEW MEXICO POWER AREA (Page 1 of 4)APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS Childs (3), Camp Verde, AZ Irving (2), Camp Verde, AZ Cholla 1, Joseph City, AZ Cholla 2, Joseph City, AZ Douglas GT 1, Douglas, AZ Four Corners 1, Farmington, NM Four Corners 2, Farmington, NM Four Corners 3, Far'mington, NM Four Corners 5, Farmington, NM Phoenix CC 1, Phoenix, AZ Phoenix CC 1, Phoenix, AZ Phoenix CC 2, Phoenix, AZ Phoenix CC 2, Phoenix, AZ Phoenix CC 3, Phoenix, AZ Phoenix CC 3, Phoenix, AZ Phoenix 4, Phoenix, AZ Phoenix 5, Phoenix, AZ Phoenix 6, Phoenix, AZ Phoenix GT 1, Phoenix, AZ Phoenix GT 2, Phoenix, AZ'Ocotillo 1, Tempe, AZ Ocotillo 2, Tempe, AZ Ocotillo GT 1, Tempe, AZ Ocotillo GT 2, Tempe, AZ Saguaro 1, Red Rock, AZ Saguaro 2, Red Rock, AZ Saguaro GT 1, Red Rock, AZ Saguaro GT 2, Red Rock, AZ Tapco 1, Clarkdale, AZ Yuma 1, Yuma, AZ HY HY ST ST GT ST ST ST ST CS CT CW CT CY CT ST ST ST GT GT ST ST GT GT ST ST GT GT ST ST 4 1 116 235 21 175 177 220 800 24 51 24 51 24 51 33 12 63 56 56 115 115 56 56 115 99 55 55 0 75 4 1 116 235 21 175 177 220 800 24 51 24 51 24 51 33 12 63 56 56 115 115 56 56 115 99 55 55 0 75 WAT WAT SUB SUB F02 SUB SUB SUB SUB WH F02 WH F02 WH F02 F06 F06 F06 F02 F02 F06 F06 F02 F02 F06 F06 F02 F02 F06 F06 RR, TK RR,TK TK RR,TK RR,TK RR,TK RR,TK RR, TK RR, TK RR,TK RR,TK RR,TK RR~TK RR,TK RR,TK RR,TK RR,TK RR,TK RR,TK RR~TK RR,TK RR,TK RR~TK TK RR, TK None None Mone None None None None Top NG MG NG NG NG NG NG NG NG NG NG NG MG None RR,TK PL PL PL PL PL PL PL PL PL PL PL PL PL PL Top RR,TK Top RR,TK 1962 1978 1972 1963 1963 1964 1970 1976 1976 1976 1976 1976 1976 1948 1949 1950 1972 1973 1960 1960 1972 1973 1954 1955 1972 1973 1917 1959 Formerly called Fairview.APS 15%PNM 13%SRP 10%EPE 7%p TGE 7%~SCE 48%7 MW capability Not available Ownership: APS 33.3%, SCE 33 3%, IID 33 3%PRC"F'ER TuRE CARO APS APS APS Yuma GT 1, Yuma, AZ Yuma GT 2, Yuma, AZ Yuma GT 3, Yuma, AZ GT GT GT 22 22 57 22 22 57 F02 F02 F02 RR, TK RR,TK RR,TK MG NG NG PL PL PL 1971 1971 1973 1.1-191/192 Blank PVNGS ER-OL ARIZONA Org AEPC AEPC AEPC AEPC Apache CC 1, Apache CC 1, Apache GT 2, Apache GT 3, Cochise, AZ Cochise, AZ Cochise, AZ Cochise, AZ NEW MEXICO POWER AREA Thermal-Plant Name, Unit No., Location Hydro-Plant Name (No.of Units)Location Unit Type CA CT GT GT Summer Winter 75 10 20 63 75 10 20 63 New Capability (MW)Fuel Type F02 F02 F02 F02 Delivery Methods TK TK TK TK Fuel Type NG NG NG NG Delivery Methods PL PL PL PL Primary Fuel Alternate Fuel Thermal Unit Commercial Operation 1965 1965 1972 1974 Comments NEED FOR POWER Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 1 of 11 ARIZONA-NEW MEXICO POWER AREA (Page 1 of 4)APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS APS Childs (3), Camp Verde, AZ Irving (2), Camp Verde, AZ Cholla 1, Joseph City, AZ Cholla 2, Joseph City, AZ Douglas GT 1, Douglas, AZ Four Corners 1, Farmington, NM Four Corners 2, Farmington, NM Four Corners 3, Farmington, NM Four Corners 5, Farmington, NM Phoenix CC 1, Phoenix, AZ Phoenix CC 1, Phoenix, AZ Phoenix CC 2, Phoenix, AZ Phoenix CC 2, Phoenix, AZ Phoenix CC 3, Phoenix, AZ Phoenix CC 3, Phoenix, AZ Phoenix 4, Phoenix, AZ Phoenix 5, Phoenix, AZ Phoenix 6, Phoenix, AZ Phoenix GT 1, Phoenix, AZ Phoenix GT 2, Phoenix, AZ'Ocotillo 1, Tempe, AZ Ocotillo 2, Tempe, AZ Ocotillo GT 1, Tempe, AZ Ocotillo GT 2, Tempe, AZ Saguaro 1, Red Rock, AZ Saguaro 2, Red Rock, AZ Saguaro GT 1, Red Rock, AZ Saguaro GT 2, Red Rock, AZ Tapco 1, Clarkdale, AZ Yuma 1, Yuma, AZ HY HY ST ST GT ST ST ST ST CS CT CW CT CY CT ST ST ST GT GT ST ST GT GT ST ST GT GT ST ST 4 1 116 235 21 175 177 220 800 24 51 24 51 24 51 33 12 63 56 56 115 115 56 56 115 99 55 55 0 75 4 1 116 235 21 175 177 220 800 24 51 24 51 24 51 33 12 63 56 56 115 115 56 56 115 99 55 55 0 75 WAT WAT SUB SUB F02 SUB SUB SUB SUB WH F02 WH F02 WH F02 F06 F06 F06 F02 F02 F06 F06 F02 F02 F06 F06 F02 F02 F06 F06 RR, TK RR, TK TK RR,TK RR,TK RR,TK RR,TK RR, TK RR, TK RR~TK RR,TK RR,TK RR,TK RR,TK RR,TK RR,TK RR,TK RR,TK RR,TK RR,TK RR,TK RR,TK RR,TK TK RR,TK None None None None None None None Top NG NG NG NG NG NG NG NG NG NG NG NG NG None NG RR, TK PL PL PL PL PL PL PL PL PL PL PL PL PL Top RR,TK Top RR,TK 1962 1978 1972 1963 1963 1964 1970 1976 1976 1976 1976 1976 1976 1948 1949 1950 1972 1973 1960 1960 1972 1973 1954 1955 1972 1973 1917 1959 Formerly called Fairview.APS 15%PNM 13%SRP 10%>EPE 7%i TGE 7%SCE 48%7 MW capability Not available Ownership: APS 33.3%, SCE 33 3%IID 33 3%PRC~~ERTURE CARD APS APS APS Yuma GT 1, Yuma, AZ Yuma GT 2, Yuma, AZ Yuma GT 3, Yuma, AZ GT GT GT 22 22 57 22 22 57 F02 F02 F02 RR, TK RR,TK RR,TK NG NG NG PL PL PL 1971 1971 1973 1.1-191/192 Blank Org.Hydro-Plant Name (No.of Units)Location ARIZONA-NEW MEXICO POWER AREA Thermal-Plant Name, Unit No., Location Unit Type Summer Winter New Capability (MW)Fuel Type Delivery Methods Primary Fuel Fuel Type Delivery Methods Alternate Fuel Thermal Unit Commercial Operation Comments PVNGS ER-OL NEED FOR POWER Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 2 of 11 APS Yuma GT 4, Yuma, AZ Citizens 1-4, Nogales, AZ GT IC 56 56 F02 RR,TK F02 TK Top NG RR~TK PL 1974 1959 ARIZONA-NEW MEXICO POWER AREA (Page 2 of 4)EPE EPE EPE EPE EPE EPE EPE EPE EPE EPE EPE EPE EPE EPE Newman 1, El Paso, Newman 2, El Paso, Newman 3, El Paso, Newman 4, El Paso, Newman 4, El Paso, Newman 4, El Paso, Rio Grande 1, Near Rio Grande 2, Near Rio Grande 3, Near Rio Grande 4, Near Rio Grande 5, Near Rio Grande 6, Near Rio Grande 7, Near Rio Grande 8, Near TX TX TX TX TX TX El Paso, TX El Paso, TX El Paso, TX El Paso, TX El Paso, TX El Paso, TX El Paso, TX El Paso, TX ST ST ST CT CT CW ST ST ST ST ST ST ST ST 82 86 106 59 59 106 13 13 19 34 32 47 47 147 82 86 106 59 59 106 13 13 19 34 32 47 47 147 NG NG NG NG NG WH NG NG F04 F04 F04 F04 F04 F02 PL PL PL PL PL PL PL TK, RR TK~RR TK, RR TK, RR TK, RR TK, RR F04 F04 F04 F02 F02 F04 F04 NG NG NG NG NG NG TK TK TK TK TK TK, RR TK, RR PL PL PL PL PL PL 1960 1963 1969 1975 1975 1975 1930 1929 1949 1951 1954 1957 1958 1972 IID IID IID I ID IID I ID I ID I ID I ID IID I ID I ID IID IID IID PEGT PEGT PEGT Drop 2 (2), Holtville, CA Drop 3 (2), Holtville, CA Drop 4 (2), Holtville, CA Pilot Knob (2), Winterhaven, CA Brawley GT 1, Brawley, CA Brawley GT 2, Brawley, CA Brawley Diesel 1-8, Brawley, CA Coachella GT 1, Coachella, CA Coachella GT 2, Coachella, CA Coachella GT 3, Coachella, CA Coachella GT 4, Coachella, CA El Centro 1, El Centro, CA El Centro 2, El Centro, CA El Centro 3, El Centro, CA El Centro 4, El Centro, CA Los Alamos Station, Los Alamos, NM Algodones 1, Algodones, NM Algodones 2, Algodones, NM Algodones 3, Algodones, NM Las Vegas Unit 1, Las Vegas, NM HY HY HY HY GT GT IC GT GT GT GT ST ST ST ST ST ST ST ST GT 8 8 16 7 11 11 12 20 20 20 20 22 30 48 80 16 15 15 15 20 0 0 0 0 11 11 12 20 20 20 20 22 30 48 80 16 15 15 15 20 WAT WAT WAT WAT F02 F02 F02 F02 F02 F02 F02 F06 F06 F06 F06 NG NG NG TK TK TK TK TK TK TK TK TK TK TK PL PL PL PL PL None None None NG NG NG NG NG NG NG NG F02 F06 F06 F06 F02 PL PL PL PL PL PL PL PL TK TK TK TK TK 1962 1962 1939 1973 1973 1974 1977 1949 1952 1957 1968 1946 1954 1954 1959 1973 Minimum 14 MW total cap.Available from IID hydro gen According to 5 yr history PNM plans to test all units PRC APE CARg 1.1-193/194 Blank PVNGS ER-OL ARIZONA Org.PNM PNM PNM PNM PNM PNM PNN PNM PNM PNM PNM PNM PNN PNM Person Unit 1, Person Unit 2, Person Unit 3, Person Unit 4, Prager Unit 7, Prager Unit 8, Prager Unit 9, Reeves Unit 1, Reeves Unit 2, Reeves Unit 3, Santa Fe Unit Santa Fe Unit San Juan Unit San Juan Unit Albuquerque, NM Albuquerque, NN Albuquerque, NM Albuquerque, NN Albuquerque, NM Albuquerque, NM Albuquerque, NM Albuquerque, NM Albuquerque, MN Albuquerque, NM 1, Santa Fe, NM 2, Santa Fe, NM 1, Waterflow, NM 2, Waterflow, NM NEW MEXICO POWER AREA Thermal-Plant Name, Unit No., Location Hydro-Plant Name (No.of Units)Location Unit Type ST ST ST ST ST ST ST ST ST ST ST ST ST ST Summer Winter 18 18 28 32 6 5 11 50 50 75 5 6 314 306 18 18 28 32 6 5 11 50 50 75 5 6 314 306 New Capability (NW)Fuel Type MG NG NM NG MG NG NG NG NG NG MG NG BIT BIT Delivery Methods PL PL PL PL PL PL PL PL PL PL PL PL TK TK Primary Fuel Fuel Type F02 F02 F04 F04 F02 F02 F02 F04 F04 F04 F02 F02 None None Delivery Methods TK, RR, PL TK,RR,PL TK, RR TK, RR TK, RR TK, RR TK, RR TK, RR TK, RR TK, RR TK TK Alternate Fuel Thermal Unit Commercial Operation 1952 1953 1954 1957 1945 1947 1948 1960 1959 1962 1949 1949 1976 1973 Comments In the near future to obtain summer and winter ratings.This comment applies to all PMM units in this report.For the past 3 years, all fuel oil deliveries have been by tanker truck.This comment applies to units with rail and/or pipeline delivery methods in addition to trucking.San Juan 1 s 2 ownership. PNM 50%<TGE 50%Units rerated in 1978.NEED FOR POWER Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 3 of 11 ARIZONA-NEW MEXICO POWER AREA (Page 3 of 4)SCIP Coolidge Dam (2), Gila, Co., AZ 10 10 WAT SRP SRP SRP SRP SRP SRP SRP SRP SRP SRP SRP SRP SRP 8RP SRP SRP SRP SRP SRP SRP SRP SRP SRP Crosscut (1), Tempe, AZ Horse Mesa (1), Salt River, AZ Horse Mesa (3), Salt River, AZ Mormon Flat (1), Salt River, AZ Mormon Flat (1), Salt River, AZ Roosevelt (1), Salt River, AZ Stewart Mtn (1), Salt River, AZ Agua Fria 1, Glendale, AZ Agua Fria 2, Glendale, AZ Agua Fria 3, Glendale, AZ Agua Fria 4, Glendale, AZ Agua Fria 5, Glendale, AZ Agua Fria 6, Glendale, AZ Crosscut, Tempe, AZ Kyrene 1, Tempe, AZ Kyrene 2, Tempe, AZ Kyrene GT 3, Tempe, AZ Kyrene GT 4, Tempe, AZ Kyrene GT 5, Tempe, AZ Kyrene GT 6, Tempe, AZ Navajo 1, Page, AZ Navajo 2, Page, AZ Navajo 3, Page, AZ PS HY PS HY HY HY ST ST ST GT GT GT ST ST ST GT GT GT GT ST ST ST 96 33 44 10 36 13 109 109 180 66 66 66 32 34 70 48 48 42 42 750 750 750 96 30 44 10 36 0 111 111 182 69 69 69 32 34 70 60 60 53 53 750 750 750 WAT WAT WAT WAT WAT WAT WAT F06 F06 F06 F02 F02 F02 F02 F02 F02 F02 F02 F02 F02 SUB SUB SUB TK, RR TK, RR TK, RR TK,RR,PL TK,RR,PL TK,RR,PL TK,RR,PL TK, RR, PL TK,RR,PL TK,RR,PL TK,RR,PL TK,RR,PL TK,RR,PL RR,TK RR,TK RR,TK NG NG MG None None None NG NG NG NG MG NG NG None None None PL PL PL PL PL PL PL PL PL PL 1958 1957 1961 1975 1974 1974 1941 1952 1954 1972 1971 1973 1973 1974 1975 1976 Water supply not dependable for full 2 MW.Four 8 MW units Navajo 1, 2, 3 ownership: SRP 21 7%USBR 24 3%+LDWP 21 2%APS 14%g NEVP 11 3%~TGE 7.5%.PRC APER CARD 1.1-195/196 Blank NEED FOR POWER PVNGS ER-OL ARIZONA-NEW MEXICO POWER AREA Org.Thermal-Plant Name, Unit No., Location Hydro-Plant Name (No.of Units)Location Unit Type New Capability (MW)Summer Winter Fuel Type Delivery Methods Primary Fuel Fuel Type Delivery Methods Alternate Fuel Thermal Unit Commercial Operation Comments Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 4 of 11 SRP SRP SRP SRP SRP SRP SRP SRP San Tan San Tan San Tan San Tan San Tan San Tan San Tan San Tan 1, Gilbert, AZ 1, Gilbert, AZ 2, Gilbert, AZ 2, Gilbert, AZ 3, Gilbert, AZ 3, Gilbert, AZ 4, Gilbert, AZ 4, Gilbert, AZ CW CT CW CT CW CT CW CT 24 48 24 48 24 48 24 48 26 52 26 52 26 52 26 52 WH F02 WH F02 WH F02 WH F02 TK,RR,PL None TK,RR,PL None TK,RR,PL None TK,RR,PL None 1974 1974 1974 1974 1974 1974 1975 1975 ARIZONA-NEW MEXICO POWER AREA (Page 4 of 4)TGE TGE TGE TGE TGE TGE TGE TGE TGE TGE TGE TGE TGE TGE TGE TGE Demoss Petrie 1, Tucson, AZ Demoss Petrie 2, Tucson, AZ Demoss Petrie 3, Tucson, AZ Demoss Petrie 4, Tucson, AZ Demoss Petrie GT 1, Tucson, AZ Irvington 1, Tucson, AZ Irvington 2, Tucson, AZ Irvington 3, Tucson, AZ Irvington 4, Tucson, AZ Irvington GT 1, Tucson, AZ Irvington GT 2, Tucson, AZ Irvington GT 3, Tucson, AZ North Loop GT 1, Marana, AZ North Loop GT 2, Marana, AZ North Loop GT 3, Marana, AZ North Loop GT 4, Marana, AZ ST ST ST ST GT ST ST ST ST GT GT GT GT GT GT GT 15 13 24 46 47 81 81 104 156 24 25 25 25 25 23 25 15 13 24 46 47 81 81 104 156 24 25 25 25 25 23 25 F06 F06 F06 F06 F02 F06 F06 F06 F06 F02 F02 F02 F02 F02 F02 F02 RR,TK RR,TK RR,TK RR,TK RR,TK,PL RR,TK,PL RR~TK,PL RR,TK,PL RR,TK,PL RR,TK,PL RR,TK,PL RR,TK,PL TK TK TK TK NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL 1949 1949 1953 1954 1973 1958 1960 1962 1967 1972 1972 1973 1972 1972 1972 1973 USLC USLC USLC USSW Davis (5), Bullhead City, AZ Hoover A3 a A4 (2), Boulder City, NV Parker (4), Parker, AZ Elephant Butte (3), T.or C.NM 268 165 HY 104 15 268 165 104 15 WAT WAT Revised operating limit operated by LDWP for Arizona Power Authority Operated by USBR;USBR-52 MW, MWD-52 MW PRC APERTURE caaD g~c%~M~xsE 1.1-197/198 Blank PVNGS ER-OL SOUTHERN CALIFORNIA -NEVADA POWER AREA NEED FOR POWER Org.BURB BURB BURB BURB BURB BURB BURB Magnolia Magnolia Magnolia Olive 1, Olive 2, Olive 3, Olive 4, 3, Burbank, CA 4, Burbank, CA 5, Burbank, CA Burbank, CA Burbank, CA Burbank, CA Burbank, CA Thermal-Plant Name, Unit No., Location Hydro-Plant Name (No.of Units)Location Unit Type ST ST GT ST ST GT GT Summer Winter 21 28 22 46 53 24 31 21 28 22 46 53 24 31 Net Capability (MW)Fuel Type Delivery Methods F06 F06 F06 F06 JF JF TK TK TK TK TK TK TK Primary Fuel Fuel Type Delivery Methods NG NG NG NG NG NG NG PL PL PL PL PL PL PL Alternate Fuel Thermal Unit Commercial Operation 1949 1953 1970 1959 1964 1974 1976 Comments Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 6 of 11 SOUTHERN CALIFORNIA -NEVADA POWER AREA (Page 1 of 6)CDWR Devil Canyon (2), San Bernardino, CA 120 120 WAT GLEN GLEN GLEN GLEN GLEN GLEN GLEN GLEN Grayson 1, Grayson 2, Grayson 3, Grayson 4, Grayson 5, Grayson 6, Grayson 7, Grayson 8, Glendale, CA Glendale, CA Glendale, CA Glendale, CA Glendale, CA Glendale, CA Glendale, CA Glendale, CA CW CW ST ST ST GT GT CT 11 12 21 47 49 