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

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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. Issue Pa e or Fi ure No. Issue Title Page Original 1.1-10 -, 1.1"186 Original Original 1.1"187 " 1.1'-190 Sup 2 Sup 4 1.1"190A - 1.1-190H Sup 1 ivA - ivB Sup 4 1.1-191 - 1.1-222 Original Sup 3 1.1-223 - 1.1-239 Sup 3 vA - vB Sup 3 1.1-240 - 1.1"242 Sup 4 vi Sup 3 Fig. 1.1 1.1"8 Original Fig. F-1 (Sht 1 of 2) Original 1.2 Tab Original Fig. F-1 (Sht 2 of 2) Original 1.2-1 Original vii Original 1.3 Tab Original Vl.il Sup 2 1.3 1.3-2 Sup 2 ix xi Original 1.3-3, Sup~ 4 xll Sup 4 1.3"4 -,. 1.3.-23 Sup 3 xiii Sup 2 1.3 1.3-38 Sup 2 xiv Sup 4 1.3-39 Sup 3 Original 1 ' 1.3-45 Sup 2 Chapter 1 Tab Original 1.3-46 Sup 3 Sup 2 1.3 1.3-73 Sup 2 1-ii - iv Sup 3 1.3-74 Sup 4 1-iva - ivB Sup 4 1A Tab Original 1 Original Appx 1A Title Page Original 1.1 Tab Original 1A-i Sup 3 1.1 1.1"3 Original 1A"1 1A-2, Sup 2 1.1 1.1-4A Sup 4 1A"3 Sup 3 1.1-4B Sup 3 1B Tab Original 1.1~5 1.1-8 Original Appx 1B Title Page Original

'.. 1 "9 Sup 2 1B-1 " 1B-7 Original 1.1'-9A Sup 3,. Fig. 1B-1 Original F 1"9B Sup 2 1C Tab 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 Original- - 1L 1L-11 Original Subtitle Page Original- 1M Tab Original Contents Page " Gr'iginal - Appx 1M Title Page Original On:ginal 1M 1M-14 Original 1C-1 - 1C-31 - Originals-' Chapter 2 Tab Original Fxhibits Title Page Original -'.2-i ii Sup 2 1C"A-1 " 1C-A-8 Original': 2-iii Original 1D Tab Original- 2-zv 2 viii Sup 2 Appx 1D Title Page Original 2-ix x Original 1D"1 - 1D-4 Original 2.1 Tab Original 1E Tab Original 2.1-1 " 2.1-4 Original Appx 1E Title Page Original 2.1 2.1-6D Sup 2 lE-1 Original 2.1"7 Sup 1 1F Tab Original 2.1 2.1-9 Original Appx 1F Title Page .'riginal 2.1"10 Sup 3 1F"1 - 1F"3 Original 2.1-10A - 2.1"10B "

Sup 2 1G Tab 'riginal 2.1"11 - 2.1-12 Sup 2 1G Title Page Origina% 2.1"13 " 2.1"14 Original IG-1 - 1G"14 Original-" 2.1-15 ." 2.1-16 Sup 1 Fig. 1G"1 " 1G-2 Orig'ina1 .u '2.1"17 - 2.1"31 Original lH Tab Original '2. 1-32

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Sup 1 Appx 1H Title Page Original 2.1"33 - 2.1-34 Original 1H 1H-26 Original '2.1-35 Sup 2 1I Tab Originals Fig. 2.1"1 - 2.1-2 Original Appx lI Title Page Original Fig. 2.1"2A Sup 2 1I 1I-27 Original Fig. 2.1 2.1-16 Original

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1J Tab Original 2.2 Tab Original Appx 1J Title Page Original 2.2-1 " 2.2"21 Original 1J"1 " 1J"9 Original Fig. 2.2 2.2-2 Original IK Tab Original 2.3 Tab Original Appx 1K Title Page Original 2.3"1 - 2.3"12 Original 1K 1K-4 Original -2.3-13 .

Sup 1 1L'Tab"

"'-'ppx Original - 2.3 2.3-45 Original lls<<Title Page Original'.3-46 Sup 2 Supplement 4 December 1981

PVNGS ER-OL Pa e or Fi ure No. Issue Pa e or Fi ure No. Issue 2.3-46A Sup 4 2B-1';.- 2B.-5 Original 2.3-46B Sup 2 2C Tab Original 2.3-47 Original Appx 2C Title Page Original 2.3 2.3-48B Sup 2 2C-1'.;2C;5 Original 2.3-49 2.3-63 Original Chapter .3 Tab Original Fig. 2.3 2.3-22 Original 3 i *>>.It Original 2.4 Tab Original 3 ii;>>, Sup 3

- 2.4-9

'.4-1 Original 3 3.1l. Ori;ginal Fig. 2.4"1 - 2.4-3 Original 3-iv ivB Sup 2 Fig. 2.4-4 (Sht 1) Original 3 v 3 vi Original Fig. 2.4-4 (Sht 2) Original 3.1 Tab Original Fig. 2.4"5 - 2.4-6 Original F 1 3.1-3 'riginal Fig. 2.4-7 (Sht 1) Original 3.1-4 Sup 1 Fig. 2.4-7 (Sht 2) Original Fig. 3.1-1, - 3.1-11 Original Fig. 2 '-7 (Sht 3) Original 3.2 Tab Original Fig. 2.4-7 (Sht 4) Original 3.2-1 -,. 3.2"2 Sup 2 Fig. 2.4-7 (Sht 5) Original 3;3 Tab Original 2.5 Tab ,Original . 3. 3".1 Sup 4 2.5"1 " 2.5-4 Original . 3 ~ 3,2, '>>'3 ~ 3 3 Sup 2 Fig. 2.5 2.5-4 Original " Fig.,"=,$ .3-1 (Sht 1) Original 2;6 Tab Original Fig. 3.3-1 (Sht 2) Original 2.6 2 '-4 Original Fig. 3.3-1 (Sht 3) Original 2.? Tab Original Fig. 3.3-1 (Sht 4) Original 2.7"1 " 2.7"2 Sup 2 3.4,Tab Original Fig. 2.7 2.7-3 Original 3. 4 3. 4-5 Original 2A Tab Original 3.4-6 Sup 3 Appx 2A Title Page Original 3.4-7 .--3.4-13 Original 2A"i Sup 2 Fig. 3.-4 3.4-9 Original 2A-1 - 2A"2 Sup 1 3.5 Tab Original 2A-3 - 2A-4 'Sup 2 3.5' 3.5-30 Original 2A"5 Sup 3 3.5-31 Sup 3 M~-6 - 2A-10 Sup 2 3.5 3.5-42 Original, 2B Tab Original Fig,,3.5-1 Original Appx 2B Title Page Original Fig.'.5-2 (Sht 1) , 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) Original '.9-13 Sup 2 Fig. 3.5-2 (Sht 3) 0'iiginal 3.9"14 " 3.9-15 Original Fig. 3.5-3 (Sht 1) Original 'ig. 3.9 3.9-2 Sup 2 lig. 3.5-3 (Sht 2) =Original Fig, 3,9 3 Original Fig. 3.5 3.5-5 Original 'ig. 3.9-3A - 3.9-3B Sup 1 1'ig. 3.5-6 (Sht 1) Original Fig. 3.9 4 Original 1'ig. 3.5-6 (Sht 2) Original "

Fig. 3.9-5 Sup 2 Fig. 3.5-7 Original 3A Tab Original 3.6 Tab Original Appx 3A Title Page Original 3.6-1 Original 3A-i Sup 3 3.6-2 Sup 3 3A"1 " 3A"4 Sup 2 3.6-2A - 3 '-2B Sup 2 3A-5 Sup 4 3.6-3 Sup 2 3A-6 - 3A-13 Sup 2 3.6-3A Sup 3 3A"14 - 3A-16 Sup 3 3.6-3B Sup 2 Chapter 4 Tab Original 3.6-4 Sup 2 4-i iv Original 3.6-5 SLlp 4 4.1 Tab Original 3.6 3.6>>6B Sup 2 4.1 4.1-17 Original 3.6 3.6-9 'riginal Fig. 4.1-1 Original 3.6 3.6"10B Sup 2 4.2 Tab Original 3.6-11 Original 4.2 4.2-4 Original 3.6-12 Sup 3 4.3 Tab Original 3.6-13 Sup 4 4.3 4.3-4 Original 3.6-14 Sup 2 4.4 Tab Original Fig. 3.6 3.6"5 Original 4.4 4.4-2 Original 3.7 Tab Original 4.5 Tab Original 3.7-1 Original 4.5 4.5-15 Original 3.7"2 - 3.7-5 Sup 2 Fig. 4.5 4.5-2 Original 3.8 Tab Original 4A Tab Original 3.8"1 Original Appx 4A Tz.tie Page Original 3.9 Tab Original Chapter 5 Tab Original 3.9 3 '"9 Original "

5-i Sup 2 3.9-10 Sup 1 5-ii Sup 4 3.9"ll -'3.9-12 Original'. 5 1ii 5 v Sup 2 Supplement 4 D December 1981

PVNGS ZR-OL Pa e or Fi ure No. Issue Pa e or Fi ure No. Issue 5.1 Tab Original 5.6 5'.6-8 Original 5.1 5.1-10 Original 5.6"9 5.6>>14 Sup 2 5 ' 5.1"'4 Sup 2 5.6-15, Sup 4 5.1"15 - 5.1-16 Original Fig. 5.6.-1 Peleted Sup 2 5.1"17 - 5.1-19 Sup 2 Fig. 5.6-2, Original 5.1"20, Original 5.7 Tab. Original 5.1 5.1-22 Sup 2 5.7-1 Sup 4 5.1 5.1"24 Original 5.8 Tab Original Fig. 5.1 5.1-12 Original 5.8 5.8-2 Original 5.2 Tab Original 5A Tab Original 5.2 5.2-3 Original Appx 5A Title Page Original 5.2"4 - 5.2-5 Sup 3 5A-.i Sup 2 5.2-6 Original 5A-1 Sup 4 5.2"7 Sup 3 5A-2 - 5A-8 Sup 2 5.2-8 Original 5B Tab Original 5.2"9 " 5.2-12 Sup 3 Appx 5B Title Page Original Fig. 5.2-1 Original 5B-i Original 5.3 Tab Original 5B-1 - 5B-4 Original 5.3-1 " 5.3-4 Original 5B-5/5B-6 Blank Sup 3 5.4 Tab Original 5B"7 - Original 5.4"1 Sup 4 5B-8 - 5B-18 Sup 3 5.'4-2 Sup 2 5C Tab Sup 2 5.4 5.4-4 Sup 4 Appx 5C Title Page Sup 2 5.4 5.4-6 Sup 2 5C 5C"8 Sup 2 5.4-7 " 5.4-9 Sup 4 Chapter 6 Tab Original 5.5 Tab Original 6-i Sup 4 5.5"1 " 5.5-6 Sup 2 6-ii Original Fig. 5.5 5.5-3 Sup 2 6-iii - 6"iv Sup 4 5.6 Tab Original 6.1 Tab .. Original I