23 30 75 11 12 21 47 49 23 30 75 WH WH F06 F06 F06 F02 F02 F02 TK TK TK TK TK TK NG NG NG NG NG NG PL PL PL PL PL PL 1941 1947 1953 1959 1964 1972 1975 1977 LDWP Aqueduct (12), Saugus, CA 74 74 San Francisqui o 1 s, 2, San Fernando, Foothill, and Franklin power plants LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP Castaic (7), Castaic, CA Hoover (8), Boulder City, NV Harbor Harbor Harbor Harbor Harbor Harbor Harbor Harbor Harbor 1, Wilmington, CA 2, Wilmington, CA 3, Wilmington, CA 4, Wilmington, CA 5, Wilmington, CA 6, Wilmington, CA 7, Wilmington, CA 8, Wilmington, CA 9, Wilmington, CA Owens Gorge (3), Bishop, CA Owens Valley (7), Big Pine, CA PS HY ST ST ST ST ST GT GT GT GT 1247 755 110 9 72 67 86 86 87 19 19 19 19 1247 755 110 9 72 67 86 86 87 19 19 19 19 WAT WAT WAT WAT F06 F06 F06 F06 F06 F02 F02 F02 F02 TK, PL,WA TK, PL~WA TK, PL,WA TK~PL,WA TK,PL,WA TK,PL TK,PL TK~PL TK,PL NG NG NG NG NG NG NG NG NG PL PL PL PL PL PL PL PL PL 1944 1948 1949 1949 1949 1972 1972 1972 1972 Units Al, A2, A9 located in Arizona, Nl-N4&NB located in Nevada operated by LDWP.SNEV 189 MW, USBC 20 MW, BURB 5 MW, GLEN 18 MW, PASA 11 MW, balance to LDWP.Haiwee, Cottonwood, Division Creek, Big Pine and Pleasant Valley power plants PRC APERTURE CARD 1.1-201/202 Blank PVNGS ER-OL Org.Hydro-Plant Name (No.of Units)Location LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP LDWP Haynes 1, Long Beach, Haynes 2, Long Beach, Haynes 3, Long Beach, Haynes 4, Long Beach, Haynes 5, Long Beach, Haynes 6, Long Beach, Scattergood 1, Playa Scattergood 2, Playa Scattergood 3, Playa Valley 1, Sun Valley, Valley 2, Sun Valley, Valley 3, Sun Valley, Valley 4, Sun Valley, CA CA CA CA CA CA del Rey, CA del Rey, CA del Rey, CA CA CA CA CA SOUTHERN CALIFORNIA -NEVADA POWER AREA Thermal-Plant Name,.Unit No., Location Unit Type ST ST ST ST ST ST ST ST ST ST ST ST ST Summer Winter 222 232 220 227 344 344 179 17.9 284 94 101 171 160 222 23 2 220 227 344 344 179 179 284 94 101 171 160 Net Capability (MW)Fuel Type F06 F06 F06 F06 F06 F06 F06 F06 NG F06 F06 F06 F06 Delivery Methods TK, PL,WA TK,PL,WA TK,PL,WA TK,PL,WA TK,PL,WA TK,PL,WA TK,PL TK,PL PL TK, RR TK, RR TK, RR TK, RR Fuel Type NG NG NG NG NG NG NG NG None NG NG NG NG Delivery Methods PL PL PL PL PL PL PL PL PL PL PL PL Primary Fuel Alternate Fuel Thermal Unit Commercial Operation 1962 1963 1964 1964 1966 1967 1958 1959 1974 1954 1954 1955 1956 Comments NEED FOR POWER Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 7 of 11 SOUTHERN CALIFORNIA -NEVADA POWER AREA (Page 2 of 6)Hoover (3), Boulder City, NV HY 261 261 Units N5, N6, and N7 owned by USBR and operated by LDWP NEVP NEVP NEVP NEVP NEVP NEVP NEVP NEVP NEVP NEVP PASA PASA PASA PASA PASA PASA PASA PASA Clark 1, Las Vegas, NV Clark 2, Las Vegas, NV Clark 3, Las Vegas, NV Clark 4, Las Vegas, NV Reid Gardner 1, Moapa, NV Reid Gardner 2, Moapa, NV Reid Gardner 3, Moapa, NV Sunrise 1, Las Vegas, NV Sunrise 2, Las Vegas, NV Westside Diesels, Las Vegas, NV Azusa Dam (1), Azusa, CA Broadway 1, Pasadena, CA Broadway 2, Pasadena, CA Broadway 3, Pasadena, CA Glenarm 8, Pasadena, CA Glenarm 9, Pasadena, CA Glenarm 1, Pasadena, CA Glenarm 2, Pasadena, CA ST ST ST GT ST ST ST ST GT IC HY ST ST ST ST ST GT GT 48 72 73 59 110 110 110 83 69 30 2 45 45 71 14 45 26 26 48 72 73 59 110 110 110 83 69 30 2 45 45 71 14 45 26 26 NG NG NG NG BIT BIT BIT NG NG F02 WAT F06 F06 F06 F06 F06 F02 F02 PL PL PL PL RR RR RR PL PL TK TK TK TK TK TK TK TK F06 F06 F02 F02 F02 F02 F02 F06 F02 None NG NG NG NG NG NG NG TK TK TK TK TK, RR TK, RR TK, RR TK, RR TK PL PL PL PL PL PL PL 1955 1956 1961 1973 1965 1968 1976 1964 1974 1963 1954 1957 1965 1932 1949 1976 1976 PRC APERTURE CARD 1.1-203/204 Blank N Org.SCE Thermal-Plant Name, Unit No., Location Hydro-Plant Name (No.of Units)Location Median Year Adjustment SOUTHERN CALIFORNIA -NEVADA POWER AREA Unit Type New Summer-41 Winter-82 Capability (MW)Fuel Type Delivery Methods Fuel Type Delivery Methods Primary Fuel Alternate Fuel Thermal Unit Commercial Operation Comments Edison does not have summer/winter median year capacity data by plants as individual plant capacity varies in response to maintenance sched-ules and water diversions. Nameplate ratings are reported.PVNGS ER-OL NEED FOR POWER Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 8 of 11 SOUTHERN CALIFORNIA -NEVADA POWER AREA (Page 3 of 6)SCE SCE SCE 8CE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE Big Creek No.1 (4), Big Creek, CA Big Creek No.2 (4), Big Creek, CA Big Creek No.2A (2), Big Creek, CA Big Creek No.3 (4), Big Creek, CA Big Creek No.4 (2), Big Creek, CA Big Creek No.8 (2), Big Creek, CA Bishop Creek No.2 (3), Bishop, CA Bishop Creek No.3 (3), Bishop, CA Bishop Creek No.4 (5), Bishop, CA Bishop Creek No.5 (2), Bishop, CA Bishop Creek No.6 (1), Bishop, CA Borel (3), Kernville, CA Fontana (2), San Bernardino, CA Hoover (4), Boulder City, NV Kaweah No.l (1), Three Rivers, CA Kaweah No.2 (1), Three Rivers, CA Kaweah No.3 (2), Three Rivers, CA Kern R.1 (4), Bakersfield, CA Kern R.3 (2), Bakersfield, CA Lower Tule (2), Springville, CA Lundy (2), Lee Vining, CA Lytle Cr.(2), San Bernardino, CA Mammoth Pool (2), Big Creek, CA Mill Creek No.l (1), Redlands, CA Mill Creek No.2 (1), Redlands, CA Mill Creek No.3 (3), Redlands, CA Ontario No.l (3), Ontario, CA Ontario No.2 (1), Ontario, CA Pool (1), Lee Vining, CA Portal (1), Big Creek, CA Rush Creek (2), Lee Vining, CA San Gorgonio No.l (1),Banning, CA HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY HY 81 66 96 138 91 58 7 8 8 4 2 10 2 331 2 2 4 25 36 2 3 1 150 1 1 2 1 1 10 10 10 1 81 66 96 138 91 58 7 8 8 4 2 10 2 331 2 2 4 25 36 2 3 1 150 1 1 2 1 1 19 10 10 1 WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT WAT A5 95MWg A6 95MWf A7 95MW~A8-46NW.Units owned by USBR and operated by SCE PRC APERTURE CARD 1.1-205/206 Blank PVNGS ER-OL SOUTHERN Org.SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE CALIFORNIA -NEVADA POWER AREA Thermal-Plant Name, Unit No., Location Hydro-Plant Name (No.of Units)Location San Gorgonio No.2 (1), Banning, CA Santa Ana No.1 (4), Redlands, CA Santa Ana No.2 (2), Redlands, CA Santa Ana No.3 (1), Redlands, CA Sierra (2), Ontario, CA Alamitos 1, Long Beach, CA Alamitos 2, Long Beach, CA Alamitos 3, Long Beach, CA Alamitos 4, Long Beach, CA Alamitos 5, Long Beach, CA Alamitos 6, Long Beach, CA Alamitos 7, Long Beach, CA Cool Water 1, Dagget,'A Cool Water 2, Dagget, CA Cool Water 3 CC, Dagget, CA Cool Water 3 CC, Dagget, CA Cool Water 4 CC, Dagget, CA Cool Water 4 CC, Dagget, CA Ellwood 1, Santa Barbara, CA El Segundo 1, El Segundo, CA El Segundo 2, El Segundo, CA El Segundo 3, El Segundo, CA El Segundo 4, El Segundo, CA Etiwanda 1, Etiwanda, CA Etiwanda 2, Etiwanda, CA Etiwanda 3, Etiwanda, CA Etiwanda 4, Etiwanda, CA Etiwanda 5, Etiwanda, CA Garden State 1, Pomona, CA Highgrove 1, Colton, CA Highgrove 2, Colton, CA Highgrove 3, Colton, CA Highgrove 4, Colton, CA Huntington Beach 1, Hunt.Bch, CA Huntington Beach 2, Hunt.Bch, CA Huntington Beach 3, Hunt.Bch, CA Huntington Beach 4, Hunt.Bch, CA Huntington Beach 5,'Hunt.Bch, CA Long Beach 8 CC, Long Beach, CA Long Beach 8 CC, Long Beach, CA Long Beach 9 CC, Long Beach, CA Long Beach 9 CC, Long Beach, CA Unit Type HY HY HY HY HY ST ST ST ST ST ST GT ST ST CT CA CT CA GT ST ST ST ST ST ST ST ST GT GT ST ST ST ST ST ST ST ST GT CT CW CT CW Summer Winter 1 4 1 2 1 175 175 320 320 480 480 121 65 81 120 60 120 60 54 175 175 335 335 132 132 320 320 121 12 32 33 44 45 215 215 215 225 121 200 79 150 60 1 4 1 2 1 175 175 320 320 480 480 121 65 81 120 60 120 60 54 175 175 335 335 132 132 320 320 121 12 32 33 44 45 215 215 215 225 121 200 82 150 60 New Capability (MW)Fuel Type WAT WAT WAT WAT WAT F04 F04 F04 F04 F04 F04 F02 F04 F04 F02 F02 F02 F02 F02 F04 F04 F04 F04 F04 F04 F04 F04 F02 F02 F04 F04 F04 F04 F04 F04 F04 F04 F02 F02 WH F02 WH Delivery Methods PL PL PL PL PL PL TK TK TK TK TK TK TK TK PL PL PL PL PL PL PL PL TK TK TK TK TK TK PL,WA PL,WA PL,WA PL,WA TK TK TK Fuel Type NG NG NG NG NG NG NG NO NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG NG Delivery Methods PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL Primary Fuel Alternate Fuel Thermal Unit Commercial Operation 1956 1957 1961 1962 1966 1966 1969 1961 1964 1978 1978 1978 1978 1974 1955 1956 1964 1965 1953 1953 1963 1963 1969 1967 1952 1952 1953 1955 1958 1958 1961 1961 1969 1976 1976 1977 1977 Comments Two 60MW Units Two 60MW Units Four 50MW Units Three 50MW Units NEED FOR POWER Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 9 of 11 SOUTHERN CALIFORNIA -NEVADA POWER AREA (Page 4 of 6)PRO APERTURE CARD 1.1-207/208 Blank PVNGS ER-OL SOUTHERN CALIFORNIA -NEVADA POWER AREA NEED FOR POWER Org.SCE SCE SCE SCE SCE SCE SCE Thermal-Plant Name, Unit No., Location Hydro-Plant Name (No.of Unrts)Location Long Beach 10, Long Beach, CA Long Beach 11, Long Beach, CA Mandalay 1, Oxnard, CA Mandalay 2, Oxnard, CA Mandalay 3, Oxnard, CA Mohave 1, Lauflin, NV Mohave 2, Lauflin, NV Unit Type ST ST ST HT GT ST ST Summer Winter 106 50 215 215 121 790 790 106 50 215 215 121 790 790 New Capability (MW)Primary Fuel Fuel Type F04 F04 F04 F04 F02 BIT BIT PL,WA PL,WA WA WA TK PL PL Delivery Methods Fuel Type NG NG NG NG NG NG NG Delivery Methods PL PL PL PL PL PL PL Alternate Fuel Thermal Unit Commercial Operation 1928 1930 1959 1959 1970 1971 1971 Comments Mohave i&2 Ownership: SCE 56%, LDWP 20%, NEVP 14%, SRP 10%.Coal is delivered by slurry pipeline.Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 10 of 11 SOUTHERN CALIFORNIA -NEVADA POWER AREA (Page 5 of 6)SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SCE SDGE SDGE SDGE SDGE SDGE SDGE EDGE SDGE EDGE EDGE EDGE EDGE SDGE EDGE EDGE EDGE EDGE EDGE EDGE Oxnard, CA Oxnard, CA Redondo Bch, CA Redondo Bch, CA Redondo Bch, CA Redondo Bch, CA Redondo Bch, CA Redondo Bch, CA Redondo Bch, CA Redondo Bch, CA 1, San Bern., CA 2, San Bern., CA an Clemente, CA Ormond Beach 1, Ormond Beach 2, Redondo Beach 1 Redondo Beach 2 Redondo Beach 3 Redondo Beach 4 Redondo Beach 5 Redondo Beach 6 Redondo Beach 7 Redondo Beach 8 San Bernardino San Bernardino San Onofre 1, S Division GT 1, San Diego, CA El Cajon GT 1, El Cajon, CA Encina 1, Carlsbad, CA Encina 2, Carlsbad, CA Encina 3, Carlsbad, CA Encina 4, Carlsbad, CA Encina 5, Carlsbad, CA Encina GT 1, Carlsbad, CA Kearny GT 1, San Diego, CA Kearny GT 2(ABCD), San Diego, CA Kearny GT 3(ABCD), San Diego, CA Miramar GT 1(AB), San Diego, CA Naval Station GT 1, San Diego, CA North Island GT 1, Coronado, CA North Island GT 2, Coronado, CA NTC GT 1, San Diego, CA Silver Gate 1, San Diego, CA Silver Gate 2, San Diego, CA Silver Gate 3, San Diego, CA ST ST ST ST ST ST ST ST ST ST ST ST NP GT GT ST ST ST ST ST GT GT GT GT GT GT GT GT GT ST ST ST 750 750 74 74 70 74 175 175 480 480 63 63 436 16 17 100 102 102 287 320 16 17 65 65 38 25 21 20 16 38 64 64 750 750 74 74 70 74 175 175 480 480 63 63 436 20 21 100 102 102 287 320 20 21 81 81 46 32 23 23 20 38 64 64 F04 F04 F04 F04 F04 F04 F04 F04 F04 F04 F04 F04 UR F02 F02 F06 F06 F06 F06 F06 F02 F02 F02 F02 F02 F02 F02 F02 F02 F02 F02 F02 WA WA PL PL PL PL PL PL PL PL TK TK TK TK WA WA WA WA WA TK TK TK TK TK TK TK TK TK PL PL PL NG NG NG NG NG NG NG NG NG NG NG NG NONE NG NG NG NG NG NONE NG NG NG NG NG NONE NONE NONE NG NG NG NG PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL PL 1971 1973 1948 1948 1949 1949 1954 1957 1967 1967 1957 1958 1968 1968 1968 1954 1956 1958 1973 1978 1968 1972 1969 1969 1972 1976 1972 1972 1968 1943 1948 1950 Ownership: 80%SCE, 20%EDGE PRC APERTURE(CARD 1.1-209/210 Blank PVNGS ER-OL Org.Thermal-Plant Name, Unit No., Location Hydro-Plant Name (No.of Units)Location SDGE BDGE SDGE SDGE SDGE SDGE SDGE Silver Gate 4, San Diego, CA South Bay 1, Chula Vista, CA South Bay 2, Chula Vista, CA South Bay 3, Chula Vista, CA South Bay 4, Chula Vista, CA South Bay GT 1, Chula Vista, CA Station B, San Diego, CA SOUTHERN CALIFORNIA -NEVADA POWER AREA Unit Type ST ST ST ST ST GT ST Summer Winter 64 140 142 198 220 18 87 64 140 142 198 220 22 87 New Capability (MW)Fuel Type F02 F06 F06 F06 F06 JF F02 Delivery Methods PL WA WA WA WA TK PL Primary Fuel Fuel Type NG NG NG NG NG None NG Delivery Methods PL PL PL PL PL Alternate Fuel Thermal Unit Commercial Operation 1952 1960 1962 1964 1971 1966 1941 Comments Header plant with 4 main turbogenerators and 1 house turbogenerator. Capability shown is boiler limited NEED FOR POWER Table 1.1-9 WESTERN SYSTEMS COORDINATING COUNCIL EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 Sheet 11 of 11 SOUTHERN CALIFORNIA -NEVADA POWER AREA (Page 6 of 6)SNEV SNEV Stauffer Chemical, Henderson, NV Stauffer Chemical, Henderson, NV ST GT 10 15 10 15 NG NG PL PL F02 F02 TK,RR TK,RR 1970 1970 PRC APERTURE CARD 1.1-211/212 Blank PVNGS ER-OL ARIZONA-NEW MEXICO POWER AREA AEPC IID IID IID Apache 2, Cochise AZ Brawley GT 1, Brawley CA Brawley GT 2, Brawley CA Magma GEO 1, Holtville CA SCE AEPC SRP Axis GT 1, Yuma AZ Apache 3, Cochise AZ Coronado 1, St.Johns AZ Org.Plant Name, Unit No., Location Unit Type ST GT GT GE GT ST ST Summer Winter 175-2-2 10 175 10 22 175 350 22 175 350 Net Capability (MW)Fuel Type Deliv.Method SUB FO2 FO2 GST RR,TK TK TK PL FO2 SUB SUB TK RR,TK RR Primary Fuel Alt.Fuel Type None None None NG None None 6-78 Yes 1-79 1-79 1-79 4-79 4-79 4-79 4-79 No No Yes 4-79 4-79 6-79 Commercial Operation Date Prev.New Date Stat E D D G G G G Comments Testing delay.Capability change summer only Capability change summer only IID will purchase and sell KWH of plant SCE Main system 4-1-81 Participation unit until 5-82, SRP 70%, LDWP 30%NEED FOR POWER Table 1.1-10 WESTERN SYSTEMS COORDINATING COUNCIL