5.6 5.6-2B Sup 4 6.1 6.1-19 Original 5.6 5.6-3B Sup 4 6.1 6.1"20D Sup 2 5.6-4 Sup 2 6.1 6.1-28 Original 5.6-5 Original 6.1-29 6.1-31B Sup 4 5.6-6 Sup 2, 6.1 6..1-34A Sup 4 Decenber 1981 Supplement 4

PVNGS ZR-OL Pa e or Fi ure No. Issue Pa e or Fi ure No. Issue 6.1-34B Sup 1 8.2 8.2"4 Original fi.1 6.1-41 Original 8A Tab Original 6.1"42 Sup' Appx 8A Title Page Original Fig. 6.1-1 Sup 4 8A-i Sup 2 6.2 Tab Original 8A-1 - 8A-2 Sup, 2 6.2 6.2"2 Original Chapter 9 Tab Original 6.3 Tab Original 9-i Original 6.3 6.3-6 Original 9-1 Original 6.4 Tab Original 9A Tab Original 6 '-1 - 6.4-2 Original Appx 9A Title Page Original 6A Tab Original Chapter 10 Tab Original Appx 6A Title Page Original 10-i Originals 6A-i Sup 2 10"1 Original 6A-1 - 6A-2 Sup 1 10A Tab Original 6A-3 - 6A-5 Sup 2 Appx 10A Title Page Original Chapter 7 Tab Original Chapter ll Tab Original l 1 7 111 Original 11-i Original 7.1 Tab Original 11-1 4 Original 7.1 7.1"27 Original llA Tab Original 7.2 Tab Original Appx 11A Title Page Original 7.2-1 Original Chapter 12 Tab Original 7..3 Tab Original 12-i ii Original 7.3-1 " 7.3-4 Original 12-1 12 Original 7A Tab Original 12A Tab Original 7A

'ppx Title Page Original Appx 12A Title Page Original Chapter 8 Tab Original Chapter 13 Tab Original 8-i - 8-ii Sup 4 13"i Original 8' Tab Original 13-1 Original 8.1 8.1-5 Original 13A Tab Original 8.1 8.1-6B Sup 2 Appx 13A Title Page Original 8.1"7 " 8.1'-8 Sup 2 8.1 8.1-12 Original 8.1 8.1"18 Sup 4 8.2 Tab 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.

Undivided Joint A licants Interest Arizona Public Service Company (APS ) 29.1%

Salt River Project Agricultural (SRP ) 29 1%

Improvement and Power District 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 FOREWORD of the ER-OL. The cross-reference list from NRC question number to ER-OL question number is as noted below: .

NRC UESTION NUMBER ER-OL VEST ION NUMBER Section 1.1.2 lA.l Section 2.1.2.3 2A.l Section 2.3 2A.2 Section 2.3 2A.3 Section 3.1.3.1 3A.1 Section 6.1.5.5.3 6A.1 Section 6.2 6A.2 240.1 3Ai2 240.2 3A. 3 240.3 3A.4 240.4 3A.5 290.1 6A.3 290.2 3A.6 290.3 6A.4 290.4 5A.l 290.5 .5A. 2 290.6 5A. 3 290.7 5A.4 290'. 8 3A. 7-290.9 5A.5 290.10 5A.6 291.1 3A.8 291.2 3A.9 291.3 3A.10 291.4 3A.ll 291.5 3A.12 291.6 3A.13 291.9 3A.14 291.10 3A.15 291.11 3A.16 291.12-3.7.3.3 3A.17 Supplement 3 vA .July 1981

PVNGS ER-OL FOREWORD NRC UESTION NUMBER ER-OL UESTION NUMBER 291.12-5.6.2 5A.7 291.13 5A.8 291.15 2A.4 291.16 2A.5 291.17 3A.18 291.18 3A.19 291.19 3A.20 291.20 3A.21 291.21 3A.22 291.22 3Q.23 291.23 3A. 24 291.24 3A.25 291.25 3A.26 291.26 3A.27 291.27 3A.28 291.28 3A.29 291.29 3A.30 291.30 3A.31 310.1 'A.9 310.2 5A.10 310.3 2A.6 310.4 2A.7 310.5 2A.8 310.6 2A.9 310.7 5A.ll 310.8 8A.1 310.9 8A.2 311.1 2A.10 311.2 2A.ll 311.3 2A.12 311.4 2A.13 311.5 2A.14 320.1 1A.2 320.2 lA.3 July 1981 vB Supplement 3

PVNGS ER-OL FOREWORD NRC UESTION NUMBER ER-OL UESTION NUMBER 320.3 lA.4 320.4 1A.5 320.5 lA.6 320.6 lA.7 320.7 1A.S 320.8 1A.9 450.1 2A.15 Supplement 3 V3. July 1981

PVNGS ER-OL NEED FOR POWER Table 1.1-1 PVNGS 1, 283 PARTICIPANTS LOADS AND RESOURCES

SUMMARY

Year 1964 1965 1966 1967 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1964 THROUGH 1992 (Sheet 1 of 7) 1.1.1 Load characteristics, demand (MW)

Company peak demand 9602 10351 11020 120LI9 12907 13869 14793 16441 17677 18444 18442 18620 19999 20375 21706 22210 22803 24091 25090 26179 27255 28339 29390 30488 31528 33111 34217 35411 36630 Firm sales outside PVNGS 1,2 6 3(a) 129 65 46 50 60 68 69 151 171 284 345 384 369 917 551 726 830 931 1033 764 742 776 810 848 886 414 430 447 464 Annual peak demand (PVNGS + FSO) 9/31 10416 11066 12099 12967 13937 14862 16592 17848 18728 18787 19004 20368 21292 22257 22936 23633 25022 26123 26943 27997 29115 30200 31336 3241LI 33525 34647 35858 37094 Firm purchases outside PVNGS -1,2 8 3(a) 87 157 205 293 741 660 801 780 741 806 926 792 773 910 989 862 777 989 777 777 1036 1036 1036 1036 1036 1036 1036 1036 1036 Adjusted annual peak demand (APD-FPO) 9644 10259 10861 11806 12226 13277 14061 15812 17107 17922 17861 18212 19595 20382 21268 22084 22856 24033 25346 26166 26961 28079 29164 30300 31378 32489 33611 34822 36058 1.1.1 Load characteristics, energy (GWh)

ompany energy 52426 56702 61913 66207 71455 77109 82305 87412 93411 97298 94151 96141 100248 103779 107236 110699 116294 121807 127155 133201 139499 145536 151921 157945 163581 171117 179747 185974 192750 Firm energy sales outside PVNGS (a) 1620 784 685 860 834 1201 1318 1962 2640 3323 3163 3653 4667 7719 5296 7988 8466 8955 9626 8005 7457 7377 7707 7592 7423 4457 4839 4948 5170 Annual energy (PVNGS +FES) 540 LI6 57486 62598 67067 72289 78310 83623 89374 96051 100621 97314 99794 104915 111498 112532 118687 124760 130762 136781 141206 146956 152913 159628 165537 171004 177574 184586 190922 197920 Firm energy purchases outside PVNGS (a) 81 254 306 405 577 844 908 1372 825 965 739 672 634 786 1198 1098 618 618 618 618 618 618 618 618 618 618 618 618 618 Adjusted annual energy (AE FEP) 53965 57232 62292 66662 71712 77 LI6 6 82715 88002 95226 101586 96575 99122 104281 110712 11133LI 117589 124142 130144 136163 140588 146338 152295 159010 164919 170386 176956 183968 190304 197302 1 ~ 1.2 Power supply (MW)

Installed resources 11853 12611 13582 15084 15464 16579 18108 18591 20660 22403 23653 24515 25433 26271 26817 27067 28289 29007 31575 32044 33661 34103 35674 36699 38603 39417 40854 41661 42881 Nonfirm purchases (a) 47 147 1LI8 140 135 130 124 123 348 17$ 365 369 179 179 179 239 339 419 178 178 178 56 56 56 56 56 56 56 56 PRO Noncommitted purchases (a) 300 300 600 APERTURE Nonfirm sales (a) 15 16 17 16 183 108 174 CARD Nonfirm sales Layoff (a) 170 202 100 Capability (IR+NFP-NFS) 11897 12755 13727 15221 15596 16706 18229 18712 21006 22571 24016 24884 25612 26LI50 26981 27290 28611 29310 31570 32114 33665 34159 35730 36755 38489 39473 41008 42017 43537 1.1.3 Capacity requirement Reserve (C-AAPD) (MW) 2253 2496 2866 3415 3370 3429 4168 670LI 6080 6566 6455 7111 6984 7397 7195 7479 2900 3899 4649 6155 6672 6017 6068 5713 5206 5755 5277 6224 5948 Reserve margin (/I) 23.4 24.3 26.4 28.9 27.6 25.8 21.7 22.5 21-3 22.7 21.5 22.0 20.7 20.7 29.6 18.3 22.8 25. 9 34.5 36.6 30.7 29. 8 26.9 23.6 25.2 22.0 24.6 22-7 24 9

a. Sales and purchases to Companies other than the PVNGS-1,263 participants.

1.1-15/16 Blank

PVNGS ER-OL NEED FOR POWER ARIZONA PUBLIC SERVICE COMPANY Table 1.1-1 1966 1967 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 Year 1964 1965 LOADS AND RESOURCES

SUMMARY

1964 THROUGH 1992 (Sheet 2 of 7) 1.1.1 Load characteristics, demand (MW) 888 969 1130 1260 1349 1587 1703 1898 1912 1987 2083 2212 2343 2541 2736 2874 3051 3215 3384 3547 3728 3905 4595 4787 4970 5151 Company peak demand 775 805 875 12 13 13 13 58 72 108 134 156 204 290 337 346 372 385 400 411 423 439 455 472 489 Firm sales outside PVNGS 1,2&3 100 32 13 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Firm sales within PVNGS 1, 2&3 0 0 0 12 0

13 0

13 13 58 72 108 134 156 204 290 337 346 372 385 400 411 423 439 455 472 489 Total firm sales (TFS) 100 32 13 982 1143 1273 1407 1659 1811 2032 2068 2191 2373 2549 2689 2913 3121 3274 3462 3638 3823 4002 4200 4394 4595 4787 4970 5151 Annual peak demand (CPD+TFS) 875 837 888 900 0 0 0 0 0 0 0 0 (6) (6) (6) (6) (6) (6) (6) (6) (6) (6) (6) (6) (6) (6) (6) (6) (6)

Firm purchases outside PVNGS 1, 2&3 0 0 0 0

~92) ~96) ~203 ~212) ~222) ~231) ~241) ~251) ~262) ~273) ~284 ) ~296 ) ~307 ~319 ~331)

Firm purchases within PVNGS 1,2&3 ~67) ~59) ~42) ~58) ~54) ~56) (56) (92) (96)

(113)

(113)

(142)

(142)

(171)

(171)

~171)

(171)

~152)

(158)

(152)

(158)

~183 (189)

) (195)

(201) (209)

)

(218) (228) (237) (247) (257) (268) (279) (290) (302) (313)

)

(325)

)

(337)

Total firm purchases (TFP) (67) (59) (42) (58) (54) 842 928 1087 1181 1311 1546 1669 1861 1897 2033 2215 2360 2488 2704 2903 3046 3225 3391 3566 3734 3921 4104 4293 4474 4645 4814 Adjusted annual peak demand 808 778 846 (APD-TFP-ID) 1.1.1 Load charact~~istics, energy (GWh) 5405 5835 6394 7470 8207 8795 8596 9019 9651 10459 10905 11907 13032 13863 14881 15772 16721 17564 18485 19490 24068 25333 25992 26983 Company energy 4063 4134 4507 4609 4869 73 82 83 358 468 576 702 1269 1586 1885 1691 2243 2507 2629 2738 2773 2879 2991 3109 3244 3379 Firm energy sales outside PVNGS 1,2&3 927 276 72 63 5487 5918 6752 7938 8783 9497 9865 10605 11536 12150 13148 14414 15661 16601 17654 18651 19712 20673 21729 22869 24068 25333 25992 26983 Annual Energy (CE+FES) 4990 4410 4579 4672 4942 (32) (32)

(32) (32) (32) (32) (32) (32) (32) (32) (32) (32) (32) (32) (32) (32) (32)

Firm energy purchases outside PVNGS 1,2&3 4942 5487 5918 6752 7938 8783 9497 9865 10573 11504 12118 13116 14382 15629 16569 17622 18619 19680 20641 21697 22837 24036 25301 25960 26951 Adjusted annual energy (AE FEP) 4990 4410 4579 4672 1.1.2 Power supply (MW) 1381 1501 1540 1734 1981 2139 2235 2565 2560 2795 2795 3037 3384 3740 3786 4142 4242 4598 4598 5076 5076 5554 5554 5854 Installed resources 1267 1270 1262 1255 1255 175 0 127 100 16 16 16 1.6 16 16 15 15 15 0 0 0 0 0 0 0 0 Nonfirm purchases outside PVNGS 1,2&3 0 0 0 0 0 0 0 0 62 62 62 62 62 62 Nonfirm purchases within Total nonfirm purchases PVNGS 1,2&3 62 62 62 62 62 62 62 62 62 62 62 62 62 62 62 237 62 62 62 189 62 162 62 78 62 78 62 78 62 78 62 78 62 78 62 77 62 77 62 77 62 62 62 62 62 62 62 62 62 62 PRC Nonfirm sales outside PVNGS 1, 2&3 (3) (3) (3) (3) (3) (3) (3) (2) (2) (2) (2) 0 0 0 0 0

0 0

APERTUpp 0 0 0 Nonfirm sales within PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0

~100 ) 0 0 ~170) ~202) CARD Nonfirm sales Layoff 0 0 0 0 0 0 0 0 0 0 0 (3) (2) (2) (2) (2) (100) (170) (202)

Total nonfirm sales (3) (3) (3) (3) (3) (3) 2041 2326 2397 2643 2638 2873 287 3115 3362 3817 3863 4219 4304 4660 4660 4968 5138 5414 5616 5916 Capability (IR+NFP NFS) 1326 1329 1321 1314 1314 1440 1560 1600 1969 3 1.1.3 Capacity requirement 610 423 513 385 411 459 771 638 828 738 926 739 864 845 940 971 1102 Reserve (C-AAPD) (MW) 518 551 475 472 386 353 379 289 423 372 465 500 20.9 22.9 56.1 41.6 32.5 32.1 22.0 27.4 22.3 25.0 26.4 30.0 19.1 21.7 15.5 15.2 15.8 25.3 19.8 24.4 20.7 24.8 18.8 21.1 19.7 21.0 Percent margin (100xR/AAPD) (%) 64.1 70.8 56.1 1.1-17/18 Blank

PVNGS ER-OL LOS ANGELES DEPARTMENT OF WATER AND POWER NEED FOR POWER Year 1964 1965 Table 1.1-1 1966 1967 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 LOADS AND RESOURCES

SUMMARY

1.1.1 Load characteristics, demand (MW) 1964 THROUGH 1992 (Sheet 3 of 7)

Company peak demand 2123 2303 2407 2679 2772 2935 3107 3439 3630 3679 3500 3594 3809 3778 4144 4016 4157 4259 4366 4488 4618 4772 4923 5077 5230 5383 5537 5691 5846 Firm sales outside PVNGS 1,2&3 78 78 78 75 11 100 120 120 120 Firm sales within PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 Total firm sales (TFS) 78 78 78 75 100 120 120 120 Annual peak demand (CPD+TFS) 2123 2303 2407 2679 2775 2938 3110 3442 3633 3757 3578 3672 3812 3853 4155 4116 4277 4379 4486 4488 4618 4772 4923 5077 5230 5383 5537 5691 5846 Firm purchases outside PVNGS 1,2&3 Firm purchases within PVNGS 1,2&3 Total firm purchases (TFP) 0 Adjusted annual peak demand 2123 2303 2407 2679 2775 2938 3110 3442 3633 3757 3578 3672 3812 3853 4155 4116 4277 4379 4486 4488 4618 4772 4923 5077 5230 5383 5537 5691 5846 (APD-TFP-ID) 1.1.1 Load characteristics, energy (GWh)

Company energy 11063 12037 13093 14091 15123 16158 17049 17803 18800 18879 16818 17652 18800 18497 19462 19711 20536 20966 21499 22134 22902 23733 24596 25481 26436 27260 28149 29040 30015 Firm energy sales outside PVNGS 1,2&3 0 0 0 0 0 21 18 41 166 286 282 455 385 87 445 652 685 692 764 103 0 0 0 0 0 0 0 0 0 Annual Energy (CE+FES) 11063 12037 13093 14091 15123 16179 17067 17844 18966 19165 17100 18107 19185 18584 19907 20363 21221 21658 22263 22237 22902 23733 24596 25481 26436 27260 28149 29040 30015 Firm energy purchases outside 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '

0 PVNGS 1, 2&3 Adjusted annual energy (AE-FEP) 11063 12037 13093 14091 15123 16179 17067 17844 18966 19165 17100 18107 19185 18584 19907 20363 21221 21658 22263 22237 22902 23733 24596 25481 26436 27260 28149 29040 30015 1.1.2 Power supply (MW)

Installed resoures 2475 2895 2800 3486 3683 3820 4027 3915 4130 4759 5311 5435 5720 5716 5672 5702 5707 5707 5707 5707 6167 6094 6090 6336 6582 6976 7222 7360 7350 Nonfirm purchases outside PVNGS 1,2&3 Nonfirm purchases within PVNGS 1, 2&3 Total nonfirm purchases Nonfirm sales outside PVNGS 1,2&3 PRC 0

Nonfirm sales within Total nonfirm sales PVNGS 1, 2&3 0 APERTURE Noncommitted CARD Capability (IR+NFP-NFS) 2475 2895 2800 3486 3683 3820 4027 3915 4130 4759 5311 5435 5720 5716 5672 5702 5707 5707 5707 5707 6167 6094 6090 6336 6582 6976 7222 7360 7350 1.1.3 Capacity requirement Reserve (C-AAPD) (MW) 352 592 393 807 908 882 917 473 497 1002 1733 1763 1908 1863 1425 1328 1221 1219 1549 1322 1167 1259 1352 1593 1586 1669 1504 Percent margin (100xR/AAPD) 1517 1586

(%) 16.6 25.7 16.3 30.1 32.7 30.0 29.5 13.7 13.7 26.7 48.4 48.0 50.1 48.4 36.5 38.5 33.3 30. 3 27.2 27.2 33.5 27.7 23.7 24.8 25.8 29.6 30.4 29. 3 25.7 1.1-19/-20 Blank

PVNGS ER-OL EL PASO ELECTRIC COMPANY NEED FOR POWER Year 1964 1965 1966 1967 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 Table 1.1-1 1.1.1 Load characteristics, demand (MW) LOADS AND RESOURCES

SUMMARY

Company peak demand 272 297 322 323 356 396 416 446 482 546 554 555 595 599 654 680 745 800 861 932 984 1,057 1,108 1,163 1,212 1, 271 1,322 1,377 1,431 1964 THROUGH 1992 (Sheet 4 of 7)

Firm sales outside PVNGS 1, 2&3 29 33 33 38 44 52 53 55 61 72 84 85 82 58 36 38 40 45 48 52 54 56 58 60 63 65 67 68 70 Firm sales within PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Total firm sales (TFS) 29 33 33 38 44 52 53 55 61 72 84 85 82 58 36 38 40 45 48 52 54 56 58 60 63 65 67 68 70 Annual peak demand (CPD+TFS) 301 330 355 361 400 448 469 501 543 618 638 640 677 657 690 718 785 845 909 984 1,038 1,113 1,166 1,223 1,275 1,336 1,389 1.445 1,501 Firm purchases outside PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Firm purchases within PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Total firm purchases (TFP) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Adjusted annual peak demand (APD-TFP ID) 301 330 355 361 400 448 469 501 543 618 638 640 677 657 690 718 785 845 909 984 1,038 1,113 1,166 1,223 1, 275 1,336 1,389 1,445 1,501 1.1.1 Load characteristics, energy (GWh)

Company energy 1,520 1,606 1,708 1,823 1,938 2, 135 2, 252 2,422 2, 643 2,866 2,901 2,996 3,160 3,299 3,424 3,616 3,913 4,206 4,591 4,924 5,274 5, 610 6, 350 6, 617 6,536 6,846 7,125 7,423 7.713 Firm energy sales outside PVNGS 1,2&3 81 88 102 122 232 326 254 240 319 403 455 454 392 173 165 193 217 236 254 276 283 296 310 327 338 349 363 366 375 Annual energy (CE+FES) 1,601 1,694 1,810 1,945 2,170 2, 461 2,506 2, 662 2, 962 3,269 3, 356 3,450 3, 552 3,472 3, 589 3,809 4,130 4,442 4,845 5, 200 5,557 5,906 6,660 6, 944 6,874 7, 195 7,488 7,789 8,088 Firm energy purchases outside PVNGS 1,2&3 Adjusted annual energy (AE-FEP) 1,601 1,694 1,810 1,945 2, 170 2,461 2,506 2,662 2, 962 3,269 3,356 3,450 3,552 3,472 3,589 3,809 4, 130 4,442 4,845 5,200 5, 557 5, 906 6, 660 6, 944 6, 874 7,195 7,488 7,789 8,088 1.1.2 Power supply (MW)