SUMMARY

OF GENERATION ADDITIONS Sheet 1 of 5 ARIZONA-NEW MEXICO POWER AREA (Page 1 of 2)IID PNM PNM SRP Rockwood GT 1, Brawley CA San Juan 3, Waterflow NM Prager 7&8, Albuquerque NM Coronado 2, St.Johns AZ GT ST ST ST 20 480-11 350 20 480-11 350 FO2 BIT NG SUB TK TK PL RR None None FO2 None 6-79 5-79 5-79 4-80 No 6-79 Yes 11-79 Yes 11-79 No 4-80 T G R T Joint project;PNM 50%and TGE 50'4 Retiring 2 units Participation unit until 5-82, SRP 70%, LDWP 30%EPE APS IID IID APS PNM PNM PNM APS APS APS PEGT APS IID EPE PEGT APS APS APS Copper Station 1, El Paso TX Cholla 3, Joseph City AZ Geothermal 1, CA Rockwood GT 2, Brawley CA Cholla 4, Joseph City AZ San Juan 3, Waterflow NM San Juan 4, Waterflow NM Prager 9, Albuquerque NM Palo Verde 1, Wintersburg AZ Four Corners 4, Farmington NM Four Corners 5, Farmington NM Combustion Turbine, NM Undetermined, AZ Geothermal 2, CA Rio Grande 1&2, near El Paso TX Escalante 1, Pruit NM Palo Verde 2, Wintersburg AZ Undetermined, AZ Undetermined, AZ GT ST GE GT ST ST ST ST NP ST ST GT GT GE ST ST NP GT GT 73 242 50 20 347-12 472-11 1270-15-15 50 50 50-26 210 1270 50 50 73 242 50 20 347-12 472-11 1270-15-15 50 50 50-26 210 1270 50 50 FO2 SUB GST FO2 SUB BIT BIT NG UR SUB SUB FO2 FO2 GST FO2 BIT UR FO2 FO2 PL RR, TK TK RR, TK TK TK PL RR,TK RR,TK TK RR,TK TK, RR RR RR,TK RR,TK NG None None None None None FO2 None None None None None NG None None None None 5-80 6-79 6-80 6-80 6-80 5-81 5-81 No Yes No No Yes Yes Yes 5-81 5-82 Yes No 7-82 1-83 No No 6-83 5-83 No Yes 5-84 No 5-80 6-80 6-80 6-80 6-81 5-82 5-82 5-82 5-82 7-82 1-83 5-83 5-83 6-83 1-84 5-84 5-84 5-85 5-85 P G P P G D T R T D D P P P R P T Reduced load forecast Plant site is undetermined Reduced load forecast.Addition of SO2 equipment Unit will come on-line with S02 equipment Retiring 1 unit Participation: APS 29.1%SCE 15.8%, SRP 23.4%, LDWP 5.7%, EPE 15.8%,&PNM 10.2%Scrubber derating Scrubber derating Peaking unit Plant site is undetermined Retiring 2 units Participation: APS 29.1%SCE 15.8%, SRP 23.4%, LDWP 5 7%~EPE 15 8%~&PNM 10 2%Peaking unit Peaking unit PRG gppp,JURE CARD 1.1-213/214 Blank PVNGS ER-OL Org.Plant Name, Unit No., Location TGE APS Springerville 1, AZ Palo Verde 3, Wintersburg, AZ IID PNM PNM Geothermal 3, CA Santa Fe 1&2, Santa Fe, NM Pumped Storage Plant, NM ARIZONA-NEW MEXICO POWER AREA Unit Type ST NP GE ST PS Summer Winter 330 1,270 330 1,270 50-11 300 50-11 300 Net Capability (MW)Fuel Type Deliv.Method SUB UR RR GST NG WAT PL Primary Fuel Alt.Fuel Type NONE NONE FO2 Prev.New Date Stat 5-85 5-85 NO NO 5-85 T 5-85 T 6-86 5-86 5-85 NO 6-86 P YES 10-86 R YES 5-87 P Commercial Operation Date Comments Participation: APS 29.1%, SCE 15.8%, SRP 23.4%, LDWP 5.7%, EPE 15.8%,&PNM 10.2%Plant site is undetermined Retiring 2 units Location, Number and size of units not yet determined NEED FOR POWER Table 1.1-10 WESTERN SYSTEMS COORDINATING COUNCIL

SUMMARY

OF GENERATION ADDITIONS Sheet 2 of 5 ARIZONA-NEW MEXICO POWER AREA (Page 2 of 2)TGE PNM PNM PNM PEGT APS IID Springerville 2, AZ New Mexico Station, Bisti, NM Person 1&2, Albuquerque, NM Pumped Storage Plant, NM Escalante 2, Pruit, NM Palo Verde 4, Wintersburg, AZ Geothermal 4, CA ST ST ST PS ST NP GE 330 472-36 300 210 1,270 50 330 472-36 300 210 1,270 50 SUB BIT RR TK NG WAT BIT UR PL RR GST PL NONE NONE F02 NONE NONE 5-83 YES 6-87 P 5-88 P 5-88 R 5-88 P 5-88 P 5-88 K 6-88 P Joint Project-50% PNM, 15.7%EPE&34.3%not allocated Retiring 2 units Planned addition Participation: APS 39.1%, EPE 4.0%, SCE 32.3%, LDWP 11.78, SDGE 5.2%, NEVP 2.2%, ANHM 1.5%, BURB 1%, GLEN 1%, PASA 1%, and RVSD 1%.Plant site is undetermined PRC APER CARD 1.1-215/216 Blank PVNGS ER-OL SOUTHERN CALIFORNIA -NEVADA POWER AREA NEED FOR POWER Org.PASA MWD SCE SCE SCE SCE NEVP NEVP SCE Plant Name, Unit No., Location Glenarm 8, Pasadena, CA Greg Ave 1, Burbank, CA Cool Water 3CC, Dagget, CA Cool Water 4CC, Dagget, CA Long Beach SCC, Long Beach, CA Long Beach 9CC, Long Beach, CA Clark 5, Las Vegas, NV Clark 6, Las Vegas, NV Long Beach No.ll, Long Beach, CA Unit TYpe ST HY CT CT CT CT GT GT ST Summer-14 1 Winter-14 1+54+54+31+22 70 70+56+69+69+38+27 70 70+56 Net Capability (MW)Fuel Type F06 WAT Deliv.Method TK F02 F02 F02 F02 NG NG F06 TK TK TK TK PL PL PL Primary Fuel Alt.Fuel Type NG NG NG NG NG F02 F02 NG 7-78 10-78 6-78 6-78 6-79 6-79 1-79 YES YES YES YES NO NO YES 1-7 9 4-79 6-79 6-79 6-7 9 6-79 6-7 9 6-7 9 7-79 M T A A A A G G A Commercial Operation Date New Date Stat Prev.Comments Retire from service Conduit Hydro, nameplate rating Rerate of GT portion Rerate of GT portion Rerate unit from 50MW to 106MW Table 1.1-10 WESTERN SYSTEMS COORDINATING COUNCIL

SUMMARY

OF GENERATION ADDITIONS Sheet 3 of 5 SOUTHERN CALIFORNIA -NEVADA POWER AREA (Page 1 of 3)SCE MWD Big Creek 3 Unit 5, Big Creek, CA Lake Mathews 1, Arlington, CA HY HY 31 5 31 5 WAT WAT 3-80 3-80 NO NO 3-80 3-80 Conduit Hydro, nameplate rating SCE MWD MWD NEVP SCE Co-Generation, CA Foothill FDR 1, L.A., CA Foothill FDR 2, L.A., CA zz HY HY Clark 7, Las Vegas, NV San Onofre 2, San Clemente, CA GT NP San Dimas 1, La Verne, CA HY Sepulveda Canyon 1, L.A., CA HY Yorba Linda FDR 1,Yorba Linda, CA HY 24 5 70 220 10 24 5 70 220 10 WH WAT WAT NG UR WAT WAT WAT PL F02 7-80 7-80 6-80 10-80 11-80 3-81 5-81 YES 6-80 6-80 YES 6-80 P NO 6-80 NO 10-80 K G YES 10-80 P YES 2-81 P NO 5-81 P Conduit Hydro, nameplate rating Conduit Hydro, nameplate rating Formerly Sunrise 3 Operation 20%of full power Ownership: 80%SCE, 20%SDGE Conduit Hydro, nameplate rating Conduit Hydro, nameplate rating Conduit Hydro, nameplate rating SCE NEVP MWD SCE SCE CDWR CDWR SCE Co-Generation, CA Clark 8, Las Vegas, NV Venice 1, Culver City, CA San Onofre 2, San Clemente, CA Temescal, NR Corona, CA San Onofre 3, San Clemente, CA Pyramid 2, Caswell, CA Pyramid 1, Caswell, CA Corona, NR Corona, CA Co-Generation, CA zz GT HY NP HY NP HY HY HY zz 4 70 10+880 220 38 38 4 70 10+880 220 38 38 WH NG WAT UR WAT UR WAT WAT WAT WH PL F02 NONE 6-81 9-81 10-81 11-81 1-82 1-82 10-81 3-82 9-81 NO NO 6-81 6-81 9-81 P K P NO 10-81 P NO 11-81 P NO 1-82 G NO 1-82 P YES 3-82 L NO 3-82 P YES 6-82 P Formerly Sunrise 4 Conduit Hydro, nameplate rating Unit rerated to full capability 1100MW Conduit Hydro, nameplate rating formerly L Feeder A 1 Operation 20%of full power ownership: 80%SCE, 20%SDGE Calif.State Water Project Recovery Plant Calif.State Water Project Recovery Plant Conduit Hydro, nameplate rating formerly L Feeder B 1 PRC APERTURE CARD 1.1-217/218 Blank PVNGS ER-OL SOUTHERN CALIFORNIA -NEVADA POWER AREA Org.Plant Name, Unit No., Location Unit Type MWD SCE SCE SCE NEVP Santiago CR 1, Orange, CA San Onofre 3, San Clemente, CA Rio Hondo 1, Southgate, CA Wind 1, CA Co-Generation, CA Warner Valley 1, St.George, UT HY NP HY WM zz ST CDWR Cottonwood 1, Los Angeles Co., CA HY Summer Winter Primary Fuel Fuel Type Deliv.Method 15 15 WAT 3 WAT+880+880 UR 2 WAT 4 5 250 4 5 250 WND WH BIT RR Net Capabilrty (MW)Alt.Fuel Type NONE NONE 1-86 YES 6-83 NO 6-83 6-83 6-83 Commercial Operation Date Prev.New Date 9-81 YES 9-82 6-82 YES 11-82 1-83 NO 1-83 11-82 YES 3-83 Stat.Comments Calif State Water Project Recovery Plant Conduit Hydro, nameplate rating Unit rerated to full capability 1100MW Conduit Hydro, nameplate rating Expected capacity 1MW Joint Project: NEVP 25%PG&E 25%, SCE 25%, uncommitted 25%.NEED FOR POWER Table 1.1-10 WESTERN SYSTEMS COORDINATING COUNCIL

SUMMARY

OF GENERATION ADDITIONS Sheet 4 of 5 SOUTHERN CALIFORNIA -NEVADA POWER AREA (Page 2 of 3)NEVP SCE Reid Gardner 4, Moapa, NV Fuel Cell 1, CA ST FC MWD Covina 1, Covina, CA Coyote CR 1, La Habra, CA HY HY PASA SCE SCE NEVP Glenarm 9, Pasadena, CA Geothermal 1, Brawley, CA Co-Generation, CA Warner Valley 2, St.George, UT ST GE zz ST BURB SCE Magnolia 3, Burbank, CA Combined Cycle GT 1-9, LUC VY, CA ST GT SCE SCE NEVP SCE SCE Balsam Meadow Hydro, CA Co-Generation, CA Allen 1, Las Vegas, NV Fuel Cells 2&3, CA Combined Cycle CC-ST, LUC VY, CA HY zz ST FC CA LDWP Scattergood 3, Playa Del Rey, CA ST 250 26-45 9 4 250+176-21 540 140 4 500 52 130 250 26 BIT UNK RR XX 3 WAT 3 WAT-45 9 4 250 F06 GST WH BIT TK RR-21 549 F06 F02 TK TK 140 4 500 WAT WH BIT RR 52 133 UNK F06 XX TK+176 F06 TK F02 NG NONE NG NG NONE NONE NONE 7-83 NO 6-83 7-83 7-87 YES 6-84 NO 1-84 6-84 6-84 6-84 6-84 10-84 6-85 NO 6-85 6-85 NO 6-85 NO 6-85 6-85 6-85 5-86 6-86 NO NO 5-86 6-86 3-83 YES 7-83 7-83 YES 11-83 K P M P P P Fifteen 26MW fuel cells are under consideration for use at various locations not yet determined fuel undetermined. Conduit Hydro, nameplate rating Conduit Hydro, nameplate rating Retire from service Joint project: NEVP 25%, PG&E 25%~SCE 25%uncommitted 25%.Convert existing natural gas unit to oil-burning capability Retire from service Various combustion and steam turbines during 1981-1987.A total of 1290MW in 3 430MW combined cycle units.Formerly Hydro Joint project: NEVP 8%, PG&E 46%, SCE 46%.See comments for fuel cell 1 Portion of combined cycle unit PRC APERTURE CARD 1.1-219/220 Blank PVNGS ER-OL SOUTHERN CALIFORNIA -NEVADA POWER AREA NEED FOR POWER Org.SCE SCE SCE SCE SCE SCE SCE NEVP LDWP SCE SCE SCE SCE SCE SCE SCE SCE SCE NEVP LDWP SCE SCE SCE SCE NEVP LDWP GLEN BURB Plant Name, Unit No., Location Combined Cycle GT, Lucerne Vy, CA Combined Cycle GT 10-12,LUC V, CA Wind 2, CA Combined Cycle CT, Lucerne Vy, CA Geothermal 2, Niland, CA Geothermal 3, Heber, CA Co-Generation, CA Allen 2, Las Vegas, NV Intermountain 1, Millard Co., UT Fuel Cells 4&5, CA Wind 3, CA Combined Cycle CC-ST, LUC Vy, CA Combined Cycle CT, Lucerne Vy, CA Combined Cycle GT, Lucerne Vy, CA Combined Cycle CT, Lucerne Vy, CA Combustion Turbine 1-2, CA Co-Generation, CA Calif Coal 1, CA Allen 3, Las Vegas, NV Intermountain 2, Millard Co., UT Fuel Cells 6-9, CA Wind 4, CA Co-generation, CA Calif.Coal 2, CA Allen 4, Las Vegas, NV Intermountain 3, Millard Co., UT Grayson 3, Glendale, CA Magnolia 4, Burbank, CA Unit Type GT GT WM CT GE GE ZZ ST ST FC WM CA GT GT CT GT ZZ ST ST ST FC WM ZZ ST ST ST ST ST-300 180 6 300 54 45 4 500-305 183 6 305 54 45 4 500 750 750 52 15 260 52 15 266 180-600 183-610 600 110 4 250 500 750 610 110 4 250 500 750 104 30 4 250 500 104 30 4 250 500 750 750-21-28-21-28 Net Capabilrty (MW)Summer Winter Fuel Type F02 F02 WND F02 GST GST WH BIT Deliv.Method TK TK TK RR BIT RR UNK WND F06 XX TK F02 F02 F02 F02 WH BIT BIT BIT TK TK TK TK RR RR RR UNK WND WH BIT BIT XX RR RR BIT RR F06 F06 TK TK Primary Fuel Alt.Fuel Type NONE NONE NONE NONE 6-86 6-86 1-87 6-86 6-86 NO NO YES NO NO 6-86 6-86 6-86 6-86 6-86 6-86 6-86 6-86 P P P P P P P P NONE 10-86 YES 7-86 NONE NONE NONE NONE NONE NONE NONE 1-87 6-87 6-87 6-86 6-87 6-87 6-87 YES NO NO NO NO NO NO 5-87 6-87 6-87 6-87 6-87 6-87 6-87 6-87 6-87 6-87 P P P P P P P NONE 10-87 YES 7-87 P NONE NONE NONE 5-88 6-88 6-88 6-88 6-88 7-88 NG NG 7-88 10-88 M M Commercial Operation Date New Prev.Date Stat Comments Convert to combined cycle Expected capacity 2MW.Replaces previous geothermal Joint project: NEVP 8%, PG&E 46%, SCE 46%.Joint project: LDWP 34.1%, ANHM 10.2%, BURB 1.7%, GLEN 1.7%, PASA 3.4%, RVSD 6.8%, ICPA 17.1%, and UPLC 25.0%.See comments for fuel cell 1 Expected capacity 5MW.Portion of combined cycle unit Convert to combined cycle unit Joint project: NEVP 8%, PG&E 46%, SCE 46%.Joint project: LDWP 34.1'4, ANHM 10.2%, BURB 1.7%, GLEN 1.7%, PASA 3.4%, RVSD 6.8%, ICPA 17.1%, and UPLC 25.0%.See comments for fuel cell 1 Expected capacity 10MW.Joxnt pro3ect: NEVP 8%, PG&E 46%, SCE 46%.Joint project: LDWP 34.1%, ANHM 10.2%, BURB 1.7%, GLEN 1.7%, PASA 3.4%, RVSD 6.8%, ICPA 17.1%, and UPLC 25.0'4.Retire from service Retire from service Table 1.1-10 WESTERN SYSTEMS COORDINATING COUNCIL

SUMMARY

OF GENERATION ADDITIONS Sheet 5 of 5 SOUTHERN CALIFORNIA -NEVADA POWER AREA (Page 3 of 3)PRC APERTUpp--.-CARD 1.1-221/222 Blank EXPLANATION LITHOLOGI DESCRIPTIONS A.UPPER ALLUVIAL UNIT SITE BOUHDARY NORTH I 1200 I I IOOO 44 44 JJ I CJ C 44 CJ 44'4J i I4 CJ CJI 44 i CI i CJ SITE BOUHOARY SOUTH 12OO I I I 1000 SILTY AHD GRAVELLY SANDS, WITH SOME SILTS AHO CLAYS (LZ-5)B.IIIIDDLE FINE GRAINED UNIT (AOUITARD) UPPER ZONE: SILTY CLAYS WITH SOME SILTS AND SILT'Y SAHDS (LZ-4)LOWER ZONE: PALO VERDE CLAY (LZ-3)000 UJ ll 600 400 200\4"'.,-I I I-IJI./',il I I-I I/C I cl./,Ic/,-Il I CC 4 SCALE HORIZOHTAL: I"=2000'ERTICAL

I"=400'ERTICAL EXAGGERATIOH:

5X HOTE: DIP OF VOLCANIC FLOW BEDDING IS HOT EXAGGERATED. 800~600 I 400 200 C.LOWER COARSE GRAINED UNIT SILTY SANO SANO AHO GRAVELLY SANO (LZ 2)FAHGLOMERATE (LZ-I)VOLCANIC FLOWS ANO FLOW BRECCIA CJ~~4 4 44 4 CJ4 BRECCIA TUFFACEOUS AHD ARKOSIC SAHDSTOME TUFF GRAHITIC AHD METAMORPHIC ROCKS PRC APERTURE CARD D.BASEMENT COMPLEX I/I 4///4 WATER LEVELS MARCH 1979 PERCHEO WATER ZONE REGIONAL AQUIFER Palo Verde Nuclear Generating Station ER-OL GENERALIZED HYDROGEOLOGIC CROSS-SECTION OF THE SITE Figure 2.4-1 800 780 YIELD: 2,460 m 3-2-69 YIELD: 2,700 gpm 7-22-53 2,840 gpm 7-13-53 YIELD: 880 gpm 9-13-61 1,360 gpm 8-6-68 I YIELD: 2,000 gpm 7-22-53 1,250 gpm 8-10-61 800 780 760 760 I-UJ IU UJ 140 720 700 680 660 640 IRRIGATION WELL (C-1-6)14dbb IRRIGATION WELL (C-1-6)18bbb IRRIGATION WELL (C-1-6)21cbb2 IRRIGATION WELL (8-1-6)27ddc 740 I-720 700 UJ 680 660 640 860 840 820 800 I UJ UJ 180 YIELD: 1,950 gpm 7-13-55 1,360 gpm 8-09-61 Y I ELD: 3, 490 gpm 7-20-49 2,260 gpm 8-05-68 860 840 820 800 I UJ UJ 780 PRC APERTURE CARD UJ 760 740 720 700 IRRIGATION WELL (8-1-6)20dbb UNUSED WELL (8-1-6)26baa IRRIGATION WELL (8-1-6)34abb BORING PV-7 760 740 720 700 UJ NOTE: WELL DATA PRIOR TO 1973 TAKEN FROM BTULIK WATER-LEVEL DATA AFTER 1973 OBTAINED BY FUGRO, INC.Palo Verde Nuclear Generating Station ER-OL HYDROGRAPHS OF DEEP WELLS IN THE SITE AREA Figure 2.4-6 $$9$1$$3$$$2 soe$1$eso$7$7-eae eoe 77 I 1 4=7 sle$$2 eoe$73 eoo$$$I12 ese$$8$7O ess$$2 see$9~$$$ese PV-14H 4$2 PV 21H 4II PV 22H$$$>>>>t!I!18!9 1$73 li!I et!f till ili 1$11 9 2 3 e I!19 le i 3!3 9 I 9!Is 1 II 3 II I 2 I 3 9!t t I e i li 1$77 187$1$75 1$1$9!I I t!!I I 3 1 il 191$4$$asses!!tie!a 1$13 edict!a!I!sita!tet!t!13!t 1878 1$75 7 sf!!913!93!I et!2318!3 1$71 197$17!.*I 3 9!!t I 3 e 8 I!I e I!t I 1 3 I 9 197$197$$$$32 9 et!!tie!a 3 st 9 t!!tle ise I 9 et!!tls!3 I!est!!!lait 3!tet!!tla i 3 3 e I 3 t!ttl as i 3 e 9 2 t!t t la is 1$75 1$'ls Isle Idle 1411 1113 1$73$1$eoe$$$$3$$2$$28 HOTES: PRC APERTURE CARD eoe soo$$$$23$2$S le$1$Vi ON SITE IRRIGATION CEASED SEPTEMBER, IG75.V WELL RESPOHSE TO FLUSHING.IRRIGATIOH WELL B-1-6-34acc, LOCATEO AT A DISTANCE OF 214'ROM PV-24H AHD JJ MILE FROM PV-25H, WAS SEALEO BY GROUTING IH JULY IB76.THE SUODEH RISE IH THE MEASURED WATER LEVELS INDICATES THAT THESE WELLS WERE LOCATED WITHIN THE COHE OF DEPRESSIOH CAUSED BY PERCHEO WATER CASCADING THROUGH THE IRRIGATION WELL.ese su 3$1$$2 PV-24H-.$12$1$P V-2 5H Palo Verde Nuclear Generating Station ER-OL II4 sssetlstlsis 1$73 I!I 9 I!!I I 8 I 3 3 2 3 9 9 3 71 8 i 8 3!I 1 I!!3 1 8 e 3 3 2 I I I!!2 18 9 tl I!I 3 I!2 3 1 8!8 3!I 3 t'!31 8 I 3 1$7$191$1$75 1$77 IS7$1$7~$$4 I!set!!ale ta I!!ef!!alia!Ill!1st! 2318131!set!3!lease!I et!!3!assai!! I!!!Iie!3 1315 1913 Isla ten 1$71 197$1!!et!ttlieii 1$1$HYDROGRAPHS OF OBSERVATION WELLS IN THE PERCHED-WATER ZONE (Sheet 1 of 5)Fioture 2.4-7 124 920 070 914 02~010 022 922 91~910 920 912 110 L', 910 916 , 1 IL I'.I-L Lie 070 000 sn 012 1.7.01~912 soe 004 810 910 001 a00 PV-28H 0a0 I 2 6 3 I lt I I 8 I ll I 4 I 3 I l 2 I I 8 I!I I 1 I I I lS 1 l 8 I il 1975 1014 1013 iciefltllale 1970 12 I ellis!'3 6182 I 1 I 1 2I li I!I 1070 1977 1979 008 PV-29H 040 1 2 I 1 f.'f la I 8 1973 1074t 1075 1976 1071 1910 1979 1 2 I 3 I 3 Ill li I i!I 8 I 3 I l 2 I lii I it 4 I 5 I l 2 2 l I I I 000 000 PV-30H I 4 I 3 I l 2 I I 8 I I 1 I I 1 f 2 f I t I I it 1013 1974 I 4 I 5 I!8 I ls I I 1015 I 2 I 3 I l I I l 8 I it 1018 3 I I 3 8 I 8 I I II i I 8 I I 3 I l 2 I tt 3 I I 8.'3 I l 2 S I li I I 1070 1077 107S PRC APERTURE CARD 110 001 01e 104 000 01~011 014 eoe LS'00~900 090 090 00~00e 00~090 NOTES: V OH SITE IRRIGATION CEASED SEPTEMBER, IOTB.V CYCLIC SEASONAL VARIATIONS REFLECT RECHARGE FROM SEDIMENTATIOH BASIN LOCATED NEAR THE CEHTER OF THE SITE.ALL SURFACE RUNOFF WITHIN THE NORTHERN HALF OF THE SITE IS COLLECTED IN THE REGIMENTATION BASIN.90~09~00e 902 Soa-PV-31H+TE=+092 090 PV-33H'-;00e e04 PV-34H Palo Verde Nuclear Generating Station ER-OL 001 18 lillt lail 1973 I 4 t if st lie>>7974 I I 3 I ia I tll a ii 1975 citillf1ltiiia*'clif fltiaiii 1976 1977 fiif.'tfllia 1970 I I 1 I.'2 tt 8 I I 7018 000 0 1973 3 4>>I l t ll 4 I I I 4>>S I 3 I I 8 I I 1974 1075 I c>>tent!Ie I I 8 4 416'1 flail 1976 1977!esesltrlall 1010 c 1 I 1 I l 2 I I 1 I!I 1970 001'57 8 2 I 3 I l 2 I tt 8 I I I!I 6 I l 2 2 tt 3 I II iciifltelats 1075 1014 1073 7070 1~8 e I l tf te I it I 2 I 3 I l 2 fig Ill 3 4 I 1 I 1 fl 3 3 it 1110 1077 iciialtf lail 1019 HYDROGRAPHS OF OBSERVATION WELLS IN THE PERCHED-WATER ZONE (Sheet 2 of 5)Figtize 2.4-7 010 eea 018 029 000 ee!411 022 044 eeo 010 420 008 402 ce!R I I eto RES 0--LES 070 ers see 014 070 eeo EEO 00 et tc 7 7 47~eoa el~450 en 402 012 see ere 000 010 458 042 PV-R2 eee ees':.::-: PV-Q1 7 000 eee t==,',-;-'.P V-03 000 eeo I!Eat!tel>>sa! E ill tt le is 1015 1016 8!t 2 t l 2!le t 0 I!i 2 2 l t t l 8 l 1 1010 1011 1814 eei!l l 2 2 l 8 t tl 1074 8!Setlttliis 7071 1070 1479 iaietltttaas!2 >>tattlers 008 1014 2 a i 2 tl!tle 42 2!8 etl 8 tle i 2 EE i itittle!2 1077 tera 008 I!S ill 2 tie a 2 1418 I!l 2 S 2 t 2 l 2 I 2 1017 I!>>tl!Ele I 2 2!8 1st t tie!2 10'10 1070 004 028+I 028 04~902 022 020 NOTES: V OH SITE IRRIGATION CEASED SEPTEMBER, 1975, 400 ne soe eea 442+920 420 418 922 020 910 970 018 SI 2 970 PRC'pppYURF. CARD Y OBSERVATIOH WELL U3-PTW-I, LOCATED NEAR THE CEHTER OF UNIT 3, WAS ABANDONED IM OCTOBER 1977 BECAUSE OF THE POWER BLOCK EXCAVATION. MONITORING OF WATER LEVELS IN THE AREA WAS CONTINUED IN WELL PV-O3, INSTALLED AT THE EDGE OF THE EXCAVATION IN JANUARY 1979.THE STEEP DECLINE OF VJATER LEVELS OBSERVED IH PV-93 REFLECTS THE LOCALIZED EFFECT OF DEWATERING IN THE EXCAVATION. 0$0 eee 044 PV-TR-1=8>>a 8 l!2 2 a i 2 I a i 2 t 1 t 2 l 8 a 2 I!l 2 t 1 t 2!i 2 i 21 a t 2 S l 1 2 l S a 2 910 910 I ef~PV-TR-I!1 I i!2 7 2 a t 2 400 988 U3-PTW-1 c!I 2 l l 8 2!I a 1 2 7 948 I!i I t.'7 l a 2 tl I 2 1 2 t.'.'8 I 2 Palo Verde Nuclear Generattng Station ER-OL HYDROGRAFHS OF OBSERVATION WELLS IN THE PERCHED-WATER ZONE (Sheet 3 of 5)1078 1017 1070 1979 1975 1975 1977 7975 1070 1977 Figure 2.4-7 915*915 I t I.'.I t I~l~I I 914*913 913~-t~~'I h 912'12 I I'I I~'I 911 I R 910 z Q 909 908 907 906 905 915 914 913 912 911 I-R 910 R O I-+)909 908 907 906 905 t h.::."-U4-H1::.::. ~~+~h~~~~~IIIIII'IIIIII IIIIIII{IIII ~{~'I l~~I:::I]IU4-H5:.::-' I I I I I I{I I I I I I I I I I I'I I'I I I 977 1 7~~IIIII lilill~I 1111 I I I{I I 1979~I I t h~*~~~U4-H2::I': t iiliilliliii'i{1{IIIIIIIII{{I{I i{lit{1979 19 8~I U4-H6.::.I~~~111{I I i I I I I I{I{ill{I{i{ {I i{I li 1978 1979~~~~~~~:: U4-H3:::~~~~I~~~IIIIIIIIIIII {11{ill{ill{ I I I{I I I I I I 1979 9 8 1 77 t I I~~~~~~~h h~~~~~~" t:.:.U4-H7;{i I I I I I I I{I I'{I I I I I I I I I I{I{I{I I I I I I{1977 1979 78 915 914 913 912 911-I-910.2 lD 909 908 907 906 905 911-I 910 R 909 908 907--:::I';:::: U4-H4:.: 906 905{{i{i ill{{I IIIIIIIIIIIIIIIIIIIIIIII 19 9 19 8 PRC APERTURE CAR I3 Palo Verde Nucle1Ir GeneratinI; Station FR=o<HYDROGRAPHS OF OBSERVATION WELLS ZN THE PERCHED WATER ZONE (Sheet 4 of 5)~Figure 2.4-7 '.i lt~Q PVNGS ER-OL'.5 , GEOLOGY Geologic conditions have not changed substantially from those presented in ER-CP Section 2.4 and the'FES.The following sections summarize the results of those investigations and additional investigations performed, during construction. For detailed information refer to FSAR Section 2.5.2.5.1 REGIONAL GEOLOGY The site area is located on the southern edge of the Tonopah Desert in Maricopa County, Arizona (figure 2.5-1).The site area is part of'he basin and range structural province of southwestern Arizona, which is characterized by predomi-nantly north, northwest and northeast trending mountain ranges rising abruptly from broad, plain-like basins.The basins and ranges owe their origin and alignment to late Cenozoic block-faulting and folding, superimposed on earlier structures developed during the Laramide orogeny.The'rocks of the basi'n and r'ange province include metamorphic, granitic, and volcanic rocks of Precambrian, Cretaceous, and Tertiary age, and volcanic and sedimentary rocks of Pliocene and Quaternary age.The region has experienced repeated tectonism since Precambrian time.The types of deformation include folding, strike-slip faulting, and normal faulting.2.5.2 SITE GEOLOGY The rocks of the Palo Verde Hills have been divided into three parts: the Precambrian metamorphic and granitic basement rocks;Miocene volcanic and interbedded sedimentary rocks;and basin fill deposits which range in age from Miocene to Holo-cene.Interbeds of volcanic rocks occur locally within the basin sediments. The distribution of those units.areally and in section are shown in figures 2.5-1 and 2.5-2, respectively. 2.5-1 PVNGS ER-OL GEOLOGY The units are described in the stratigraphic chart of the site area (figure 2.5-3).2.5.2.1 Basement Rocks Precambrian granitic and metamorphic rocks ar'e not exposed at the ground surface but are known to exist in the subsurface from exploratory borings at depths ranging from 300 feet to 400 feet.2.5.2.2 Bedrock Surface exposures of bedrock in the Palo Verde Hills are pre-dominantly Miocene volcanic rocks with localized interbedded sequences of water-laid tuffs and sandstone. Potassium-argon ages on these volcanic rocks range from 17.7 to 20.3 million years.2.5.2.3 Basin Sediments Basin sediments at the site have been divided into six strati-graphic units (see figure 2.5-3).In order of decreasing age these are the following units:-~Tertiary indurated fanglomerate (LZ-1)~Lower silt and lower sand and gravel deposits (LZ-2)o Palo Verde Clay (LZ-3)~Silty clay deposit (LZ-4)~Upper sand and gravel deposit (LZ-5)~Younger fan deposits (LZ-6)The average thickness of the alluvial sequence (LZ-2 through LZ-5)above the indurated fanglomerate (LZ-1)is approximately 320 feet with a variation of thickness of approximately 100 feet.The stratigraphic units within the alluvial sequence are continuous across the site and generally continuous for several miles beyond the site boundaries. 2.5-2 PVNGS ER-OL GEOLOGY The Palo Verde Clay (LZ-3)is the most distinctive strati-graphic unit.in the all'uvial sequence.This unit demonstrates exceptional continuity within the site and up to 5 miles south-east and 5 miles northeast of the site.The up'per contact of unit LZ-4 is well defined throughout the site using borehole data and geologic mapping data from the Units 1, 2, and 3 powerblock excavations. In many areas of the site contact was characterized from numerous closely spaced borings.2.5.2.4 Structure The Palo Verde Hills are a part of a regional positive struc-tural block.that includes Saddle Mountain, Gila Bend Mountains, Buckeye Hills, and the White Tank Mountains. (1)Bedrock structure at the site includes stratification, possi-ble minor folding, and faulting.The dominant structure of the Palo Verde Hills area is a homocline with the volcanic flow I bedding dipping 15 to 40 degrees southwest (figure 2.4-1).Detailed mapping in the Palo Verde Hills has revealed only one small fault approximately 3 miles west of the site area.This fault displaces Miocene volcanic.rocks.The fault trends beneath the Tertiary indurated fanglomerate (LZ-1)but does not displace it.The structure of the basin sediments covering the site area was carefully analyzed to determine the tectonic history of the Palo Verde Hills area during the Pliocene and Pleistocene. The Palo Verde Clay, the most distinctive unit in the alluvial sequence, was traced continuously in closely spaced borings (<100 feet apart)in the site specific (powerblock) areas, in boring approximately 2500 feet apart across the site, 5 miles to the southeast under the Arlington basalt flow, and 5 miles to the northeast of the site (see figure 2.5-2).The 2.5-3 PVNGS ER-OL GEOLOGY Arlington basalt has been dated by potassium-argon techniques at approximately 2 million years old.Therefore, the Palo Verde Clay is older, and has been estimated by paleomagnetic techniques to possibly be 2.8 million years old.There is no evidence of faulting or folding in the Palo Verde Clay, and no indication of any major tectonic activity in this area since at least late Pliocene time.I Ground surface deformation associated with natural or man-induced phenomena, such as the formation of salt bodies or subsidence, does not affect the PVNGS site.Subsidence or subsidence cracks due to withdrawal of groundwater during 25 years of irrigation have not been observed or reported during the investigations at the site.The site area was formerly under cultivation,and irrigation through August 1975 when all agricultural activity at the PVNGS site ceased.2.5.3 SEISMIC HISTORY The site is in an area of low historic seismicity. No epicen-ters of earthquakes, magnitude 4 or greater, have been reported within a 65-mile radius of the site.Five epicenters of earth-quakes less than magnitude 4 have occurred within about 50 miles of the site.Figure 2.5-4 presents an updated map that details recorded epicenter locations and seismic zones in the site region.Refer to FSAR Section 2.5.2.1 for a detailed descrip-tion of regional seismicity. 2.