Installed resources 419 419 530 530 495 536 642 642 756 740 716 840 940 890 900 885 977 1,033 1,178 1,174 1,348 1,348 1,548 1,559 1, 609 1,609 1,745 1,745 1,836 Nonfirm purchases outside PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Nonfirm purchases within PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Total nonfirm purchases 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Nonfirm sales outside PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Nonfirm sales within PVNGS 1,2&3 Total nonfirm sales 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 PRC Noncommitted APERTURE Capability (IR+NFP-NFS) 419 419 530 530 495 536 642 642 756 740 716 840 940 890 900 885 977 1,033 1,178 1,174 1,348 1,348 1,548 1,559 1, 609 1,609 1,745 1,745 1,836 CARD 1.1.3 Capacity requirement Reserve (C AAPD) (MW) 118 89 175 169 95 88 173 141 213 122 78 200 263 233 210 167 192 188 269 190 310 235 382 336 334 273 356 300 335 Percent margin (100xR/AAPD) (%) 39.2 27. 0 49.2 46.8 23.8 19. 6 36.9 28.1 39.2 19.7 12. 2 31.3 38.8 35. 5 30.4 23.3 24.5 22. 2 29.6 19.3 29.9 21.1 32. 8 27.5 26.2 20.4 25.6 20.8 22.3 1.1-21/22 Blank

PVNGS ER-OL PUBLIC SERVICE COMPANY OF NEW MEXICO NEED FOR POWER Year 1964 1965 1966 1967 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1.1.1 Load characteristics, demand (MW)

Table 1.1-1 LOADS AND RESOURCES

SUMMARY

Company peak demand 268 303 316 316 341 372 399 455 486 533 566 556 584 620 683 745 1,165 1,265 1,352 1,445 1, 659 1, 783 1, 928 of 814 883 979 1, 076 1, 565 2, 089 1964 THROUGH 1992 (Sheet 5 7)

Firm sales outside PVNGS 1,2&3 0 0 0 0 0 0 18 30 49 95 126 164 212 252 275, 241 205 221 237 256 274 289 303 319 334 Firm sales within PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Total firm sales (TFS) 0 0 0 0 0 0 18 30 49 95 126 164 212 252 275 241 205 221 237 256 274 289 303 319 334 Annual peak demand (CPD+TFS) 268 303 316 316 341 372 399 455 486 533 584 586 633 715 809 909 1, 026 1, 135 1, 254 1, 317 1,370 1,486 1,589 1, 701 1, 839 1, 948 2, 086 2, 247 2,423 Firm purchases outside PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 75 75 0 0 0 0 0 Firm purchases within PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Total firm purchases (TFP) 0 0 0 0 0 0 0 0 0 75 75 0 0 0 0 0 Adjusted annual peak demand (APD-TFP-ID) 268 303 316 316 341 372 399 455 486 533 584 586 1,486 2,423 633 715 734 834 1,026 1,135 1,254 1,317 1, 370 1, 589 1,701 1, 839 1, 948 2, 086 2, 247 1.1.1 Load characteristics, energy (GWh)

Company energy 1,474 1,577 1,682 1,779 1,919 2,094 2,272 2,534 2,771 2,914 3,060 3,369 3,417 3,480 3,740 4,691 5,118 6,871 7,459 7,996 9,269 9,958 10,713 11, 514 4, 253 5,690 6, 321 8, 575 12, 387 Firm energy sales outside PVNGS 1,2&3 0 0 0 0 0 0 0 0 54 448 1,760 1,883 Annual Energy (CE+FES) 1,474 0 0 152 1, 039 1, 063 1,376 1,586 1, 905 2, 145 2, 038 1,706 1, 642 2, 015 2, 127 2, 230 2, 347 2, 458 1,577 1, 682 1,779 1, 919 2, 094 2. 272 2, 534 2,771 2, 914 3,114 3,521 3,865 4, 519 4, 803 5, 629 6, 277 7,023 7,835 8,359 8,577 9, 101 9, 756 10,458 11, 284 12, 085 12, 943 13, 861 14,845 Firm energy purchases outside PVNGS 1, 2&3 412 480 Adjusted annual energy (AE-FEP) 1,474 1,577 1,682 1,779 1, 919 2, 094 2, 272 2, 534 2, 771 2, 914 3, 114 3,521 3,865 4,519 4,391 8,577 9,101 10, 458 13,861 14,845 5, 149 6,277 7,023 7,835 8, 359 9, 756 11 284 12 085 12 943 1.1.2 Power supply (MW)

Installed resources 333 333 333 333 333 437 541 541 541 561 726 726 720 858 842 842 1,071 1,071 1,656 1,656 1, 786 1, 786 1, 916 2, 055 2, 405 2, 405 2, 405 2,405 2, 405 Nonfirm purchases outside PVNGS 1,2&3 0 0 0 17 17 17 0 Nonfirm purchases within PVNGS 1,2&3 0 0 0 0 60 160 240 0 0 0 35 50 42 57 10 85 95 60 115 0 0 0 Total nonfirm purchases 0 35 50 59 74 27 85 95 60 115 60 0 0 240 0

160 0 0 0 Nonfirm sales outside PVNGS 1, 2&3 0 0 0 0 0 142 Nonfirm sales within PVNGS 1,2&3 0 0 0 0 0 151 76 0 0 0 Total nonfirm sales 0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 151 0

76 0

142 0

0 0

0 0

0 PRC Noncommitted 300 300 600 APERTURE)

Capability (IR+NFP-NFS) 333 333 333 333 368 487 541 541 600 635 753 811 815 918 957 902 1,231 1,311 1,505 1,580 1,644 1,786 1,916 2, 055 2,405 2,405 2,705 2, 705 2,945 CARD 1.1.3 Capacity requirement 268 303 316 316 341 372 399 455 486 1,839 2,423 533 584 586 633 715 734 834 1,026 1,135 1,254 1,317 1,370 1,486 1,589 1,701 1, 948 2, 086 2, 242 Reserve (C AAPD) (MW) 65 30 17 17 27 115 142 86 114 102 619 458 522 Percent margin (100xR/AAPD) 169 225 182 203 223 68 205 176 251 263 274 300 327 354 566 457

(%) 24 10 5 5 8 31 36 19 23 19 29 38 29 28 30 8 20 16 20 20 20 20 21 21 31 23 30 20 22 1.1-23/24 Blank

PVNGS ER-OL NEED FOR POWER SALT RIVER PROJECT 1964 1965 1966 1967 1968 1969 1970 1971 1972 197 3 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 Year Table 1.1-1

1. 1. 1 Load characteristics, demand (MW) LOADS AND RESOURCES

SUMMARY

(a) 652 679 762 944 1,055 1,120 1,360 1,448 1,645 1 634 1 732 1 731 1,854 2,065 2,185 2, 312 2,429 2, 541 2, 652 2,790 2,909 3, 024 3,103 3, 178 3, 276 3,376 3,474 1964 THROUGH 1992 (Sheet 6 of 7)

Company peak demand 547 609 0 0 0 0 0 0 26 31 35 31 141 41 46 46 50 55 60 60 60 60 60 60 60 60 60 60 Firm sales outside PVNGS 1, 2&3 0 0 0 56 53 55 90 94 111 140 169 169 158 150 236 193 201 210 220 229 239 251 260 271 282 292 302 312 322 Firm sales within PVNGS 1, 2&3 61 56 38 56 53 55 90 166 200 204 291 277 239 247 260 275 289 299 311 320 331 342 352 362 372 382 Total firm sales (TFS) 61 56 38 608 665 690 735 815 999 1,145 1,214 1,471 1,614 1,845 1, 838 1, 921 2, 022 2, 131 2, 304 2,432 2, 572 2, 704 2,830 2,951 3,101 3,229 3,355 3,445 3,530 3,638 3,748 3,856 Annual peak demand (CPD+TFS)

(157) (205) (293) (378) (400) (423) (404) (365) (430) (409) (181) (162) (299) (297) (160) (160) (160) (160) (160) (160) (160) (160) (160) (160) (160) (160) (160) (160)

Firm purchases outside PVNGS 1,2&3 (87) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Firm purchases within PVNGS 1, 2&3 0 0 0 0 0 0 (400) (423) (404) (365) (430) (409) (181) (162) (299) (297) (160) (160) (160) (160) (160) (160) (160) (160) (160) (160) (160) (160) (160) (160)

Total firm purchases (TFP) (87) (157) (205) (293 ) (378)

Adjusted annual peak demand 442 437 599 722 810 1,106 1,184 1,436 1,657 1,759 1,723 1,834 2,144 2 272 2,412 2, 544 2, 670 2,791 2, 941 3, 069 3,195 3, 285 3, 370 3,478 3, 588 3,696 (APD TFP ID) 521 508 485 ~

1.1.1 Load characteristics, energy (GWh)

Company energy (includes interruptible 5,419 6,119 6,586 7,464 7, 936 8, 226 8, 591 9, 555 10 432 11 275 11 792 12,441 13,050 13,853 14,545 15,307 15,850 16,375 17,057 17,795 18,552 energy) 2. 777 2,849 3,102 3, 313 3,518 4,364 4,936 7, 667 0 114 178 171 236 363 306 284 346 357 320 335 335 336 336 336 336 336 336 336 336 Firm energy sales outside PVNGS 1, 2&3 0 0 0 0 0 0 0 5,419 0

7, 642 7, 838 8,172 8,589 8,897 9,839 10,778 11,632 12, 112 12,776 13,385 14,189 14,881 15,643 16,186 16,711 17,393 18,131 18,888 Annual energy (CE+FES) 2. 777 2, 849 3, 102 3,313 3, 518 4,364 4,936 6, 119 6, 700 Firm energy purchases outside (672) (602) (754) (754) (586) (586) (586) (586) (586) (586) (586) (586) (586) (586) (586) (586) (586) (586)