5.4 REFERENCES

Sumner, J.S., and Aiken, C.L.V.,"Geophysical Investi-gation of the Palo Verde Hills Area, Maricopa County, Arizona," Unpublished report prepared for Fugro, Inc., 1973.2.5-4 GEOLOGIC MAP SYMBOLS LITHOLOGIC UNIT AGE THICKNESS LOCATION DESCRIPTION LITHOLOGIC MAGNETIC MAGNETIC SYMBOL POLARITY ZONE MAGNETIC TIME SCALE anterpretation for Pab Verdo area)WORLDWIDE PALEOMAGNETIC TIME SCALE Qsu QTb bf QT LZ 6 Young Fan Deposits Arlington Basalt Flow LZ-5"Upper" Sand and Gravel LZ-4 Upper Silt L-IO Horizon LZ 3 Palo Verde Cia Holocene-Pleistocene 2 ill.y.(Best K-Ar date)2m y.>2m.y.to 2.8m.y.2.8 m.y.at top 8 to l5 feet 5 to 200.feet (estimate) Up to 50 feet'50 to 200 feet 20 to I36'I feet North and east of site Arlington Palo Verde basin Palo Verde basin and south and southeast toward Ar ling ton Central part of P.V..basin and south and south-east toward Arling ton Brown gravel in a loose to medium dense silt and sand matrix, poorly sorted moderately stratified Volcanic, granitic, and metamorphic clasts.Dark gray, hard, slightly porphyritic olivine basalt.UN CONFORMITY Brown, medium dense silty sand and gravel;predominantly quartz sand with volcanic gravel;weathered mica common;localy calcareous PARACONFORMITY Brown, medium dense to dense silt and clayey silt with generally minor interbedded fine sand;scattered fine weathered mica common;local calcareous cement;coarse sand and gravel locally at base of unit.Series of paleosols developed near upper contact.PARACONFORMITY Red-brown, very stiff, calcareous, silty clay;interbedded clastic wedges near west edge.of basin.Paleosols devebped at upper contact.'0'0'.'o p v h 1 ('1..~'o.,MZ 5 Reversal Designation MZ-4 MZ Reversal Des nation MZ 2 R IO 2.8m.y.R 8 Matuyama Epoch 2.imam.y.Gauss Epoch;;5.08m.y.Period Epoch o)R)C: O)I Rl C 0)O O)h Rl Q.O E O O Age Event O ol c oo-: 0 Rial~0.69~0.87~0.92 Jaramillo~I.60~l.7l Olduvai~I.86~2.00 IO Reunion Tvfn Tvb Tvu Tvt I>Not exposed in site area LZ 2 Lower Silt Lower Sand 8 Gravel LZ I In dura te d Fanglomerate Volcanic Bedrock Sequence Arkosic Conglomerate Grdnitic and Metamorphic Basement)3m'.3m.y.I6.7-3 m.y.(K<r date of int~rbedded basalt)l7.7 to 20.3 (K-Ar dotes)Unknown Precambrian 20 to 97 I feet IOto 30'eet 35 to 285 feet 6)000 to 7,000 Feet I48 Feet Unknown Central part of P.V.basin 8 sout and southeast toward Arlington Palo Verde basin Palo Verde basin Palo Verde Hills Palo Verde Hills Subsurface Palo Verde Hills Subsurface Brown to red-brown, stiff to very stiff, sandy and clayey silt, locally grading to sand and gravel at base of unit.R....o~,o.': v 0.'~'.~~~.<'.<.~I, Note: e m v v v v v v v v v"v V)v v v'v v VI++y cvh vv v)V r.~>)v)as<>o).'oo~v).0+.ojj Miocene volcanic sequence includes inter-bedded basalt, andesite and tuff, Tvb differentiated basalt, Tvu undiffer-entiated basalt and andesite, Tvt tuff and tuf faceous sandstone. UNCONFORMITY Arkosic conglomerate, granite andesite and basalt clasts.MA JOR UNCONFORMITY 'V iI-i rI vi-$iv g i V 1)Si V I'r-Granite, granitic gneiss and metamor-phosed volcanic and sedimentary rocks.Brown, dense, silty and clayey sand and gravel of volcanic origin, poorly sorted.UNCONFORMITY Brown, moderately to well cemented fanglom-erate composed of volcanic ciasts derived from underlying bedrock;local interbed of dark gray, hard basalt at boring PV-DH-33.MAJOR UNCONFORMITY MZ-I-3.5.m.y.?4 Gitbert, Epach?')C 4)V O a Kaena~?.90~3.00 3 085 Mammoth Cochitl~3.82~3.97 Nun(vak~4.33~4.4I~4.48~4.65 C2 STRATZGRAPHTC CHART OF SITE AREA Figure 2.5-3 Palo Verde Nuclear Generating Station//~ER-OL f l I 38o x(~X X 4x>~~X w'I'P'x IF I X4<X Xxy 1%~~(K~I Y X NEVADA+P>>7o+xxTA K)e xQl NEVADA I), 14 X x X x x X X X X~~~~~y X X y L13'y 0~xi>>Xe~K~X~/g X~>>~x'0 X X X 110 090 38 X COLORADO 36 EXPLANATION X M<<4.0 x 4.0<<M<<5.0 X 50 M<<60 X 6.0<<M EPICEHTERS FROM USGS WORLDWIDE CATALOG OF EARTHQUAKES, NATIONAL GEOPHYSICAL AHD SOLAR-TERRESTIAL DATA CENTER.COVERAGE FOR THIS AREA IS 1852-1977. SEI SMI C ZONE BOUNDAR I ES 50 Cx xo X K~X ARIZONA 35 y NEW AIEXICO-, CAPABLE FAULTS-LESS THAR 500.000" YEARS OLD X X~34~x CAL I FORM I A 1E~X x~XKg g>>X~X X~X.~D~SITE 0<@x x X X X X X"..'x 1140 XX 1150 180 ,~330.x XX X~~~~~~X~~~~/,: ';"'.B'L X<<x X x')'yy~~,'i>/>~q<<~.h~X)'(y+.,~~~~~'0,'~X<'GlfLF'8F'AJ A xxx', y>e'v'.X yV X Xi'XAC,'XX X X X x CALIFORNIA.X '+x X" O CAL I FOHN'A C I~%v~SONORA x~112~I~/'A'i~)I I 1114~~y X~.0 I X 110 1 34o~~y~~~~~~~330 320 1094,'.QUATERNARY FAULTS-500,000 YEARS TO ABOUT I.6 MILLION YEARS OLD----, ONLY EARTHQUAKES WITH M-4 SHOWN SOUTHWEST OF THIS LINE NOTE: SEE FIGURE 2.5-6 FOR SOURCES OF FAULT DATA 0 50 100 MILES REGIONAL EPICENTER MAP Figure 2.5-4 L P alo Verde Nuclear Generating Station ER-OL I w\ PVNGS ER-OL II 2.6 REGIONAL HISTORIC, ARCHAEOLOGICAL, ARCHITECTURAL, SCENIC, CULTURAL AND NATURAL FEATURES The environmental baseline descriptions of regional features in connection with PVNGS are as described in ER-'CP Section 2.'3 and the FES..This information is summarized and updated.in~this section to reflect changes in transmission line routing and the mitigation of archaeological finds at the PVNGS site and along the wastewater conveyance pipeline route.2.6.1 PVNGS SITE There are 13 archaeological sites located within or near the boundaries of the plant site.Those sites located within the~plant site boundaries have been affected by the construction of Units 1,263.The following steps have been taken as means of preservation: ~-Excavation of known archaeological sites Investigation for potential sites~Mapping and analyses of trail networks and their interrelationships. Where artifacts and evidences of archaeological significance have been found, they have been preserved and analyzed to the~]satisfaction of the State Historical Preservation Officer.Hence, the archaeological heritage of the site has been established and preserved. \Review of the National Register of Historic Places and=consulta-tion with the Museum of Northern Arizona, the Arizona Department of Library and Archives, the Arizona State University Hayden.Library, and the State Historic Preservation Officer indicates that there are no register historic properties located on or near the site.2.6-1 PVNGS ER-OL REGIONAL HISTORIC, ARCHAEOLOGICAL, ARCHITECTURAL'CENIC~ CULTURAL AND NATURAL FEATURES Review of the National Registry of Natural Landmarks and con-sultation with the State Parks Director and the State Historic Preservation Officer indicate that there are no natural areas located on or near the plant site.No architectural, scenic, or cultural features have been identified within or near the boundaries of the PVNGS site..2.6.2 TRANSMISSION ROUTES The transmission system associated with PVNGS is described in section 3.9.1.Information presented in ER-CP Section 2.6 and the FES has been updated to reflect final line routings and the addition of a transmission line from PVNGS to Devers Sub-station in California. The expected impacts of Project 1 and 3 transmission systems are updated and summarized in this section.Information concerning the PVNGS to Devers line is contained in the U.S.Department of Interior Bureau of Land Management and U.S.Nuclear Regulatory Commission Final Environmental Statement, Palo Verde-Devers 500 kV Transmission Line, February, 1979.Descriptions are presented for preferred and alternate routes.The Project 1 transmission line routes described in sec-tion 3.9.1 traverse several zones of ancient culture occupation associated with the Hohokam and Cochise traditions. Surveyed sites within these areas are associated with the Hohokam, although other cultures might be represented. Most identified sites are small seasonal gathering-sites.The State Historic Preservation Officer (SHPO)has approved the plan for protection of sites along the PVNGS to Westing Line.The plan for protection of sites along the PVNGS to Kyrene line has been submitted for approval of the SHPO.'.6-2 PVNGS ER-OL REGIONAL HI STORI C g ARCHAEOLOGI CAL ARCHITECTURAL, SCENIC, CULTURAL, AND NATURAL FEATURES The proposed transmission line routes will cross three areas of scenic quality: (1)Rainbow Valley;(2)an area east, of.-Table Top Mountains; and (3)an area west of Sawtooth Mountains. There are no architectural, natural, or historic properties located on or near the proposed transmission line routes;A survey of most of the Project 3 transmission'ine route by.the New Mexico Environmental Institute discovered some sites.of archaeological interest.However, none were"visibly spectacular nor sufficiently important to justify the establish-ment of a state or federal monument for their preservation and exhibition." The survey did not constitute an archaeological clearance of the route but, did identify that there are no known or recognizable sites of archaeological significance along the route.The proposed transmission line route will follow for the most part existing utility corridors through isolated desert, grazing, and agricultural land.It is expected that scenic features will be minimally impacted as a result of the construction and operation of the project.There are no architectural, natural, or historic properties located on or near the proposed transmission line route.2.6.3 WASTEWATER CONVEYANCE SYSTEM A number of prehistoric archaeological sites are located near the right-of-way. Sites located close to the right-of-way have been mitigated using measures similar to the ones described in section 2.6.2.The State Historic Preservation Officer has (4)approved the plan for protection of sites along, the pipeline.Where artifacts and evidences of archaeological significance have been found, they have been preserved and analyzed.Hence, there has been a significant positive impact upon the 2.6-3 PVNGS ER-OL REGIONAL HISTORIC, ARCHAEOLOGICAL, ARCHITECTURAL, SCENIC, CUITURAL, AND NATURAL FEATURES archaeologic features as a result of the extensive mitigation approved and executed for the construction and operation of the project.Review of the National Register of Historic Places and consulta-tion with the Museum of Northern Arizona, the Arizona Department of Library and Archives, the Arizona State University Hayden'ibrary, and the State Historic Preservation Officer indicate that there are no registered historic properties located on or near the pipeline right-of-way. Review of the National Register of Natural Landmarks and consultation with the Arizona State Parks Director and the State Historical Preservation Officer indicate that there are no natural areas located on or near the right-of-way. There are no architectural scenic, or cultural properties located on or near the right-of-way. 2.

6.4 REFERENCES

2.Letter dated May 18, 1976 from Dorothy Hall, Arizona State Historical Preservation Officer (SHPO)to Dr.Robert A.Gilbert, Project Manager, Environmental Projects, Branch 3, U.S.Nuclear Regulatory Commission. Letter dated September 21, 1978 from Dorothy Hall, Arizona SHPO to Bob Buffington, State Director, Bureau of Land Management.'. Environmental Im act Stud of Pro osed 345 kV Power Transmission Line Corridors from Dona Ana Count , New Mexico to Greenlee Count , Arizona, prepared for the El Paso Electric Company, prepared by the New Mexico Environmental Institute, Las Cruces, New Mexico, January 1974.Letter dated August 9, 1977 from Dorothy Hall, Arizona SHPO to Dr.Robert A.Gilbert, U.S.Nuclear Regulatory Commission. 2.6<<4 PVNGS ER-OL 2.7 NOISE Ambient noise levels in the vicinity of the site were measured prior to construction and presented in ER-CP Section 2.9.L50 sound levels at 10 sampling points varied from 17 to 66 dBa with an overall average of 34 dBa.Daytime, evening, and nighttime sound levels are shown in figures 2.7-1 through 2.7-3.Preconstruction noise survey methodology is described in section 6.1.The noise sensitive land uses in the vicinity of the plant site are residences. Distances from major noise sources to nearby residences are indicated in table 2.7-1.There are no institu-tions or wildlife preserves in the vicinity of the plant site.There are few terrain features and little significant ground cover in the vicinity of the site which would have significant effect on propagation of sound from the plant.Most o'f the vegetation in the area lies along drainage gullies and would provide little attenuation of sound.The terrain in the vicinity of the site is generally flat, sloping gently to the south, and interrupted occasionally by rock formations that vary in height from 20 to 100 feet.The only features of potential significance for sound attenuation are those imme-diately to the north of the site and to the east of the site.Due to the distance of these barriers from the plant noise sources and the limited width of these features, little attenua-tion of sound at the residences in these directions is anticipated. March 1981 2'1 Supplement 2 PVNGS ER-OL NOISE Table 2.7-1 DISTANCES TO NEAREST RESIDENCES WITHIN FIVE MILES OF MAJOR NOISE SOURCES Distance from Source Location (Miles)Direction Nearest Cooling Tower Nearest Unit Transformer (Switchboard) Reclamation Water Pumps N NNE NE ENE E ESE SE SSE SSW SW WSW 1.2 1.7 1.8 2.7 3.3 3.7 4.0 3.7 2.9 3.6 1.4 1.8 1.9 2.7 3.2 3.5 3.9 3.7 2.9 3.7 1.8 2.1 2.1 2.7 3.0 3.2 3.6 3.7 3.2 4.0 0.9 1.2 1.3 2.4 3.1 3.6 4.5 4.7 4.1 4.8 NW'.0 2.2 2.3 2.4 2.6 2.8 2.1 2.0 Supplement 2 2~7 2 March 1981 ~.1 e Crevek e~n I/'o l Interobnrg I;I~~~~~I~~$~~'~~~~~~~~~~~~~~~I~~OOI/le e)I ,Well lr3 r~ace<<r{C~re nc o rr o+o IE Y Well, I~lore~roe re er r{Q~l33 I Wed 66 22 t~4 r lr Q'1 23 e I v I I" a>8 r J e-0 ,$c\)r.24 19~te C.r I e<<e o')66 2S I',g ,'it.,32 Ir l.....I V (~Well'loge~error e (', 3~r Ar Comp.i'joeoeeaagaral Wen PALO VERD'f a mrrrrarrnrlr>> E NUCLEAR GENERATING STATION Mo e roe~~I31 LINI'ired. oeo" er1-'Oeeert Well I Qo 18 Well ddO>>17 (I I er1 29 r j'J~15'f 14 12'I WAdn VA8M 6 c e\~e~I or e doe'13 bor emp 8M 88l e e rae r 1 well 33 r I 8 AO rr pre~" I./A%4 18~+(ree~'er 261 era rrra orr~ell>r ceo~r~~1 e I e 19 aae ee ore~e o o ato~~r~"1"d.2II f~I 30 0 0 Irr r NORTH rr rry ,OerrrrO(r Arlington Station~tebor 23 rI'Comp Palo Verde Nuclear Generating Station ER-OL SCALE LEGEND: O 32 R E PRESENTS LEO OF 32d BA COMPOSITE DAYTIME SOUND LEVELS Figure 2.7-1 l 1'(I <<4~~,~.p 4 Glerel,'ss e IP<<4+/...r I Gr I I:." Q~tr I 17" tt~~~+<</Wield,<<rest ,'I hr p<<4 Iree Inthth'I~~~~~~~~~~~~~~~~~\/I ss<I'~I.Well<1 I(I~Et.;II)r1'(/4,?c?jf3'I<<Jr?O,>>i194 Well(20 M'"gtrlr<<EI...(~~~4)g ssL pcs rS Iersr 21 62 22)4.~23 o;24 X C~s burrs 1.I, c 19'"~~r r.('?test I r<<<<t tel yg~,'C-"/I (, 11 25'so NUCLEA Well~Well'-s ps"w tester SI Cemp I~hssr~s~s~wefl PALO VERDE R GENERATING <<\It gars 4 I?sr STATION~<<r<<rl s<<rhII1 s 404~E Qe sl?Ie~Q<<I I,C ,'~(P'i~'S'n-"},~,~31~)j"': t, 4~3"~/~1~~K Jl Qv I sert Ferms tlt Well 1+IEEell 17 1 ell~9 I?4 1S'.'17 L'l 4 ss r'-~I<<: '/l'l 13r'~s 4 1S 14 W I+I<<,/" I')VAh<<4 s, ,r C'1~m-<.J~Q.13 r Weh etxrl~mp~4 hse hhl Itrlrntttrsn Sthtron Ish s s'1~ss~J i en)F'9 4 r<<~tet<<el p'Cemp.,W"',4'sssssss 30 NORTH M 0 1 Ml s.//g4 Itr.l Palo Verde Nuclear Generating Station ER-OL SCALE LEGEND: I~~!5 0 30 REPRESENTS LB0 OF 30dBA COMPOSITE EVENING SOUND LEVELS Figure 2.7-2 I J)I J P 1 Qletel I~P(l II I oel 18 OC O e I~Ci t 17'(Lie(el~>I P(l (OR I COO~0~~00~0 0~~I eu/I 1~I Wto(et ffrel~a(15 IO(>>intelaburg ~~~~~~~~~~~~~I~~~~~~~~~~~~~I~, I~1 24 Well'I 13 le Qsa RC rO'-19 Well I IIXV~t V>I~I l 3 4't~0 00 0>tee~21 27 22~~~Ie 23 0 24 0 f 0~~0 00~0 19~I~000 00~30 e(I Jeaow r!I'yl pot(ca>ye>(@ 6'9 32l((/(.Ot Well'~F',~'ell~0%tea(R~0>mp~I~0~0 0 0>3 1 Well aI>$~'I I 3 t>~0 1 I 31 ATION'I~~0%(~00 Isa 0 I~/j), r'.I , l PALO VERDE NUCLEAR GENERATING ST~0 t Ot 1 I 1'1\\1 2S 38 BA%a;31 I 24 ,6 7/8,~(I De>el t pe(ms el)!((Well 1 8'I I all~II~II II~II~I(~18'27 Well x~pep, 000000 0~0~lell 3OO*~~19 000000 0 0~0~000, 00~00 20 Weu POI l f Well~el>~9 I IC 0 10 r I 000 (r l)~!1 1S I/ep'!I e~l I (~Itp1O>l+, 21: j ((22 e ps (~16~.t eel~a 11 11 I 12 pRO vpa>>I OOI 24 I t 0~00 t>>I Imp'l(~wph an aal Arlington Station~tete>>I CIIRP, I 24 J II'3 0 g 00000 Weu Qe)~0 O'I 28S, z..'00~00'(25 l 2..os 30 NORTH F 0'i Ml Palo Verde Nuclear Generating Station ER-OL SCALE LEGEND: O 31 REPRESENTS Lso OF 31dBA COMPOSITE NIGHTTIME SOUND LEVELS Figure 2.7-3 J J I i I I PVNGS ER-OL APPENDIX 2A RESPONSES TO NRC UESTIONS 1 l I PVNGS ER-OL TABLE OF CONTENTS Question 2A.1 Question 2A.2 Question 2A.3 Question 2A.4 Question 2A.5 Question 2A.6 Question 2A:7 Question 2A.8 Question 2A.9 Question 2A.10 Question 2A.ll Question 2A.12 Question 2A.13 Question 2A.14 Question 2A.15 (NRC No.(NRC No.(NRC No.(NRC No.(NRC No.(NRC No.311.1)311.2)311.3)311.4)311.5)450.1)(NRC comment.on section (NRC comment on section (NRC comment on section (NRC No.291.15)(NRC No.291.16)(NRC No.310.3)(NRC No.310.4)(NRC No.310.5)(NRC No.310.6)ll 2.1.2.3)2.3)2.3)P acute (6/18/80)2A-1 (6/18/80)2A-1 (6/18/80)2A-3 2A-3 2A-4 2A-4 2A-4 2A-5 2A-6 2A-6 2A-7 2A-8 2A-9 2A-9 2A-10 March 1981 2A-i Supplement 2 0I'I l~ PVNGS ER-OL ll*('1 3((//School children should be included in table 2.1-3.RESPONSE: The response is given in revised section 2.1.2.3 and table 2.1-3.(6/18/80)2.3 l((Meteorological data should include most recent one-year period (11/78-11/79). RESPONSE: Meteorological data have been continuously collected at the PVNGS site since August 13, 1973.As a result, August 13 has become the anniversary date for annual meteorological reporting. In the preparation of the PVNGS FSAR and the PVNGS ER-OL, the latest documented annual meteorological data available in conjunction with the submittal schedules of these documents covered the period August 13, 1977 to August 13, 1978.This period represented the fifth consecutive year of meteorological monitoring at PVNGS and a detailed report covering the five year period from August 13, 1973 to August 13, 1978 was prepared.These five years of meteorological data became the data base for the diffusion calculations used to assess the radio-logical consequences of plant operation in normal and postulated accident conditions. Areas of the FSAR and ER-OL affected by these calculations include: 1)Short term (accident) and long term (routine)'diffusion estimates (X/Q's)(FSAR section 2.3 and ER-OL sec-tion 2.3)2)Environmental assessment of the radiological impact from normal operation (ER-OL section 5.2)September 19'80 2A-1 Supplement 1 PVNGS ER-OL APPENDIX 2A 3)Evaluation of compliance with 10 CFR 50, Appendix I and 40 CFR 190 (ER-OL Appendix 5B)4)Environmental effects of accidents (ER-OL section 7.1)5)Design basis accident consequences (FSAR Chapter 15)6)PVNGS Emergency Plan This data base was also used to assess the air quality impacts of cooling tower operation (ER-OL section 5.4).The use of these five years of meteorological data (the latest available 5 years of data when the FSAR and ER-OL were being prepared)provides a superior basis for the above calculations than two annual cycles of data required by Regulatory Guides 1.70 Rev.3 or 4.2 Rev.2.This position is supported by the considerable increase in statistical significance afforded by the use of a five year base, since it provides a much more representative view of the long term climatology of the site region.It is considered that the use of a 5 year data base exceeds the intent of both Regu-latory Guides 1.70 Rev.3 and 4.2, Rev.2.Subsequent to submittal of the FSAR and ER-OL, meteoro-logical for the latest available year (August 13, 1978 to August 13, 1979)were analyzed.Dispersion factors calcu-lated from this data are comparable to those calculated for the five prior years as presented in the FSAR and ER-OL.In addition average values of climatic parameters during this period are comparable to the five prior years.For these reasons, we request the NRC reconsider the request for revised meteorological data.Supplement 1 2A-2 September 1980 PVNGS ER-Of APPENDIX 2A K No monthly mixing height data.(6/18/80)2,.3 RESPONSE: The seasonal mixing height data provided in ER-OL section 2.3.1.2.7 are adequate to represent, the mixing heights of the region.These data are the same as that'rovided in the Environmental Report-Construction Permit Stage (ER-CP)for Units 1-3 and the ER-CP for Units 4-5.In all dispersion calculations o was constrained to values less II Z than 1000 meters.This is consistent with average afternoon mixing heights for all seasons.Therefore, dispersion calculations implicity account for mixing heights appro-priate to the PVNGS climatic regime, regardless of whether monthly or seasonal data is'sed.9*.(.11 2.7 Provide a discussion of noise sensitive land uses in the vicinity of the plant site.The discussion should describe the type of land use (e.g., hospital, cemetery, school, residence, wildlife management area), and its location and distance from plant noise sources such as cooling towers, circulating water pumps, plant transformers, switchyard, steam vent locations and outdoor paging systems.RESPONSE: The response is provided in the revised section 2.7.March 1981 2A-3 Supplement 2 PVNGS ER-OL APPENDIX 2A QUESTION 2A.5 (NRC No.291.16)2.7 Provide a discussion of all significant barriers (natural or otherwise) to noise propagation and ground cover (such as groves of trees and other vegetation) that could possibly affect sound propagation to offsite areas.Indicate their location;extent, elevation, proximity to noise sources and noise sensitive land uses, and estimate their effect on noise propagation offsite.RESPONSE: The response is provided in the revised section 2.7.QUESTION 2A.6 (NRC No,.310.3)2.1.2 Based upon available 1980 preliminary census counts, locate on a map all population centers within a 50-mile radius of PVNGS, including all towns, cities, and unincorporated communities. Update of tables 2.2-1 and 2.2-2 in the CP-ER would be appropriate. RESPONSE: The response is provided in the revised section 2.1.2.QUESTION 2A.7 (NRC No.310.4)2.1.2 Provide updated zoning and current and future land use plans for the 0-50 mile radius from the site, including Maricopa County and the Phoenix area.RESPONSE: Four counties are included in a 50-mile radius of the PVNGS: Maricopa, Pinal, Yuma, and Yauapai.Zoning maps are available for Maricopa County, including the City of Phoenix, and Pinal and Yuma Counties, but not for Yauapai County.Current and future land use plans are available for Maricopa County, including the City of Phoenix, and Yauopai County, but not for Pinal and Yuma Counties.The Supplement 2 2A-4 March 1981 PVNGS ER-OL APPENDIK 2A following items will be sent under separate cover in fulfillment'of this request: Zoning Information 1.Maricopa County, Unincorporated Area, Zoning District Maps, various dates.2.City of Phoenix Zoning Maps, various dates.3.Pinal County Zoning Map, including Hidden Valley area inset, May 13, 1968.4.Yuma County Zoning Maps (Area No.4).Current, and Future Land Use Plans Maricopa Association of Governments, Transportation and Planning Office: Guide for Re ional Develo ment and Trans ortation, July 23, 1980.2.Maricopa County Planning and Zoning Department, Westcentral Maricopa County, Arizona Plan, October 1971.3.City of Phoenix, Arizona, Phoenix Conce t Plan 2000: A Pro ram'for Plannin.5.City of Phoenix, Arizona, Interim 1985 Plan.Northern Arizona Council of Governments,"Regional Comprehensive Plan" and"Existing Population/Land Use" (Yavapai County).g*'2.8(.1.5)2.l.2 Explain the method by which the 5-50 mile radius population figures in Section 2.1.2.l were calculated. RESPONSE: The 5-50 mile radius population figures were calculated in the same manner as the 5-10 mile radius population figures, as noted in sections 2.1.2.1 and 2.1.2.2.July l981 2A-5 Supplement 3 PVNGS ER-OL APPENDIX 2A QUESTION 2A.9 (NRC No.310.6)2.1.3 In addition to traffic counts provided in the OL-ER Table 2.1-4, please provide traffic counts on the following roads: 355th Avenue Elliot (Ward)Road 339th Avenue Van Buren Street Wintersburg road heading south from the site, and U.S.Highway approaches (I-10).Identify any places where traffic congestion or problems of interference with patterns of local and pedestrian traffic might be anticipated. RESPONSE: The response is provided in the revised section 2.1.3.1.6. QUESTION 2A.10 (NRC No.311.1)2.1 A number of discrepancies between information supplied in the PSAR vs.the FSAR have been noted regarding information con-cerning the site vicinity.Examples of such discrepancies are as follows: (a)The CP lists the PVNGS site as being 15 miles west of Buckeye and 36 miles west of Phoenix, whereas the FSAR lists these distances as 16 and 34 miles, respectively.(b)The PSAR lists the elevation of the northern site boundary as 975 feet MSL, whereas the FSAR indicates 1030 feet MSL.