PVNGS 1,2&3 (81) (254) (306) (405) (577) (844) (908) (1,372) (825) (965) (739) 18,302 2, 595 2,796 2, 908 2, 941 3, 520 4,028 4,047 5, 294 5, 735 6, 903 7,166 7, 570 7,835 8, 143 9, 253 10,192 11,046 11,526 12,190 12, 799 13,603 14, 295 15, 057 15,600 16,125 16, 807 17,545 Adjusted annual energy (AE-FEP) 2, 696 1.1.2 Power supply (MW) 758 845 1,155 1,336 1,627 2, 152 2, 241 2,449 2,450 2, 468 3, 074 3, 190 3, 618 3,615 3, 912 3, 906 4, 203 4, 203 4, 203 4, 203 4, 203 4, 323 4, 503 Installed resources 607 608 611 610 610 681 130 124 123 156 153 221 269 163 163 163 163 163 163 163 163 163 56 56 56 56 56 56 56 56 Nonf irm purchases outside PVNGS 1, 2&3 47 147 148 140 135 0 0 0 0 0 0 0 0 0 0 0 0 Nonfirm purchases within PVNGS 1,2&3 0 0 0 0 0 0 0 80 0 0 0 0 163 0

163 0

163 0

163 0

163 0

163 163 163 163 56 56 56 56 56 56 56 56 Total nonfirm purchases 47 147 148 140 135 130 124 203 156 153 221 269 0 0 0 0 0 0 0 0 0 P R.C 0 0 0 0 0 0 0 0 0 Nonfirm sales outside PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0 Nonfirm sales with in PVNGS 1,2&3 ~62 ) ~62 ) ~62 ~62 ) ~62 ) ~62 (62)

) ~62 (62)

~62 )

(62)

~62 (62)

~62 )

(62)

~62 (62)

) ~62 (62)

) ~62 (62)

~62 )

(62)

~62 (62)

~62 (62)

~62 (62)

~62 (62)

) ~202 )

(202)

(202)

(202)

~13 2 (132)

~132)

(132)

~62 )

(62)

~62 )

(62)

~62 )

(62)

~62 )

(62)

~62 (62)

~62 (62)

) ~(6 2 (62) APERTURE Total nonfirm sales (62) (62) (62) (62) (62)

GARO Noncommitted 820 986 1,249 1,427 1, 786 2, 359 2, 342 2, 550 2, 551 2, 569 3, 175 3, 291 3, 579 3, 576 3, 943 3, 830 4,197 4,197 4,197 4, 197 4,197 4, 317 4,497 Capability (IR+NFP-NFS) 592 693 697 688 683 749 442 722 810 1,106 1,184 1,436 1,657 1,759 1,723 1,834 2,144 2 272 2,412 2, 544 2, 670 2, 791 2, 941 3, 069 3,195 3,285 3, 370 3,478 3,588 3,696 1.1.3 Capacity requirement 521 508 485 437 599 ~

243 350 702 583 827 717 425 903 879 1,035 906 1,152 889 1, 128 1,002 912 827 719 729 801 Reserve (C-AAPD) (MW) 71 185 212 246 246 150 98 176 143 20. 21.7 13.6 36.4 43. 55.7 56.3 25.0 13.6 21.7 12. 20. 24.4 42.4 33.1 48.0 39.1 19.8 39.7 36.4 40.7 33.9 41.3 30. 2 36. 8 31.4 27.8 24. 5 20.7 3 Percent margin (100xR/AAPD) (%) 7 9 5 1.1-25/26 Blank (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.

ER-OL NEED FOR POWER SOUTHERN CALIFORNIA EDISION COMPANY Year 1964 1965 1966 1967 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 Table 1.1-1 LOADS AND RESOURCES

SUMMARY

1.1.1 Load characteristics, demand (MW) 1964 THROUGH 1992 (Sheet 7 of 7)

Company peak demand 5617 6034 6448 7164 7707 8092 8556 9632 10132 10535 10279 10369 11292 11564 12159 12361 12361 13101 13581 14091 14621 15071 15551 16051 16515 17025 17509 18069 18639 Firm sales outside PVNGS 1,2&3 35 35 258 32 40 79 135 Firm sales within PVNGS 1,2&3 150 150 0 0 0 0 Total firm sales (TFS) 185 185 258 32 40 79 135 Annual peak demand (CPD+TFS) 5617 6034 6448 7164 7707 8092 8556 9817 10317 10535 10279 10369 11292 11822 12159 12393 12671 13180 13716 14091 14621 15071 15551 16051 16515 17025 17509 18069 18639 Firm purchases outside PVNGS 1,2&3 (363 ) (260) (378) (376) (376) (376) (517) (611) (611) (611) (611) (611) (611) (823) (611) (611) (870) (870) (870) (870) (870) (870) (870) (870) (870)

Firm purchases within PVNGS 1,2&3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Total firm purchases (TFP) (363) (260) (378) (376) (376) (376) (517) (611) (611) (611) (611) (611) (611) (823) (611) (611) (870) (870) (870) (870) (870) (870) (870) (870) (870)

Adjusted annual peak demand 5617 6034 6448 7164 7344 7832 8178 9441 9941 10159 9762 9758 10681 11211 11548 11782 12060 12357 13105 13480 13751 14201 14681 15181 15645 16155 16639 17199 17769 (APD-TFP ID) 1.1.1 Load characteristics, energy (GWh)

Company energy 31529 34499 37821 40592 44088 46953 49961 52840 55608 57846 55113 55861 57916 60626 61560 62659 64815 67210 69720 72500 75630 78160 80870 83480 86000 86610 91370 94210 971.00 Firm energy sales outside PVNGS 1,2&3 612 420 511 675 529 772 963 1323 1687 1944 1492 1152 1620 4172 1626 3 240 3125 3136 3405 2480 2254 2112 2192 1802 1355 1645 1910 1899 2001 Annual Energy (CE-FES) 32141 34919 38332 41267 44617 47725 50924 54163 57295 59430 56605 57013 59536 64798 63186 65899 67940 70346 73125 74980 77884 80272 83062 85282 87355 90255 93280 96109 99101 Firm energy purchases outside 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 PVNGS 1,2&3 Adjusted annaul energy (AE-FEP) 32141 34919 38332 41267 44617 47725 50924 54163 57295 59430 56605 57013 59536 64798 63186 65899 67940 70346 73125 74980 77884 80272 83062 85282 87355 90255 93280 96109 99101 1.1.2 Power supply (MW)

Installed resources 6752 7086 8046 8870 9088 97 24 10639 11108 12344 13026 13134 13127 13247 13798 14158 14375 14423 14622 15676 16106 16306 16727 17319 17948 18728 19148 19725 20274 20933 Nonfirm purchases outside PVNGS 1,2&3 0 0 Nonfirm purchases within PVNGS 1,2&3 0 0 Total nonfirm purchases 0 PRO Nonfirm sales outside Nonfirm sales within PVNGS 1,2&3 PVNGS 1,2&3 15 0

16 0

17 0

16 0

32 0

32 0

32 0

APERTUpp Total nonfirm sales 15 16 17 16 32 32 32 CARD Noncommitted Capability (IR+NFP-NFS) 6752 7086 8046 8870 9088 9724 10639 11108 12344 13026 13134 13127 13247 13798 14143 14359 14486 14606 15644 16074 16274 16727 17319 17948 18728 19148 19725 20274 20933 1.1.3 Capacity requirement Reserve (C-AAPD) (MW) 1135 1052 1598 1706 1744 1892 2461 1667 2403 2867 3372 3369 2566 2587 2595 2577 2346 2249 2539 2594 2523 2526 2638 2767 3083 2993 3086 3075 3164 Percent margin (100xR/AAPD) (%) 20.2 17.5 24.8 23.8 23.7 24.2 30.1 17.6 24. 2 28.2 34. 6 34.5 24.0 23.1 22.5 21.9 19.5 18.2 19.3 19.2 18.4 17.8 18.0 18.2 19.7 18.5 18.6 17.9 17.8 1.1-27/28 Blank

PVNGS ER-OL 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 PVNGS PARTICIPANTS (1 of 8)

Total YEAR: 1981 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Energy 1.1.1 Load characteristics, demand (MW)

Company monthly peak demand 18024 17509 17316 17549 19817 22180 23645 23998 23205 19723 13468 18858 Firm sales 794 790 688 637 701 912 929 928 793 700 738 742 Monthly peak demand 18818 18299 18004 18186 20518 23092 24574 24926 23998 20423 19206 19600 (PVNGS-1,2&3+FS)

Firm Purchases (a) 67 65 74 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand 18751 18234 17930 18059 20370 22926 24408 14760 23832 20355 19143 19532 (MPD-FP) 1.1.1 Load characteristics, energy (GWh)

PRg Company monthly energy 9806 8741 9631 9392 9907 10556 11572 11778 10780 10252 9491 9900 121806 APppg~~

Firm energy sales (a) 756 692 612 586 752 788 859 868 780 737 732 775 8937 CAPg Firm energy purchases 28 29 36 59 66 77 88 82 71 28 25 28 617 Monthly energy requirement 10534 9404 10207 9919 10593 11267 12343 12564 11489 10961 10198 10647 130126 (PVNGS-1,2&3+FES-FEP)

(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)

Total YEAR: 1982 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 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 19547 19016 18801 18999 21457 24125 25660 26031 25060 21326 20048 20461 (PVNGS-1,2&3+FS)

Firm Purchases ( ) 67 65 74 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand 19480 18951 18727 18872 21309 23959 25494 25865 24894 21258 19985 20393 (MPD-FP) 1.1.1 Load characteristics, energy (GWh)

Company monthly energy 10234 9112 10052 9786 10343 11023 12088 12305 11253 10702 9917 10339 127154 PRG Firm energy sales (a) 800 744 771 738 779 809 869 898 842 798 775 803 9626 Firm energy purchases 28 29 36 59 66 77 88 82 71 28 25 28 617 APERTURE Monthly energy requirement CARD (PVNGS 1 f 2 &3+FES PEP ) 11006 9827 10787 10465 11056 11755 12869 13121 12024 11472 10667 11114 136163 (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)

Total YEAR: 1983 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 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 20246 19680 19454 19663 22245 24869 26447 26835 25942 22052 20701 21138 (PVNGS 1,2&3+F8)

Firm Purchases (a) 67 65 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand 20179 19615 19380 19536 22097 24703 26281 26669 25776 21984 20638 21070 (MPD-FP) 1.1.1 Load characteristics, energy (GWh)

Company monthly energy 10717 9542 10515 10242 10834 11561 12671 12908 11804 11205 10375 10828 133202 Firm energy sales (a) 762 706 692 626 624 635 674 701 640 648 630 657 7995 PRC Firm energy purchases 28 29 36 59 66 77 88 82 71 28 25 28 617 APERTURE Monthly energy requirement 11451 10219 11171 10809 11392 12119 13257 13527 12373 11825 10980 11457 140580 CARD (PVNGS-1,2&3+FES FEP)

(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)

Total YEAR: 1984 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Energy 1.1.1 Load characteristics, demand (MW)

Company monthly peak demand 20327 19748 19514 19787 22426 25128 26752 27155 26242 22295 20827 21269 Firm sales 681 677 675 622 693 722 740 738 722 618 909 914 Monthly peak demand 21008 20425 20189 20409 23119 25850 27492 27893 26964 22913 21736 22183 (PVNGS-1,2&3+FS)

Firm Purchases (a) 65 74 128 148 166 166 166 166 68 63 68 Adjusted monthly peak demand 20941 20360 20115 20281 22971 25684 27326 27727 26798 22845 21673 22115 (MPD-FP) 1.1.1 Load characteristics, energy (GWh)

Company monthly energy 11214 10161 10995 10703 11329 12101 13270 13507 12346 11714 10842 11314 139496

(

Firm energy sales )

667 589 631 607 593 601 646 664 615 609 583 644 7449 Firm energy purchases 28 29 36 59 66 77 88 82 71 28 25 28 617 PRC Monthly energy requirement (PVNGS-1,2&3+FES-FEP) 11853 10721 11590 11251 11856 12625 13828 14089 12890 12295 11400 11930 146328 APERTURE CARD (a) Sales and purchases to Companies other than the PVNGS-1, 2 & 3 participants.

1.1-35/36 Blank

PVNGS ER-OL NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 5 of 56)

PVNGS PARTICIPANTS PVNGS PARTICIPANTS (5 of 8) Page 5 of 8 Total YEAR: 1985 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Energy 1.1.1 Load characteristics, demand (MW)

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 22019 21442 21161 21403 23984 26911 28588 28995 28034 23829 22557 23028 (PVNGS-1,2&3+FS)

Firm Purchases (a) 67 65 74 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand 21952 21377 21542 21276 23836 26745 28422 28829 27868 23761 22494 22960 (MPD-FP) 1.1.1 Load characteristics, energy (GWh)

Company monthly energy 11705 10424 11469 11169 11831 12641 13875 14134 12909 12239 11326 11813 145535 Firm energy sales (a) 639 566 601 589 558 603 667 679 608 620 593 650 7373 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 12831 11894 12435 152291 PRC--

APEpyg~~

(a) sales and purchases to companies other than the PvNGs-l, participants.

2 & 3 CAPg 1.1-37/38 Blank

PVNGS ER-OL NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 6 of 56)

PVNGS PARTICIPANTS PVNGS PARTICIPANTS (6 of 8) Page 6 of 8 Total YEAR: 1986 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Energy 1.1.1 Load characteristics, demand (MW)

Company monthly peak demand 21873 21299 21025 21309 24185 27151 28863 29279 28307 24065 22416 22894 Firm sales 942 937 935 884 703 788 808 806 788 676 963 968 Monthly peak demand 22815 22236 21960 22193 24888 27939 29671 30085 29095 24741 23379 23862 (PVNGS-1,2&3+FS)

Firm Purchases (a) 67 65 74 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand 22748 22171 21886 22066 24740 27773 29505 29919 28929 24673 23316 23794 (MPD-FP) 1.1.1 Load characteristics, energy (GWh)

Company monthly energy 12183 10848 11929 11624 12311 13170 14452 14729 13455 12743 11788 12290 151522 Firm energy sales (a) 662 595 633 606 583 637 694 708 648 641 617 673 7697 Firm energy purchases 28 29 36 59 66 77 88 82 71 28 25 28 617 PRC Monthly energy requirement 12817 11414 12526 12171 12828 13730 15058 15355 14032 13356 12380 12935 158602 APERTURE)

(PVNGS-1,2&3+FES-FEP)

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)

Total YEAR. 19 87 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Energy 1.1.1 Load characteristics, demand (MW)

Company monthly peak demand 22635 21985 21757 22044 25064 28192 29947 30372 29366 24969 23232 23695 Firm sales 969 965 962 913 734 825 846 844 826 710 1622 1627 Monthly peak demand 23604 22950 22719 22957 25798 29017 30793 31216 30192 25679 24854 25322 (PVNGS-1,2&3+FS)

Firm Purchases (a) 67 65 74 127 148 166 166 166 166 68 63 68 Adjusted monthly peak demand 23537 22885 22645 22830 25650 28851 30627 31050 30026 25611 24791 25254 (MPD FP) 1.1.1 Load characteristics, energy (GWh)

Company monthly energy 12663 11260 12433 12066 12797 13708 15053 15333 14007 13257 12263 12826 157666 Firm energy sales (a) 708 644 669 649 611 674 725 643 567 551 529 605 7575 Firm energy purchases 28 29 36 66 77 88 82 71 28 25 28 617 P R C

'-':-'PERTURE Monthly energy requirement 13343 11875 13066 12656 13342 14305 15690 15894 14503 13780 12767 13403 16462,4 (PVNGS-1,2&3+FES-FEP)

CARD (a) Sales and purchases to Companies other than the PVNGS-1, 2 a 3 participants.

1.1-41/42 Blank

PVNGS ER-OL NEED FOR POWER Table 1.1-2 LOAD AND ENERGY REQUIREMENTS BY MONTH 1981 THROUGH 1988 (Sheet 8 of 56)

PVNGS PARTICIPANTS of Page 8 of 8 PVNGS PARTICIPANTS (8 8)

Total YEAR: 1988 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Energy 1.1.1 Load characteristics, demand (MW)

Company monthly peak demand 23429 22755 22474 22781 25918 29168 30977 31408 30409 25826 24006 24518 Firm sales 1625 1624 1621 1666 767 862 884 882 863 743 1651 1657 Monthly peak demand 25057 24379 24095 24447 26685 30030 31861 32290 31272 26569 25657 26175 (PVNGS-1,2&3+FS)

Firm Purchases (a) 67 65 74 127 148 166 166 166 166 65 68 Adjusted monthly peak demand 24990 24314 24021 24320 26537 29864 31695 32124 31106 26501 25594 26107 (MPD-FP) 1.1.1 Load characteristacs, energy (GWh)

Company monthly energy 13150 11877 12846 12488 13253 14220 15618 15910 14537 13735 12700 13257 163591 Firm energy sales (a) 631 565 596 598 562 625 676 703 607 620 588 648 7419 Firm energy purchases 28 29 36 59 66 77 88 82 71 28 25 28 617 Monthly energy requirement 13753 12413 13406 13027 13749 14768 16206 16531 15073 14327 13263 13877 170393 (PVNGS-1,2&3+FES-FEP)

PRC APERTURE (a) Sales and purchases to Companies other than the PVNGS-1, 2 3 participants.

CARD 1.1-43/44 Blank

PVNGS ER-OL NEED FOR POWER SALT RIVER PROJECT Total Table 1.1-2 Year 1986 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Energy LOAD AND ENERGY REQUIREMENTS BY MONTH

l. l. 1 Load characteristics, 1981 THROUGH 1988 (Sheet 46 of 56) demand (MW) SALT RIVER PROJECT (a) Page 6 of 8 Company peak demand 1,776 1,716 1,710 1,813 2,461 2,849 2,909 2,855 2,775 2, 170 1,710 1,824 Firm sales outside 60 60 60 60 60 60 60 60 60 60 60 PVNGS 1,2&3 Firm sales within 251 251 251 251 251 260 260 260 260 260 260 260 PVNGS 1,2&3 Total firm sales (TFS) 311 311 311 311 311 320 320 320 320 320 320 320 Monthly peak demand 2,087 2,027 2,021 2,124 2,772 3,169 3,229 3,175 3,095 2,490 2,030 2,144 (CPD+TFS)

Firm purchases outside (63) (62) (71) (123) (143) (160) (160) (160) (160) (64) (59) (64)

PVNGS 1,2&3 Firm purchases within 0 0 PVNGS 1,2&3 Total firm purchases (TFP) (63) (62) (71) (123) (143) (160) (160) (160) (160) (64) (59) (64)

Ad3usted monthly peak 2,024 1,965 1,950 2,001 2,629 3,009 3,069 3,015 2,935 ',426 1,971 2,080 demand (MPD-TFP-ID)

l. l. 1 Load characteristics, energy (GWh)

Company monthly 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 (includes interruptible energy)

Firm energy sales outside 35 33 37 20 26 28 34 20 16 27 336 PVNGS 1,2&3 Firm energy purchases (26) (27) (34) (57) (63) (74) (84) (78) (68) (26) (23) (26) (586) outside PVNGS 1,2&3 Monthly energy requirement 1,179 1,013 1, 009 923 1,014 1,239 1,460 1,559 1,558 1,316 1,020 1,005 14,295 PRC (CME+FES-FEP)

APERTURE (a) Interruptible demand is not included in the is planned to supply interruptible demand.

peak load forecast, and no generation CARD 1.1-119/120 Blank

PVNGS ER-OL NEED FOR POWER SALT RIVER PROJECT Total Table 1.1-2 Year 1987 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Energy LOAD AND ENERGY REQUIREMENTS BY MONTH 1.1.1 Load characteristics, 1981 THROUGH 1988 (Sheet 47 of 56) demand (MW)

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 60 60 60 60 60 60 60 60 60 60 60 60 PVNGS 1,2&3 Firm sales within 260 260 260 260 260 271 271 271 271 271 271 271 PVNGS 1,2&3 Total firm sales (TFS) 320 320 320 320 320 331 331 331 331 331 331 331 Monthly peak demand 2,165 2,049 2,097 2,204 2,878 3,293 3.355 3,299 3,215 2,586 2,108 2,226 (CPD+TFS)

Firm purchases outside (63) (62) (71) (123) (143) (160) (160) (160) (160) (64) (59) (64)

PVNGS 1,2&3 Firm purchases within PVNGS 1,2&3 Total firm purchases (TFP) (63) (62) (71) (123) (143) (160) (160) (160) (160) (64) (59) (64)

Adjusted monthly peak 2,102 1,987 2,026 2,081 2,735 3,133 3,195 3,139 3,055 2.522 2,049 2,162 demand (MPD-TFP-ID)

l. 1.1 Load characteristics, energy (GWh)

Company monthly energy 1,232 1,060 1,059 1,009 1,106 1,350 1, 589 1,687 1,683 1,393 1,082 1,057 15,307 (includes interruptible energy)

Firm energy sales outside 35 33 37 20 26 28 34 34 26 20 16 27 336 PVNGS 1,2&3 Firm energy purchases (26) (27) (34) (57) (63) (74) (84) (78) (68) (26) (23) (26) (586) outside PVNGS 1,2&3 Monthly energy requirement 1,441 1,066 1,062 972 1,069 1,304 1,539 1,643 1,641 1,387 1,075 1,058 15,057 PRC (CME+FES-FEP)

APERTURE (a) Interruptible demand is not included in the peak load forecast, and no generation .. CARD is planned to supply interruptible demand.