(c)There are some differences between the PSAR and FSAR in the distances and even some directions of the towns and communities listed.Supplement 2 2A-6 March 1981 PVNGS ER-OL APPENDIX 2A (d)There is considerable difference in the population distribution shown on the charts in the CP and OL sub-mittals.The distribution in certain sectors is con-, fusing.Following is an example of some of the obvious population shifts noted in 6 of the sectors.40-50 N NNE 30-40 ESE SE 20-30 SE SSE 0-5 NW NNW CP-1970 OL-1978 CP-1980 OL-1980 II CP-1990 OL-1990 CP-2000 OL-2000 CP-2010 OL-2010 0 3397 0 3623 0 4621 0 5935 0 7622 2698 358 4261 381 6291 187 8682 625 11983 803, 955 0 534 0 0 916 0 502 1439 0 788 0 0 1168 0 640 1986 0 1088 0 0 1500 0 822 2741 0 1501 0 0 1927 0 1055 125 0 0 174 197 0 0 186 291 0 0 237 402 0 0 304 555 0 0 390 The above data is representative but does not include all of the questionable population numbers noted through-out the document.Please resolve these discrepancies and amend the FSAR, as appropriate.'ESPONSE: A review of the data presented in the PVNGS FSAR indicates that the statistics stand as correct and should be used as the basis'or evaluation of environmental impacts.'The difference in the data reflects refinement of the population modeling methodology since the PSAR.March 1981 2A-7 Supplement 2 PVNGS ER-OI'PPENDIX 2A g*.1 (.11.2.l.3 The population for the year 2030, for the cities of Avondale and Goodyear has a higher residential population than the sector (E)in which these cities are located.Please resolve this discrepancy. Also, explain how the population projections for the entire 30 mile radius around the site can be lower than either of the above (Section 2.l.3.6).RESPONSE: The reason for these apparent discrepancies can be explained as a function of the methodology employed in preparing the population distribution projections. As noted in sections 2.1.2.1 and 2.1.2.2, 1978 population distributions are based on the location of U.S.Bureau of the Census-defined population centroids relative to PVNGS.2.l.3 Sun City has been designated as the nearest population center as defined by 10 CFR Part l00.However, since the projected population for the cities of Avondale and Goodyear, which are closer to the site than Sun City, is expected to reach 25,000 prior to the end of plant life, please amend your application accordingly by designating Avondale/Goodyear as the nearest population center.RESPONSE: FSAR section 2.1.3.5 identifies two sets of nearest.population centers for differing time periods.Sun City for the period 1978 to 1995;and Avondale and Goodyear for the period 1995 to 2030.Since the latter designation is based on projections only, it appears preferable to leave these designations as such in order to clarify the reasons for designating Sun City as the nearest population center.Supplement 2 2A-8 March 1981 PVNGS ER-OL APPENDIX 2A ((*.(.11.2.2.2 Southern Pacific Pipelines is"currently studying the feasibility of installing a pipeline parallel to the existing pipeline" which is 4.5 miles from Unit 2.There is no indication as to whether the new pipeline will be closer to the site, or exactly where it will be located.Please discuss the proposed location more fully and provide all pertinent additional information regarding this pipeline.RESPONSE: Southern Pacific Pipelines does not now plan to construct a second pipeline parallel to the existing line for transport of refined petroleum products.Section (a)2.1.3.1.6.4 has been revised accordingly. a~McDanxel, R.R., Manager, Engineering, Southern Pacific Pipelines, Inc., telephone conversation with Higman, S.L., NUS Corporation, February 20, 1981.((*.1 (.11.2.2.2 Provide more information on the current, status of the proposed energy research park and petroleum refinery mentioned in the FSAR.RESPONSE: FSAR Section 2.2.2.4, Projections of Industrial Growth, includes a brief discussion of a tentatively pro-posed energy research park and petroleum refinery to be located within a 20-mile radius of PVNGS.A preliminary report and plan was submitted by the project developers to the Maricopa County Planning Department in June, 1977 for information only.No further action had been taken by either parties, i.e., the developer or the planning depart-ment, during the time the FSAR was prepared and submitted. March 1981 2A-9 Supplement 2 2 PVNGS ER-OL APPENDIX 2A The Maricopa County Planning Department indicates that the project has been abandoned.In conclusion, it appears that the project can be stricken from the record.Section 2.1.3.2-1 has been revised accordingly. a.Rengenburg, L., Principal Planner, Maricopa County Planning Department, telephone conversation with Higman, S.L., NUS Corporation, February 20, 1981.1 (1)2.3 Provide a magnetic tape of hourly meteorological data for the five-year period described in the ER-OL.The data should be in the format described in Appendix A of the Draft of Revi-sion l to Regulatory Guide 1.23.The tape should be compatible with IBM computer equipment. RESPONSE: The tape is being provided under separate cover.Supplement 2 2A-10 March 1981 PVNGS ER-OL APPENDIX 2B ANNUAL JOINT FRE UENCY DISTRIBUTIONS OF WIND SPEED AND WIND DIRECTION BY ATMOSPHERIC STABILITY CLASS FOR PVNGS BASED ON 35-FOOT WINDS Au ust 13, 1973-Au ust 13, 1978 0 SI4HILI fY CL4SSI.4 ELEYAIII)4I 55 FEEI DI REC I Ill"I~5~74~75+I~5 I~5 I~2~5 h>>NNF, NE ENE ESE SE SSE S SSw 8tl WSW I>>>>It W NN tl YARIASLE TOTAL8 V 2 1 2 L a 2 3 I 5?-.3 0 I.0 31 I 3 3 5 7 lf lh Iu 7 lf 3 3 0 0 0 n I 1'5 7 12 12 13 15 4 4 5 1 2 0 0 IVZ 1 5 I 6 15 I5?8 15 23 f8 12 tf 5 2 2 I 0 V h 5 22 24 29 39 24 11 5 7 1 0 V L96 200~il IIELT 4 1 55~0)FEE'T 5~Sf~b~5 2'I~$~5 3~Sf 4~'5 4~51 5'HOUR IIILI 8 PER 5 5 4 15.$4 29 32 08 77'I vl 59 i?7 10 5 9 468 9 12 28 29 8 18 52 1$7 223 120 60 f7 6 8 0 719 3 2 Io 21 3 7 21 75 218 105 al 23 17 21 618 27 28?I9 Zo3 0 0 0 5 12 5 0 0 3 15 45 7 18 9 6 0 2 3 7 64 8 2 3 25 bl 182 57 28 50*20 24 0 156 LZ0 125 20$818 577 178 fo8 64 69 0 517 Lt?0 502V 6'f>>ts~5 4~Sf le 5 ll~Sf~fa~5 14~Sf+20~5>20'5 PERIODS t)F CALN)I hJ I I HOUR'I 5 5 7 II I 12 17 5 I 5 7 2ll Zn I t)24 17 7 3 2 I il I 54 3 3 I 1 3 7)II 2 i)I?I I 0 V tl9 0 V 0 0 0 0 0 0 0 0 n 0 n V V II>>l Nt)E.NE E NF.E,SE se SSF 8$$+SW ANDRI NW N tlh VAR I ALII E TOT AI.S 1 5 Ib 19 43 i?9 57 5v$7 Il)3 4 II 298 22 55 4 II 41 4I 25 t?5 15 Lu 5 3?$0 30 30 2h 22 14 5 2 0 5 0$il I I?4V STAHILI I Y CLASS!8 tLEItA f IONI 35 FFF I DELTA I (200~4 35~0)FEET DIRECT IIIN~5~74~75+I~5 I~St~2~5 2~51+5~5 3~51 0~S 4~51 5~5 5~51+6~'5 IIILES PER HOUR 7 3 6 9 46 68 0$34 09 66 90 bv 22 8 4 5 0 52n 8 4 13 Sg 42 12 18$8 L)n IZ7 106 7 IO 0 but 0 5 7 5$17 0 3 10 27 71 07 27 18 6 It 325'5 4 5 31 4 3 5 20 59 21 9 18 fv 9 0 2VS 0 0 0 3 5 0 3 2 2 5 8 0 5 4 0 2 00 28 07 91 280 271 t95 Z08 245 i?82 044 270 142 Of 45 2713 hySL+8~5 8~Sf~I I~5 I I~Sf+la~5 10~51~20~5>20~5 TU'fAL P 8 R I l I 8 8 l IF 0 4 L Ii 8 HOI I tt 8 ST A>>1L I I Y CLASS)C E LEVA T]C)>c)35 FEET t>EL]A I (200~CI~SS, 0)F f ET D]RECT J))>c,'b" c 4~75 1~S)~St~7~'5 2~5]3~5 3~S)4~5 4~Sf<<'5~5 5~51 65 6~S>~8~5.'I]LES PER>ll'Uk 8,51 11,5 f f,b]14~5]4~51 70~5)20~5 IUTAL NNE NE ENE ESF SE SSE'SS>c I Slc>iklc>ck Nk Ic VAk]A)>)f. TQTALS PE R IUDS UF CAL"'S I 0 0 0 I I I 2 3 0 n 0'I 1 0 0 0 0 ln>IQURS 0 S 2.0 5 12 17)I tl 7 3 0 I 2 n 6 c)h 13 26 45 50 27 5>>24 4 5 9 3 3 4 0 25S 6 1]n 20 30 nh 56 42 c>9~32 fb 15 8 6 0 SS>>1 4 1 0 17 44 Uh 46 47 SS 35 I'5 13 9 ll 2 0 395 1 5 7 10 Sl 32 45 31 36 40 te 9 3 1 li 0 354 6 10 1'5 45 52'9 23 Sl 78 fnh bh 24 lb 9 0 541 4'5 12 56 cl I 8 8 15 Sb 88 63 39 20 14 10 0 421 0 4 9 39 12 I 7 27 50 28 13 16 16.5'0 234 1 0 3 5 c?3 2 I 4 15 44 20 13 12 12 6 0 165 0 2 I 1 1 1 I 0 5*7 2 1 3 1 1 28 SO Sb 60 109 321 SOS 254 205 245 295 395 237-.132 91 5S 51 0 2849 5 5 1218 52=11 2.11 29 92 187 81 4S SS 28 IS 0 644 0 0 5 2 11 4 5 7 57 13 13',5 20 1 145 5 8 6 17 11 21 9 1 21 57 SS9 95 56 35 2S IS 0 595 ll 13 64 134 112 49 2h Uc>94 157 I in 12 35 27)3 I'79 10 19 8 58 123 78 20 12 29 lul 219 inn 101 c>i 22 19'950 9 12 25 38 82 86 51 48 he hb hf ho 35 20 10]1 0 cc cc Q 7 17 59 55 91]52)f8 95 99 tn)(cb 57 3a 29 c?))9 0 Inc 2 26 33 hS 5s)134 165)18)Sh f47 154 1]n Sh 4)Sl 27 2u cl 13'>2 ll 32 42 95 145 155 1 nc>13cl 124 110 96 I 1 Se 7 ic IH)h~c I 2N'I 31 25 32 33 10 87 I I 0>>S 89 So SU S9 25 i?1 c?1 c?5 0 Ic 34]4)0 5 26 13 22 23 22 lh 20'I 0>2 5)S 0 773 0 0)0 2 0 2 0 n 0 0 II 0 0 0 I>>>')E NE F.I'E ESE SE SSE 8 Sec Sa>>Sc>cga>IN>.Nc>VAR]A>)>E T>)TALS STAI>]LIT'> CLASS)D f I FVA Ill)>>'5 FEET DELTA I (200~II 35~0)FE)I DTRECT]l)N ~5-~7 I~75 1~5 1~Si 2~5 7~51-3~5 j S)-),5 4~51 5~5 5~5]-h,b 6.51 5~5 8,51 11~5]1~Sf 14~5 14 Sl 20~5>20 5 I>fLES Pf k>>UUk TU'IAL 129 174 261 cl47 947 567 112 612 655 861 1144 725 462 321 2fe 167 U 5736 4EII]l>DS l>>f cL.IS Ic>>\II>3 ST Arr IL I I v CLASS I'LEvAT IUrrl 35 Ff EI DELI)IRECT Ill'r~5~~74~TS I~5 1~51 2~5 Ze5$~3eS 35~0)FEI I ZIJO.V-A T (3'$4'4~Sf SrS 5.5$-6.5 NI LES Ir E JI 6~51 JI~5 8~51+1 1~5 1 1~Sf+$4~5 lu~51+20~5>ZO~'5 TUIAL lr Nr)E NE EIJE F.ESE SF SSE 8 SSw W iWWW rr rr)rrJW VARI AHl.f T(ITAI.S 2 2 3 1 0 2 1 1 0 0 1 2 0 1 r)18 IP$6 la 15 15 12 7 A$0 15$0 15 11$1$5$0 0 2$4 un i?5 55 P.h P.5 S5 S8 59 52 np 3S 38 3V 18 26 32 563 SA SP 52 49 46 na 57 52 72 51 af 28 32 23 SS 2rl 0 681 i?6 SP ab 37 ll V 42 29 55 43'lb 54 uj i?8 21 26 17 0 SP2 IS 30 32 30 ul Sa 26 Zrt 48 ht 12 49 36 23 21 16 0 511 17 PS P.S Srt SV 29 21 28 PP 50 83 SZ rl8 20 13 11 0 5$7 ll 22 P.3 52 58 43 38 22 44 07 190 151 110 54 jl 20 0 981 15 22 44 14 Sj 10 15 St tt9 Sla 280 106 94 40 24 0 1261 11 7 17 52 15 6 it 15 bf 215 132 49 57 70 11 0 745 9'll 9 3 tP 1 9 9 11 56 120 39 20 47 57 f9 0 439 0 1 1 0 S 1 2 1 0 6 3 0 2 0 0 32 206 237 266 321 403 287 254 289 365 611, 1145 857 481 S70 350 0 6614 rFRIOOS (rF CALIIS 13 IJUURS I I RE C I I I)u 54 68 50 40 50 ST 2u 22 SA 45 72 71 SA nZ rr 0 Sr)0 77h 28 al SS 36 24 22 21 P,'5 35 4$71 42 Se 40 Zh SS Qrrrr 11 19 67 55 55 Qu SS 30 bV 67 63 66 56 5I 45 61 0'l I rr 71 hb hu 50 Sl Sh 51 SH 51'l2 47 Qrr uv rl r)'I 3 0 Wgrl 99 73 9S hh 60'56 61 4P Tn 41 61 62 bn nd hl'l 0 I rr 5'I 23 11$4 23 fh 18 i?I$5 P.O f4 ZP 22 I P.i?2$7 0 284 20 will rr)r rJF.8 f.KNE E ESE SE SSE 8$$W$>>W$W W W rrr W NW VARIABLE TI)TALS 0 1 0 0 2 0 1 1 2 0 0 0 13"FRIr)0$rr~C:rt"S 8 I AAILI TV CLASS)F ELFVATII)rJI 55 FEET UELTA I (ZVV~')35~0)FFf I~5~7 J~75rl~5 1~51+2~5 2~5f 3~5 3~51 4~S 4~51 5~5 5~St~hyS rrtLES pER IIQUM 33 31 32 Sa 41 14 20 18 26 du lhT lr)b 117 hl 51 rJ2 r)857 23 19 14 Zb 30 9 3 9 10 67 1 (IT 11S 40 44 4'I 0 I)8 10 14 P 6 4 1 1 0 4 5 SS 9 0 5 f~)V 114 2 3 1 0 3 2 1 0 1 0 I 0 0 1 1 1$7 414 412 S71 SZl 557 268 Zjb ZSS Sf8 398 125'551 499 310 Sa9 S/1 V 6156 6~5$8~5 8s5$~$1~'5 11~51~$4~5 14~51~20~5>20~5 TUTAL ST Ao]LI T)'LASS)tll;E HE FtE E: ESE SE SE S 8 S!ik S<<!Sw kitik!th)!kryo!VAVI At$LE TOTaLS'5 5 1 1 2 3 4 5 3 3 5 5 2 0'b2 99 75 b9 57 4$4)37 24 42 44 3(!5?.36 02 44 73 0 7b?ELE'v A T I!)h.]OIIIECTIO+ ~5~74~75<<]F 5$5 ff K.f fo5]?ob?34 2)3 115 115 117 7n 77]VS 74 71 97 n9)4V]97 0]951 3b z'ku~0 (>EL)a 1 (a,51-5.5 2s5]3eb 3,51 aeb t!(!V 229 319 t)]LES PER$91 022 394 35b 2l!6 119 1 3(k lzl 50 56 73 69 115 79 74 142 2b8 0 2496 1'b'5 b6 96 k)b 55 31]oj 21 zu 04 aa 22 56 130 0 fabu 2VO 94]up 122 49 41 167.bu~49 oz 7 t)44 H2 193 0 22U2.u)FEET 5.51"6.5 R]04 211 96 29'54 3b 1'b 6 Su lu 15 5!)52]6 29 47 0 817 97 I 5k)75 27 49 22 5 24 12 31]0 14 15 2V 07 0 6]0 00 1V]ua 7 14 3 1 8 3 23 5 6 2 6 ll 0 2/5 25 7 S 1 0 0 I 0 1 2 0 0 2 0 51 13 lbaZ 15ob f055 469 ob9 ba9 S02 2ab 687 3UZ 317 395 S5b SuS b$1 9ol lu715 6~'bl 8 5 5~51 11'b 11~51 10~5 la~51 20 5)20~5 TUTAL~PEI)I(!OS OF CALLS N]k!I)ukt 8 S)af)ILJTY CLASS)ALL ELE)IAT]k>>l I 35 FEE, T OKLTA T (2VV~0<<55~0)DIRECT]Ok) ~5~14~75 1~5 1~51?~5 2~5]3~5 3~5]" b 4 Sf<<b 5 S~P~5]<<n~'5 6~'51 8~5 8~51<<11~'5 11~5]<<]4~5 14~51~20~5)'20~5 I (/1 AL ti kE E~E E ESE Sl SSE S SS<<8>>kI8 Y'<<kyle be Pl,<<VA>IASLE'T',!T A L S 7 6 5 12 5'5 9 4 4 4 7 5 6 4 94]49 118 94]uk)HS 1!7 77 9)!9b 85 HV Hf 71!92 113 0 la98 385 337 3')5?35 27/3(h 3l 5 350 31 t)254 21 l 2SS 20u]b3 2S8 3vn 0 439o So9 SVH 068 359 a3?ubZ a<<4 545 347 21?2$0 175 262 572 0 6076<<i(f.S PER bh9 S85 575$)9 II 4 6 anH Sn]55k)455 552 zoo 2bu 2]fk 142)bj 304 0 5658 k!Ok;fl S]u 44t)299 2$v 3'b 7 38u S55 278 399 3ob 524 Phn 2oo 130 165 220 0 aab7 2vS 295]9$flu 26a 27I))91 2)3 29V 212 SS7 224 19o 1v5 94 114 0 3450 113 8]75 38k)$45 225 159 2hb 488 da2 bo<39'b 199 lu7 14'5 0 4956 107 115 105 lb2 Sk)4 zs'5 11 H]]63 ba3 1151 529 4$2 2S5 145 12S 0 4965 45 6$39 Il?7'b 57 24 ju 84 25$75o 411 189 f49 140 74 u 2683 25 27 54 39 f92 28]7$0/3 244 b95 215 113]63]29 73 0 2000 1 I 9 S3 10 8 lu 12 nb/7 Zb 12 45$8 10 0 3ab Zu54 2799 2 1!I I]HS1$170 27u1 zu17 1922 2 lab 52uu 495o S39b 2219 lb9$1640 1861 0 40801 PERIOOS OF CAL"S 73 hOuRS PVNGS ER-OL APPENDIX 2B OlISFHVATIQtlS HIT4 1ISSINU t)ATA 29 JQ TllT AL Ol<SEkV AT IU>S FOR l<f PF HI(>V Ah)4VH70 PERCENTAGE I)CC<lfthEHCE flF Sl A~ILITY CLASSES 7'~6~6A F 97 I)E F 71~S>16~21 15~11 26 F 20 2B-5 0 PVNGS ER-OL APPENDIX 2C ANNUAL JOINT FREQUENCY DISTRIBUTIONS OF WIND SPEED AND WIND DIRECTION BY ATMOSPHERIC STABILITY CLASS FOR PVNGS BASED ON 200-FOOT WINDS (Au ust 13, 1973-Au ust 13, 1978) 4l OI RECT IDN~N ttwE NE.EtlE E ESE SE ssE 3 SSH 3>>h$h QHh Nh NNH V<RI>t)LE TnfaLS PERI(>f)3 QF n 0 V 0 n n 0 0 0 0 0 0 0 0 0 0 0 0 CALNS 0-n n 0 1'0 0 0.-0 0 0 0 1 3 Hl)(IR 3 T 1 2 0 1 2'2 1 1 9 1 n f4 0 4 1 2 5.4)5 7 7 6~I 3 1 1 1 0 57<)LES PEN 2 4 11 13 12 13.7 5 4-2 1 1 0 91 tttiVN 4-S 2-.7 11)2 ll 7 14 3 21.2 ,0 101 1 5 2 10 6)5 21 15 27 17 12 13 2 1 155 6 4 7 tu 51'5 47 46 65 18)El 7 5 5 0 344 8 lt 0 11 22 23 13 26 46 124 162 77 41 fO 5 7 0 599 6 6'12 31 27-8 lf 26 103 t74 74 42 10 12 556 3 4 8 13 72 11 3 3 29 11P 253.78 42 37 21 20 0 725 0'4 52.4 0 0 9.59 82 23 1'6 24 l6 0 2)5 SfaBILITy CLass).4 ELEdlfI(lN) i?00 FEET pFLTa T (Zunian~35~0)FEEf 5~74~7$-).5).51-2~S 2.5f 3.5 3,5)-4.5 4,5)-9.5 5.5)6.5 a.bt 8.5 8,51-11.5 f),5)-)4,6 14,51 20,5)20.5 I()fAL 28 40 40 70)P9 130 l)6 150 212 46P 768 293 172 99 71 7.2.0 2018 DIRECTION N NWE NE ENE iE ESE SE SSF.S.SSh.-Sr W 3 I>>Wtsh Ha t4 flH VaRIAt)LE T(iT AL3 5~74~75~)~5),5)~2'0 1 3 0¹STAHILITy CLASS)ELEvlll)UNT Zuu FEET 1 1 6)5 15 15 ln 7 2 2 2 2 2 n fuh<ILES PF.R 3 5?)4 13 25 29 20 22 Zt 6 2)5 0)ti9 H()UN 5 7)6 10 28 34 57 i?3 17 9 9 6)0 259 2 t)f4 7 17 SS 35 Iln 51 25 i?5 18 Tu 5 5 0 PHP 6 ll 10 19 en 5)4¹32 61-b7 6V 29 17 4 6&4¹nN 7 6 9 19 bS)9 25 V9 9¹64)2 11 1 iJ ibZ 7 5 5 9 57)4 4 i?6 55 86 64 30 f¹5 9 0 396 6 6 13 Of 4 1 1 7 25 04 20 i?3 27 11 8 0 Suv 1 1.0 3 14 2 3 5 Zf)0 8 P¹V luS l)FLTA T (200'~'3')FEET 2'1 3'3')4 5 4'1 5'5'1 6'6 51 8 5 8 51 11~5 11 51 14'14 51 i?0 5>2'ruriL 53 42 61 105 289 2i?3 190 177 251 3)9 410 251 154 7P 47 48 0 263'9 PER)t>n3 l)F ('h('is n.Nfl'tNS 81AHTI.TTv r(.aSSI.C ELE<raiTUNI 200 FEE I l)ELLA I (ZVO~0<<35~0)FEI T DIRECT lf ill~5~74~75<<1~5 I~51<<?