1.1-121/122 Blank

PVNGS ER OL ARIZONA NEW MEXICO & SOUTHERN CALIFORNIA NEVADA NEED FOR POWER Year 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 Table 1.1-3 LOAD AND RESOURCES

SUMMARY

COMBINED 1.1.1 Load Characteristics, demand (MW) ARIZONA-NEW MEXICO (AZ-NM) AND (AZ-NM) system peak demand 5,590 6,104 6,502 6,565 6,958 7,110 7,383 8, 329 8,948 9, 569 10, 200 10,803 11,421 12,267 12, 921 13,650 14,262 SOUTHERN CALIFORNIA-NEVADA (SoCA NV)

(SoCA-NV) system peak demand 16,807 17,201 16,817 17,009 18,580 18,815 20,150 20, 807 21,463 22,350 23, 265 23,810 24,749 25,631 26,543 27,521 28,450 23,574 25,538 25,925 27,533 29,136 30,411 31,919 33,465 34,613 36,170 37,898 39,464 41,171 42,712 SYSTEMS AS REPORTED TO THE WSCC (a)

Combined system peak demand 22,397 23,305 23,319 (1972 THROUGH 1987)

Firm sales outside combined system 0 0 0 0 0 605 148 316 197 25 28 31 35 38 358 927 1,496 Combined system annual peak demand 22,397 23,305 23,319 23,574 25, 538 26,530 27,681 29,452 30,608 31,944 33,493 33, 644 36, 205 37,936 39,822 42, 098 44,208 Firm purchases outside combined system 2,084 2,214 2,471 2,316 2,311 2, 349 2,537 2,593 2,762 2,963 2,623 2, 312 2, 347 2,365 1,878 1,231 1,184 Combined system interruptible demand 0 0 0 0 11 28 42 129 179 183 187 191 195 465 569 713 718 Combined system adjusted annual peak demand 20,313 21,091 20,848 21,198 23,216 24,153 25,102 27,730 27,667 28,798 30, 683 32,141 33,663 35,106 37,375 40, 146 42, 306 1.1.1 Load characteristics, energy (GWh)

(AZ-NN) system annual energy 27,252 30,082 31,878 30,082 34, 034 35,787 37,387 40,973 44,973 49,211 52,989 56, 606 60, 204 64,570 68,439 72,675 76, 377 (SoCA-NV) system annual energy 90,841 94,214 90,394 91,025 95,716 96,666 102,317 103,347 103,969 110, 660 115,047 118,304 122, 977 127, 383 132,220 316,963 141,910 Combined system annual energy 118,093 124,296 122,272 121,107 129,750 132,453 139,704 144,320 148,942 159,871 168,036 174,910 183,181 191,953 200,659 209,638 218,287 Firm energy sales outside combined system (b) (b) (b) (b) 753 9, 599 2, 993 4, 934 4, 590 4,327 4, 450 4, 085 3,919 3, 927 4,399 5, 979 8, 267 Firm energy purchases outside combined system (b) (b) (b) (b) 2,985 8, 716 18, 025 3,541 6, 282 6,959 5, 874 5, 579 5, 395 5, 559 5,573 5, 592 5, 644 Combined system interruptible energy (b) (b) (b) (b) 148 233 258 290 326 414 414 414 414 1,300 1,987 2, 730 2, 730 Combined system annual energy requirement 127,370 133, 103 124,414 145,423 146,920 156,825 166,198 173,002 181, 291 189, 021 197,498 207, 295 218,180 1.1.1 Power supply (MW)

(AZ-NN) system installed resources 6, 678 7,170 8,365 9,922 10,685 11, 027 9, 605 10, 284 11, 607 11,854 13,386 13,528 14,780 15,562 16,680 17,149 18,210 (SoCA-NV) system installed resources 18,635 19,764 20,259 20,954 21,151 22, 197 24,771 25, 638 25,760 26,104 27,447 28,405 29,182 29,627 30,739 32,320 33,790 Combined system installed resources 25,313 26,934 28,624 30,876 31,836 33, 224 34,376 35,922 37,367 37,958 40,833 41,933 43,962 45,189 47,419 49,469 52,000 Nonfirm sales outside combined system (b) (b) (b) (b) (b) (b) (b) (b) (b) (b) (b) (b) (b) (b) (b) (b)

Nonfirm purchases outside combined system Combined system maintenance and force outage (b) 1,868 (b) 3,569 (b) 3,480 (b) 2,954 (b) 4, 058 (b) 3, 288 (b) 6, 266 (b) 378 (b) 534 (b) 507 (b) 329 (b) 353 (b) 199 (b) 178 (b) 427 (b) 532 784 PRC Combined system capability 23,445 23,365 25,144 27,922 27,778 29,936 28,110 35, 544 36,833 37,451 40, 504 41, 580 43,763 45, 011 46,992 48,937 51,216 APERTURE 1.1.1 Capacity requirement CARD Reserve (MW) 3 132 2,274 4,296 6,724 4, 562 5, 783 3,008 7,814 9, 166 8, 653 9,821 9,439 10, 100 9, 905 9,617 8,791 8,910 Percent margin (%) 15.4 10.8 20.6 31.7 19.7 23.9 12.0 28.2. 33.1 30.0 32.0 29.4 30.0 28. 2 25.7 21.9 21.1

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

PVNGS ER-OL NEVA NEED FOR POWER ARIZONA NEW MEXICO & SOUTHERN CALIFORNIA Table 1.1-4 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec LOADS

SUMMARY

BY MONTH COMBINED ARIZONA-NEW MEXICO (AZ-NM) AND Year: 1982 SOUTHERN CALIFORNIA-NEVADA (SoCA-NV) 1.1.1 Load characteristic, demand (MW)

SYSTEMS AS REPORTED TO THE WSCC (AZ-NM) system peak demand 6, 923 6, 671 6, 726 7,248 8,707 9, 975 10,221 10, 200 9, 869 8, 023 6, 980 7,300 1982 THROUGH 1987 (SoCA-NV) system peak demand 18,263 17,750 17,397 17,116 18,916 20,960 22,684 23, 265 22,374 19,354 18,937 19,294 Combined system peak demand 25,186 24, 421 24,123 24, 364 27, 623 30,935 32, 905 33, 465 32, 243 27 377 25,917 26, 594 Sheet 1 of 3 Firm sales outside combined system 125 125 125 28 28 28 28 28 28 28 128 128 Combined system monthly peak demand 25,311 24,546 24,248 24,392 27,651 30, 963 32,933 33,493 32, 271 27,405 26, 045 26,722 Firm purchases outside combined system 2,455 2,407 2,415 2, 471 2,631 2, 683 2,675 2,623 2, 592 2, 375 2, 321 2, 390 Combined system interruptible demand 177 177 177 177 177 187 187 187 187 187 177 177 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 7 ~ 377 7, 110 7,164 7,707 9, 253 10,599 10, 835 10,803 10, 450 8,500 7, 403 7, 741 (SoCA-NV) system peak demand 18, 732 18,194 17,833 17,519 19,317 21,370 23,148 23,810 22,894 19,731 19,339 19,647 Combined system peak demand 26,109 25,304 24,997 25, 226 28,570 31,969 33,973 34,613 33,344 28,231 26,742 27,388 Firm sales outside combined system 26,237 128 128 25,432 128 25,125 31 25, 257 31 28,601 31 32, 000 31 34,004 31 34,644 31 33,375 31 28, 262 131 26,873 131 27,519 PRC Combined system monthly peak demand Firm purchases outside combined system Combined system interruptible demand 2,438 181 2,422 181 2, 398 181 2, 159 181 2,315 181 2, 304 191 2, 345 191 2, 312 191 2,318 191 2, 128 191 2, 123 181 2,156 181 APERTURE Combined system adjusted monthly CARD peak demand 23, 618 22, 829 22, 546 22,917 26,105 29,505 31,468 32,141 30,866 25,943 24,569 25,182 1.1-143/144 Blank

PVNGS ER-OL NEED FOR POWER ARIZONA NEW MEXICO & SOUTHERN CALIFORNIA NEVADA Table 1.1-4 LOADS

SUMMARY

BY MONTH COMBINED Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec ARIZONA-NEW MEXICO (AZ-NM) AND SOUTHERN CALIFORNIA-NEVADA (SoCA-NV)

Year: 1984 SYSTEMS AS REPORTED TO THE WSCC 1.1.1 Load characteristic, demand (MW) 1982 THROUGH 1987 (AZ-NM) system peak demand 7,780 7,494 7, 552 8,121 9, 746 11,204 11,444 11,421 11,045 8, 995 7, 845 8, 219 Sheet 2 of 3 (SoCA-NV) system peak demand 19,387 18,836 18,445 18,137 20,207 22,290 24,107 24,749 23,800 20, 492 20, 148 20,408 Combined system peak demand 27,167 26,330 25,997 26,258 29,953 33,494 35,551 36,170 34,845 29, 487 27,993 28, 627 Firm sales outside combined system 131 131 131 35 35 35 35 35 35 35 135 135 Combined system monthly peak demand 27,298 26,461 26, 128 26, 293 29,988 33,529 35, 586 36,205 34,880 29, 522 28,128 28,762 Firm purchases outside combined system 2,101 2,119 2, 056 2, 140 2,406 2,394 2,396 2,347 2,330 2, 103 2,129 2,103 Combined system interruptible demand 185 185 185 185 185 195 195 195 195 195 185 185 Combined system adjusted monthly peak demand 25, 012 24,157 23,887 23,968 27,397 30,940 32, 995 33,663 32,355 27,224 25,814 26,474 Year: 1985 1.1.1 Load characteristic, demand (MW)

(AZ-NM) system peak demand 8, 326 8,083 8, 238 8,842 10,541 12, 040 12, 294 12, 267 11, 854 9, 637 8, 362 8, 738 (SoCA-NV) system peak demand 20,070 19,485 19,085 18,762 20, 881 23,065 24,911 25, 631 24,575 21, 248 20,775 21, 045 Combined system peak demand 28,396 27,568 27 323 27,604 31,422 35,105 37,205 37,898 36,429 30,885 29,137 29, 783 Firm sales outside combined system 135 135 135 38 38 38 38 38 38 38 38 38 PRG Combined system monthly peak demand Firm purchases outside combined system 28,531 2,102 27,703 2, 077 27,458 2,061 27,642 2,111 31,460 2,398 35,143 2,411 37, 243 2, 341 37,936 2,365 36,467 2, 362 30, 923 2, 097 29,175 2,118 29, 821 2, 110 APERTURP Combined system interruptible demand 277 339 439 449 451 465 465 465 445 375 289 279 CARD Combined system adjusted monthly peak demand 26, 152 25, 287 24,958 25,082 28,611 32, 267 34,437 35,106 33,660 28,451 26,768 27,432 1,1-145/146 Blank