~5 2~'51<<5~5 3~5l 4~)4~51<<5~5 5~51 6<')6~51<<8~5 8~51 11~5 11~5(<<14~S 14~51<<20~5)Zv~5 T(ITAL N II hE F<8 EIIF.E ESE SE SSE 8 SSN SN NSN NNN NNN YARTASLE T(IT AL8 I 0 1 n n 2 0 0 0 n 0 0 1 0 0 n 0 5 7?0 5 6 53 5 5 6 ll i?4 ZL 25 28 27 9 14 4 3 3 1 1 0 187 l<lLl$PF.R 4 3 13 15 33 4$37 31'3 22 lv lv 8 6 5 7 0 282 l<I<UN 0 H 18 2U 32 54 31 47 35 40 28 13 2 7 6 363 7 12 18 37<IU 35 3U 32 31?4 lb 6 2 3.312 1 8 10 2?.65 47 49 51 42 63 73 42 12 11 16 6 0 518 5 5 4 L5 64 Sl lS 15 29 bo lU5 57 20 15 17 0 467 2 5 5 10 SH 14 5 2 24 63 40 17 13 6 0 257 1 4 28 9 3 2 ll 25 55 25 21 27 8 10 0 238 2 0 2 3 10 3 2 1 1 15 ZL lo 9 9 2 0 94 39 47 75 1<?4 338 Zde Z15 215?22 295 397 215 120 92 69 45 0 2716 PER 1 IIDS DF C AL~:s 0 HI3UIIS N NNE.NE, ENF E ESE SE SSE 8 SSN S<<NSN WNh h<<hNN vARTAHI.E 7<IT AL8 0 2 2 2 S 7.2 1 U 0 v 0 0 0 0 0 0 la 6 5 7 8 11 I7 L7 8 13 6 h 5<I 121 25 26?i?35 58 79 78 75 62 53 SS 25 27 lv I i?15 644 PERT(IDS l<F CAL<:8 5 i<DI<RS S I AB1LT lT CLASS L 0 ELEVATIIII I PVO FEET DlRECl Jr>>~%-~74.75 1~5 L,SL-'2.5 HILLS PER 1'1 25 51 94 1ZH 133 1?4 lv5 1 I a 80 56 4<3 av 13 15 18 n 27 63 eo'I 21 LUO LLO Lvb Lvh'I V5 40 S4 20 21 21 n LVVO LUTU H(I(I R IS 31 h3'I ZS H9 111 79 08 99 Hl?H lb L1 lv v v5(10 16 Zv 46 98 76 85 51 79 51 73 4U ZH 1H 12 0<)1 LH Zvo~0<<DELTA T (35')FEET 5 F 51<<6'2~51<<3~5 3~51<<4~5 4~51 5~5 h 11 Sh$6 (34 121 dv 42 62 03 lv5 Th ab Sd lh le 0 91Fl 21 ZL bL LS7 88 37 ZZ S5 lvo 19a lvb b5 S6 19 ll 0 0>S 5 9 14 29 0S SZ lb 9 28 69 15S 08 64 22 13 10 h<<4 LS 13 9 Zd 77 21 10 7 Sb 87?52 107 57 64 27 11 817 2 6 13 18<?0 lv 6 13 Sn 1'U5 LS2 SB S2 65 24 9 0 5$2 136 2o5 302 507 Loop 766 660 522 658 870 1165 642 427 315 181 LSb 0 65vo 6~51<<e~5 8~51 11~5 11~5'I<<14~5 14~51<<20~5>20~5 TUTAL t)1 RECT f()cc H)IF,~HE EHf.E ESF, SE SSE 8 SS>>II 8W H HH>>" Hlc)IHH VAR]A)c(r T(lt AL8 1 II ll)0 24 I')I 25 74 3cl 23)9 14 lh I]13?ol 0 I)I 1 Il]~STA(if(.f)Y rLASS)E I LEVA t f(III I 76(I F f f t~5 F 74~75<<1~5 I~5)<<c.~5 v 3 1" Il, 0 5.~4 7 6 1 1 6-1 1 1 6 0 7 0-7 10 h 3 4 0 lj 22 58 24 54 jv 2 II 3?3 (I'7 17.15]5 0-1?I)5 7 cl 17]7 52" 21.42 20]8 26 56 15 21 l2 12 n jh?9 ZA 2~20, 37 29 2)2r?4 30 22 15 11'fa-n jhl 15 12 74 35 29~26'5]8?n*.21 Sv 52 16 lu 13 5 0=330 25 43 55 63.56 26 27 47,i 55'I 1'5 75 aa 24 50 12 0 6ov 13 26 54 b8, ((4 52=]P 28 45 lv3 lea 122 74 cl 3 10 c?0 0 012 8-1'5 ,15 36 7.5 21 12 i?8 fn5 258.]ei 1]1 35 36-f7 0 orS?8 25 Zo 45.30 20, la'6 163 431'32'1 14 133 03 15 0 1469 lb 6 lo 0 26 4?17 0 Sb 145 55'7 59 69 i?6 0 Sva r)FL)A I (c?VO~V<<5'I~'I)FF f t?c)I<<jcS 5~.I)<<4~5 4~5)<<5~I 5~51 bcS heel 8~5~51 1]~5 I I~Sl la~5]4~5)20~5>Zv~5 H]LES Pf.t(Hl.VH t()AL 151 fPZ 240 349'ol?67'v7 501,', 6]a]315 757 449 364.302 147 0 6309 PER 1(I(IS I'r q AL)" 8 Ht)VRS H HHF.Hf E'lE E ESF SE SSE 8 SS>>8 II II S g IIH>I I)H HN>>VAR)All(F.Tl)T ALS v 7.2 2 2 0 I I)II 0 1 1 0 1 A Il 17 7 9 Il H 20 0 I?9 ln A 7 7 7 7 7.n)47 29 20 25 74 5CI 23 77 7)I?2 74 72 lj I 5 4 (hcl PER f I I(le III Ctl.'I (I)St Ae]L 1 t~CI.ASS t F LEVA I fll)II?nn r F f'I I)1af C T]r"..5-.7a,7S-I.S I.S)-?.5 25 ah 44 45?II I?5 22 5)I Zl ju]8 lr I'II 4)5 Zb 5)4 Il 55 Zw?1 72 53 Sa 45 ZS 7)1 lb 14~I i)ra Pf L)A I (2I!4~n Z~5]3~)3 F 51<<4'u~5)I I 1 I.f!l P F 4)7 25 51 41 45 75 lr?cl jj 55 55 IIH (9)5 n 47u ucc (55~0)FFFT<<5~5 5~Sl<<h~5 I I I)(J 4)7 30 70 5A jh 26?I]h 3(42 40 4.5 5 Ih)r c 2 (I 20 45 76 44 Sf(42 52]7 h)$lan 09 Sc I)4 jl 74 II AS?20 55 46 56 hl 27 14 20 51 ra 2I)7]au I]4~IZ Sb 55 I 0 Scc 10 54 17?I42 fe ll Zn 69 185 t?7'I vv'I r Sh 52 v II]I 18 28 18 21]1 2 4 72 63 59 76 31 0 7hh 1 20 1?8 7 5 i?4 9 13 3 1 0 7 4 97]pe 537 420 552 414 250 fbo]65 258 461 955 659 476 5]P jjv i?25 v Sobb 51 ec5 8 51 l]IS 11 Sl 14~5 14 51 Zo 5>i?VS 5 T()tAL bl R a M Ic Nr(E ERE F E RF.SE SSE.8 SSW Sw wSH w wow Hw tJ>JW VARTARLE T(ITALS I I (I'1 c)3 7 I i?2 0 3 0 0 cl 3 74 32 77 i?V 28 PR 21 7R 20 32 P.3 20 24 17 24 24 (1 397 18 74 HH 01 (VP.76 IJ 3 72 7r(HL73 7R 61 42 (JS 55 V))9))03)51 127 103 76 7(c 1vl 1L 7H HH 73 bv 71 9)4 147S STAIILLT'f Y CLASS)8 ELFVA'(TII(r)2VV FEE T VEL(h 0)RECT I(!'I~5~74'14 I JS I~5(2~5?~Sl S~>hlLES Pt.h 06 134 lhf h(IUH 09 bR 110 153?VH P.OS 134 12$e0 56 Se.76 ae 77 60 55 5$7i?RO 0 lseb lbl)10 b0 4$53 50 aH hv 49 42 Sl 67 0 fP78)35 7$32 Ie 21 Sl 76 44 37 24 40 5$1v22 35')FEEI 20v~0 5 c5(~la~5 a.b)-5.b 3~51""~b lav 248 524 184 116 47?2 17 a0$0 75 75 60 57 78 114 1625 Vf 219 2$7 98 b5 2f 12 7 22 b3 70 68 40 75 99 1199 30 72 85 25 2$13 2 17 3i?37 32 22 52 0 501 31 70 48 31 17 5 I 0 3 25 5 7 a?9 26 0 310 4 28 IH 2 3 I 0 1 0 0 0 2 2 2 65 784 1326 1551 995 754 473$$6 31'9 469 fflb 543 55b 462 323'bb3 hbS~f0498 6~'bl 8~5 8~bf I I~5 I I~51)rl~5 Iac51~20~5>20~5 f<f AL PEP II!(IS (I((;ALrcS IR H(ll(R S S)AH)L 1)Y CLASS)hLL ELEVhf T(J'(I 2on FEE)(JE.LT OIRECTlevl ~5,1(,75 I~5 I~'5(g,b 2,5)5,'b 2(IV~0 35~0)F EE T m b)4~5 4~Sl 5'5'f~bo5 6'1~8~5 8~51 ll~5 lf~51 14'1'1~2'>20~5 r)LES PFR hfdf!II TUTAL hllv E E IJE E ESE SF SSF S Sew Sw wel lc JJW Nw N(c W VAR)heLE T(ITALS I I'5 15 9)3 h.6 6 2 5 4 I 2 S ef 41 S'3 49 39 63 c(O 56 57 4 (I 4R$6$0 57 (I 77?Ia3 IS1)55)JJV?vg 7)b P.23 I cril 71)(eb)55 I rlS)21 0(J)Vg~IR cl 751H)9$203 31(280 3 rib 20h 303 275 261 2$u feu fbv Ivj 122 lb3 IJ 574/151 22I 512 S?2 SHS$56 SOH 267 24(J c!4cr 196)5b 111 124 13)rl 149 205 SHV SJJ4 Ihb?cr6 P.V3 P.b I?15?67 c19)O'J 130 Ha lol I 27.e(120 221 S26 20V 3vb 2ab 21H 10?264 P.I v 28$2LH)54 84 95 H9 V$29H 205 3ab 5(l3 SH7 bvh 575 2b9 229 Sbl 421 65$4)4 2(9 159 180 10?5" I cJ lbS$43 S(0 SIR 416 276 I27 143 c!6 I bea 990 656 42$2$1 Ivh)HI 57)9 71 144 Iab f42 357)42 6$5$15v 442 949 62$$96 17$'1 7H 126 4164 98 La7 ff3)55 558 av 31 128 Soe 1318 574 327 351 265)30 0 28 bl bv cl 7 I c!I 29 f4 39 be 258 415 117 18 L68 1$5 6S 0 fh/0 1569 2189'724 i!b42 Sbva 2386 1900 1753 2$7I$444 b'b'b 5-S$12 2240 lbvl 1553 1325 0 59696 PER)(llrS<<f ('ALrlH Rn hl JJJ(J 9 PVNGS ER-OL APPENDIX 2C Ollgf RVATIOMS HI IH vISSllvQ'ATA ll>Pb I IOTA(IiRSFRVAT IURS FOR 7Hf.PE RIOI)ARF 3V720 PERCF NTAGE OCCURRENCE OF STAB IL IT Y CI.ASSKS A 8 C n F.F 4 7~35 hib4 6~00 21~01 Ibi11 15~03 2bo07 2C-5 '0, l' 915 915 914 914 913 913 912 n 911 Ll n 910 O I 909 908 LL TL'12 911 I 910 2 O I 909~)908 907 906 U5-Hl 05-H2==--:.U5-H3 t U5-H4 U5-H5 U5-H6 907 905 I I I I I I I I I I I I I I I I I I i I I t I I I I I I i I i I t I I 1979 1978 77 I I I I I I I I IlI t 1977 I I I I I I I l I I I t 1978 t2ltllll ttt 1979 I I I I I I i I I t I I I I I I I I I I I I I I 1977 9 8 I I I I I I It I I 1979 I I I I I I I I I t I t 977 I I I I li i I I I I 1978 I I I I I I I I I I 1979 IIII IIIIII IIIIIli illill I 1978 1977 IIIII Itltll 1979 I I I I I I il I I II 1977 I I I I I I i I at'I l 1978 U5-H6 I I I I I it I it 1979 905 915 915 914 914 913 912 911 I 910 R O~)909 908 913 912 I 911 910 O 909<)908 PRC APERTURE CARD 907 606 905 U5-H7 I lt ill lic ltt I lt I I ltltflll lil ilill I 1977 1978 1979 U5-H6 I I I I i I I I I I I I I I I I I I i I I t i;I I'I I I I i I I I I I 1977 1978 1979:LjU5-H9-=---->i I i I i I I>I" t I I t I I i I I t I t 1978 1977 I I i I i li I it I l 1979U5-H10 111 t I t I I I I I 1977 I'Itliiiftllllltl il ill 1978 1979 U5-H11 lllt liitltl llll tlilli titttit I it tl I 977 1978 1979 907 906 905 Palo Verde ltjnclear Generating Station ER-OL HYDROGRAPHS OF OBSERVATION WELLS IN THE PERCHED-WATER ZONE (Sheet 5 of 5)Figure 2.4-7 QTs Ki QTC QTs QTs Ka as Ka Qb Qb Qb Ka'-'/MTS:...,-;,",,gf'I'i Ki Ki Kr QTs Palo Verde Site Qb'"an,+Kr.I Riff;;<<TA,Nlti 'r~sch Qb gi...h 69 QTC Qs,,.'!:~'I ic!ia'gr'0's Qb Peoria NIX QTC Qb Lgf vfh.rp gf I Lgf//Glendale QTs QTC 94'hoenix 0's Ki s cn Ka gf I vfn Tvfn"','Mv M, K lect+/(.~gT Rll Qb Qs I Qb Tv tn K.Mv.QTbf QTs f, RIYAL)':~aTs~v QTbf~QO R~l Qs:.:: 0's".::..~,":,:.':'.:'.::'S',,:'.:',:,':,'::,,,:':::::::'..':.:::,:::.'::;::..: .<<::::::....,:.'::::::::::::,..':,.'::.::.:,:::">>:...'.":,:': QTC r Qs"',Ty t , I'r/', QTC Qs gr Afeo sheen efl regional geologic map.-EtUCK//gf sch QTC Tv Ki index Map of Anzona QTs gr QTb gf QTs LEGEND Silt, sand and gravel.Basalt InCludes tuff and gravel.Sand, gravel and conglomerate. Basalt flow.O o Dif fsventiatml tanglomerate. Sawn fill deposit.Volcanic tan deposit M/OCene Ufldlffefent/Oted volcafvcs O O Undif ferentioted volcanics. Andesite.4 rt-t s Lgr Granite and related crystalline rocks.O O Andesite includes tuff ond agglomerate. 0 u 0 Dikes and plugs.Rhyolite.Schist includes diorite, rhyolite and greenstone. Grarute and related crystalline rocks.GIanltIC gneisc Fault: Dotted where concealed. Dashed where interred.LITHOLOGY~QTS[QTb~QT bf+Tvfn~Mv~T.v~TG.'ssI~9r:.SYMBOLS a ca as K QTC NORTH Geologic contact: Dashed where opprowmate. A QTs Qb Qb ats as'.'.::;',Qt','Tv Ds: gf I~<<', I//I rl I-//gf'lg','I gr', ARICOPA-MTS: i./gf I I/gf gr sch'f SCALE (Miles)0 Reference/ Arizona Bureau of Mines mcdiriwl by Fuoro Inc.PRG APERTURE Section Location Palo Verde Nuclear Generating Station ER-OL t!EGIONAL GEOLOGIC HAP Figure 2.5-1 Geologic Section Across Palo Verde Site I300 A'AST 1300 I 00 Upper Sand and Gravel Boring PV-23 Boring PV-I R-IO Indura ted Boring Fanglomerate PV-IB Upper Silt Palo Ver e a~r*:.;2 t,;::;:;;.:,';::,":; .'.:,::.:,'::,".::;' Basalt-Andesltec; .'AGNETO S ite Property Boring P V-24 Boring PV-25 HORIZON Upper Silt Basalt-Andestte;". xt~~~i-'W;;.".;;; ~.',";: 'oner Slit xrltn Sand and G~~~e'..::.t'.'.I.x-.'x..'-'..r::;. x','v..x.'.: r~'....'.'."., Indurated.Fantltomerattx..'r:: I I 00 900 n~I a a rn 700 u PRC APERTURE CARD 0 1000 2000 SOOO 4000 Ho izontal Scale in Feet Vertical Exaggeration SX Palo Verde Nuclear Generating Station ER-OL GEOLOGIC SECTION Figure 2.5-2 ait,r.Ek 5;+~~+'1)h N A a N R a Mk~~,h;Žk-"::eu-'&INP'P"<<~I)I)Ij)u T I)I T.T, TVzT)R N CPN N 0 I e PRC APERTURE CARD f'R I'4"', NBA'1,'6 0~8858YATI0 g, AIR@.'" i 54>'y.T N T)L j--sK IR TR/Tuft h,7$Tt...a Reel/T ,'p'i R,'P uTN LEGENO 0 POTENTIAL ACCESS POINTS~kg)I 1 ,I r)/I pII-,tie;)I h.2 I i'I/Pi'e,t-.RNP,'"-$NORTH 5 0 5 10 15 20 Ml SCALE q")':J e L Palo Verde IVuclear Generating Station ER-OL Phe 2 IT 4P:.'RANSMISSION LINE ROUTE PROJECT 3 CHANGE Se March 1981 Figure 3.9-2 Supplement 2 1/au d I I/1/,/4 PRC APERTURE CARD I hhld 4 4 EBON TOLL lh W R R D 4 I I-=+VOIIIDALE I A Id t ,PehP BASE LIN 4 L BASE L IN E tc lll dm 1';.I>>'n~..j I-h/L I R.R...V/4 L Y ,,~~.CKEYE-.P----" C BUG U.S.80/BUCKEYE CANAL TURINlIOUT LINE 86",/'."',,'..'.J PIPE GILA RIVER BASE LINE PIPELINE 114 8 Ill A V E.SE WAG E TREATMENT PLANT j RIVER , d SALT D i r I./Ch CHANGE PALO VERDE NUCLEAR GENERATING GTaTIDN P LUKE AU PIE/Vtiwi j PUMP STATION j'I GILA I R'Q~r~W r;)Cjrg BUCKEYE C AC I D 0 WOW MILES 2 3 SCALE Z.C ,/1,'Rd~@~i',(Qj~9,~~i~~grQ(.~J L ht*Palo Verde Nuclear Generating Station ER-OL PVNGS WATER CONVEYANCE PIPELINE Figure 3.9-5 4 5 Su lement March 1981 PP~CLN~~I.M"45-(Q PRC APERTURE CARD PVNGS ER-OL EVALUATION OF COMPLIANCE WITH APPENDIX I OF 10CFR50 AND 40CFR190 Table 58-1 MAXIMUM INDIVIDUAL DOSES FROM RADIOIODINES AND PARTICULATES (mrem/yr)Pathway Total Body Bone Thyroid Dose from Unit 1 Release Total Body Bone Thyroid Location A Dose from Unit 2 Release Total Body Bone Thyroid Dose from Unit 3 Release Total Body Bone Thyroid Dose from Unzt 1 Rele.ase Location B Dose from Unit 2 Release Total Body Bone Thyroid Dose from Unit 3 Release Total Body Bone Thyroid Adult Ground Plane Vegetable Ingestion Inhalation Total 1.01 1.17 1.31 8.90(-1)1.03 1.14 3.28(-3)3.28(-3)3.28(-3)2.65(-3)2.65(-3)2.65(-3)8.46(-1)1.17 1.02 7.48(-1)1.03 8.90(-1)~1.57(-1~4.14-4~2.82(-1~1.39-1~3.62-4 2~48-1 2.32(-3)2.32(-3)2.32(-3)7.27(-1)1.00 8.52(-1)~1.34-1~3.49-4~2.40-1 8.63(-1)1.00 1.09 6.82(-4)6.82(-4)6.82(-4)6.14(-1)8.96(-1)6.544(-I)~1.19-1~2.98-4 2.1'7(-1)7.34(-1)8.97(-1)8.65(-1)7 79(-4)7.79(-4)7.79(-4)6.67(-1)9.76(-1)7.13(-1)~1.30-1 3~26-4~2.29-1 7.98(-1)9.77(-1)9.43(-1)8.75(-1)1.07 1.04 9 01(-4)9.01(-4)9.01(-4)7 32(-1)1.07 7.85(-1)~1.42-1)~3.5 9-4)~2.51-1 Teenager Ground Plane Vegetable Ingestion Inhalation Total 1.22 1.90 1.53 1.08 1.67 1.34 3.28(-3)3.28(-3)3.28(-3)2.65(-3)2.65(-3)2.65(-3)1.06 1.90 1.21 9.42(-1)1.67 1.06~1.58(-1~5.62-4~3.14(-1~1.39(-1 4~92-4~2.75-1 2.32(-3)2.32(-3)2.32(-3)9.16(-1)1.62 1.02(-1)1~35-1 4~74-4~2.67-1 1.05 1.62 1.29 6.82(-4)6.82(-4)6.82(-4)7 73(-1)1.45 8 06(-1)~1.2 0-1~4.0 5-4)~2.33-1 8.94(-1)1.45 1.04 7.79(-4)7.79(-4)7.79(-4)8.41(-1)1.58 8.78(-1)~1.31-1)~4.43-4)~2.54-1 9.73(-1)1.58 1.13 1.07 1.73 1.25 9.01(-4)9.01(-4)9.01(-4)9.22(-1)1.73 9.66(-1)~1.43-1)4~88-4)~2.79-1 Child Ground Plane Vegetable Ingestion Inhalation Total 2.07 4.57 2.47 1.84 4.03 2.17 3.28(-3)3.28(-3)3.28(-3)2.65(-3)2.65(-3)2.65(-3)1.93 4.57 2.15 1.71 4.03 1.89~1.40(-1~7.34-4~3.16(-1~1.23-1 6 43(-1)2 78(-1)2.32(-3)2.32(-3)2.32(-3)1.66 3.91 1.82 1.20(-1)~6.19-4~2.69-1)1.78 3.91 2.09 6-82(-4)6 82(-4)6'2(-4)1.40 3.50 1.45~1.06-1~5.29-4~2.34-1)1.51 3.50 1.69 7.79(-4)7.79(-4)7.79(-4)1.53 3.81 1.58~1.15-1~5.79-4)~2.56-1 1.65 3.81 1.84 9.01(-4)9.01(-4)9.01(-4)1.67 4.18 1.74~1.27-1~6.38-4 2~81-1 1 80 4 18 2 02 Infant Ground Plane Vegetable Ingestion Inhalation Total 3.28(-3)3.28(-3)3.28(-3)2.65(-3)2.65(-3)2.65(-3)(c)(c)(c)(c)(c)(c)8~06-2~5.37-4~42-1~7.09(-2 4~70-4~2.12(-1 8.39(-2)3.82(-3)2.45(-1)7.36(-2)3.12(-3)2.15(-1)2.32(-3)2.32(-3)2-32(-3)(c)(c)(c)~6.89-2~4.53-4 7.12(-2)2.77(-3)2.07(-1)6.82(-4)6.82(-4)6.83(-4)7.79(-4)7.79(-4)7.79(-4)9 Ql(4)9 QI(4)9 Ql(4)(c)(c)(s)(c)(c)(c)(c)(c)(c)~6.11-2)~3.88-4~1.7'I-1~664-2~4.24-4)~195-1)~728-2)~4.67-4)2~14-1 6.18(-2)1.07(-3)1.7)(-1)6.72(-2)1.20(-3)1.96(-1)7.37(-2)1.37(-3)2.14(-1)a.Location A is 2300 meters north of Unit 1, 2600 meters north of Unit 2, and 3000 meters north of Unit 3.b.Location B is 5500 meters south-southwest of Unit 1, 5100 meters SSW of Unit 2 and 4700 meters SSW of Unit 3.c.Pathway not applicable. X%~'lmXc x%K-1c July 1981 5B-5/5B-6 Blank Supplement 3 HVAC LINES FANS DAMPERS SUPPLEMENTAR Y INSTRUMENT DESIGNATIONS EOUIPMENT R FIXTURES EOUIPMENT PROCESS PIPING LINE VALVES VALVESTATUSSYMSOLS MISCELLANEOUS[CONT) ~IPING IDENTIFICATION 0 2 5-9--*--COILS AIR CLEANING DEVICES FIRE PROTECTION EOUIPMENT DRAINS t Y 0 MISCELLANEOUS

• VALVE IDENTIFICATION HUMIDIFIERS P T 7--*-LJ Qi PROJECT CLASSIFICATION PIPING MATERIAL CLASSIFICATION DUST COLLECTORS LOUVERS STEAM TRAP DETAIL Palo Verde Nuclear Generating Station a ER-OL PIPING AND INSTRUMENT DIAGRAM LEGEND AND SYMBOLS (Sheet I of 2)Figure F-I}}