PVNGS ER-OL ARIZONA NEW MEXICO & SOUTHERN CALIFORNIA NEVADA NEED FOR POWER Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Table 1.1-4 LOADS

SUMMARY

BY MONTH COMBINED ARIZONA-NEW MEXICO (AZ-NM) AND Year: 1986 SOUTHERN CALIFORNIA-NEVADA (SoCA-NV) 1.1.1 Load characteristic, demand (MW) SYSTEMS AS REPORTED TO THE WSCC (AZ-NM) system peak demand 8,744 8,492 8, 638 9,260 11, 094 12, 678 12,949 12,921 12,460 10, 107 8,764 9, 163 1982 THROUGH 1987 (SoCA-NV) system peak demand 20,724 20,101 19,701 19,386 21,621 23,973 25,804 26,543 25,490 22, 020 21,481 21,822 Sheet 3 of 3 Combined system peak demand 29,468 28,593 28,339 28,646 32,715 36,651 38,753 39,464 37,950 32, 127 30,245 30,985 Firm sales outside combined system 138 138 138 42 42 42 358 358 358 358 458 458 Combined system monthly peak demand 29,606 28,731 28, 477 28,688 32,757 36, 693 39,111 39,822 38,308 32,485 30, 703 31,443 Firm purchases outside combined system 2,090 2,020 1, 984 2I 132 2,385 2, 404 2, 388 1,878 1,840 1,620 1,644 1,611 Combined system interruptible demand 313 383 473 473 538 565 569 569 523 413 308 303 Combined system adjusted monthly peak demand 27, 203 26, 328 26, 020 26, 083 29, 834 33, 724 36, 154 37, 375 35, 945 30, 452 28, 751 29, 529 Year: 1987 1.1.1 Load characteristic, demand (MW)

(AZ-NM) system peak demand 9,330 9, 052 9, 258 9, 902 11,759 13,400 13,677 13,650 13, 105 10, 672 9, 327 9, 760 (SoCA-NV) system peak demand 21,481 20,724 20,412 20,080 22,391 24,812 26,712 27,521 26,411 22,807 22, 336 22,520 Combined system peak demand 30,811 29,776 29, 670 29,982 34,150 38,212 40,389 41, 171 39,516 33,479 31, 663 32, 280 Firm sales outside combined system 458 458 458 362 362 362 677 677 677 677 777 777 Combined system monthly peak demand 31,269 30,234 30,128 30,344 34,512 38,574 41,066 41,848 40,193 34, 156 32, 440 33,057 Firm purchases outside combined system 1,555 1,404 1,470 1,583 1,816 1, 792 1,801 1, 239 1,215 980 1, 031 990 Combined system interruptible demand 489 549 698 698 703 713 713 713 603 515 461 472 Combined system adjusted monthly peak demand 29,225 28,281 27,960 28,063 31,993 36,069 38,552 39,896 38,375 32,661 30,948 31,595 PRC APERTURE CARD 1.1-147/148 Blank

PVNGS ER-OL NEED FOR POWER PVNGS 1, 2 F 3 PARTICIPANTS Table 1.1-7 MONTHLY PEAK DEMAND (MW)

COMPARISON OF MONTHLY PEAK DEMANDS Month 1972 1973 Change (%) 1974 Change (5) 1975 Change (%) 1976 Change (g) 1977 Change (){) 1978 Change (I) AND ENERGY REQUIREMENTS 1972 THROUGH 1978 (Sheet 1 of 7)

Jan 13457 14558 8.2 13607 -6. 5 14478 6.4 14431 0.3 15503 7.4 15664 1.0 Feb 13097 13910 6. 2 12566 9.7 13786 9.7 14433 4.7 14786 2.4 15262 3.2 Mar 12826 13918 8.5 12553 9.8 13348 6.3 14527 8.8 14695 1.2 14700 0.0 Apr 13406 14094 5.1 13464 4 5 9.6 13319 -1.1 14483 8.8 14973 3.4 14764 -l. 4 May 15130 15941 5. 4 14409 14898 3.4 17038 14.4 16709 1.9 18076 8.2 Jun 15873 18312 15. 4 17875 2. 4 15903 11.0 19990 25.7 18307 -8. 4 20084 9.7 Jul 17468 17806 1.9 18227 2.4 18192 0.2 19480 7.1 20346 4.4 21243 4.4 Aug 17368 17495 0.7 17319 1.0 18586 7.3 19895 7.0 20186 1.5 20690 2.

Sep 15992 16735 4.6 '7852 6.7 18398 3.1 18795 2.2 20405 8.6 21588 5.8 Oct 14942 15472 3. 5 '6033 3.6 16205 1.1 16051 1.0 16251 1.2 18216 12.1 Nov 13957 14509 4. 0 13853 4.5 14315 3.3 15849 10.7 15191 4.2 15950 5.0 Dec 15104 13806 8.6 14252 3.2 14749 3.5 15394 4.4 15594 1.3 17162 10.1 MONTHLY ENERGY REQUIREMENTS (GWH)

Month 1972 1973 Change (g) 1974 Change ()l) 1975 Change (%) 1976 Change {)() 1977 Change ()l) 1978 Change (5)

Jan 7242.8 6719.5 7855.9 8.5

+2.

7286.9 6487.3

-7.2 6.1 7757.7 6.5 7918.4 2.1 8263.9 4.4 8375.5 l. 4 Feb 6910.7 8 6906.0 6.5 7299.4 5.7 7351.4 0.7 7501.5 2.0 Mar 7306.4 7688.4 5. 2 7115.6 -7.5 7500.7 5.4 7996.8 6.6 8334.6 4.2 8210.1 1.5 Apr 7017.8 7359.2 4.9 7003.7 4.8 7347.5 4.9 7682.6 4.6 7998.0 4.1 7943.6 0.7 May 7633.3 8078.3 5. 8 7680.2 4.9 7702.4 0.3 8252.7 7.1 8208.6 0.5 8794.6 7.1 Jun 7944.1 8564.8 7.8 8347.6 2.5 7974.8 -4.5 8931.2 12.0 9060.8 1.5 9654.1 6.5 Jul 8774.2 9045.4 3.1 8992.2 -0.6 8990.6 0.0 9545.9 6.2 9827.4 2.9 10378.3 5.6 Aug 8814.8 9212.7 4. 5 8835.4 4.1 8942.1 1.2 9378.3 4.9 10263.3 9.4 10289.8 0.3 Sep 7861.9 8098.3 3.0 8398.7 3.7 8484.5 1.0 8548.4 0.8 8982.0 5.1 9505.4 5.8 Oct 7564.0 8086.8 6.9 7838.2 -3.1 7953.5 1.5 8240.2 3.6 8489.6 3.0 9154.6 7.8 Nov 7270.3 7512.2 3.3 7163.1 4.6 7403.5 3.4 7834.7 5.8 7950.9 1.5 8443.2 6.2 Dec 7780.0 7292.1 6. 3 7644.7 4.8 7869.5 2.9 8264.6 5. 0 8296.6 0.4 8982.7 8.3 PRC APERTURE CARD 1.1-151/152 Blank

PVNGS ER-OL NEED FOR POWER ARIZONA PUBLIC SERVICE COMPANY Table 1.1-7 COMPARISON OF MONTHLY PEAK DEMANDS Monthly Peak Demand (MW)

AND ENERGY REQUIREMENTS Month 1972 1973 Change (/) 1974 Change (/o) 1975 Change (/) 1976 Change (/) 1977 Change (/) 1978 Change (/) Sheet 2 of 7 Jan 944 1052 11.4 1099 4.5 1264 15.0 1304 3.2 1397 7.1 1531 9.6 Feb 928 1037 11.7 1068 3.0 1147 7.4 1295 12.9 1361 5.1 1490 9.5 Mar 1002 1028 2.6 1149 11.8 1174 2.2 1354 15. 3 1373 1.4 1370 0.2 Apr 1053 1211 15.0 1302 7.5 1144 -12.1 1449 26.7 1651 13.9 1533 -7.1 May 1301 1554 19.4 1601 3.0 1563 -2.4 1758 12.5 1955 11.2 2020 3.3 Jun 1514 1786 18.0 2032 13.8 1790 -11.9 2114 18.1 2286 8.1 2356 3.1 Jul 1633 1809 10.8 1936 7.0 2008 3.7 2191 9.1 2346 7.1 2549 8.7 Aug 1659 1813 9.3 1873 3.3 2068 10.4 2121 2.6 2373 11.9 2373 -0.4 Sep 1549 1728 11.6 2008 16.2 1903 -5.2 2070 8.9 2372 14.6 2359 -0.5 Oct 1283 1432 11.6 1683 17.5 1646 2.2 1466 -10.9 1775 21.1 2015 13.5 Nov 963 1127 17.0 1112 1.3 1244 11.9 1399 12.5 1360 -2.8 1480 8.8 Dec 1087 1065 -2.0 1236 16.1 1232 -0.3 1354 9.9 1430 5.6 1726 20.7 Monthly Energy Requirements (GWh)

Month 1972 1973 Change (/) 1974 Change (/) 1975 Change (/o) 1976 Change (/) 1977 Change (/) 1978 Change (/)

Jan 499.9 572. 9 14.6 584.4 2.0 680.8 16.5 697. 7 2.5 753.9 8.1 776.1 2.9 Feb 477.4 496.0 3.9 536.9 8.2 596.2 11.0 632.9 6.2 680.8 7.6 687.7 1.0 Mar 521.1 559.1 7.3 604.5 8.1 651.8 7.8 710.1 8.9 773.4 8.9 740.4 -4. 3 Apr 502.0 546.6 8.9 602.5 10.2 619.9 2.9 673.4 8.6 766.0 13.8 745.6 2.7 May 595.7 692.7 16.3 714.0 3.1 700.4 -1.9 792.1 13.1 791.4 -0.1 881.8 11.4 Jun 692.4 797.2 15.1 919.6 15.4 798.9 -13.1 925.6 15.9 1051.7 13.6 1099.0 4.5 Jul 829.4 910.4 9.8 951.3 4.5 985.0 3.5 1063.9 8.0 1184.3 11.3 1250.3 5.6 Aug 786.2 944.0 20.1 949.6 0.6 983.3 3.5 1068.4 8.7 1215.5 13.8 1189.4 -2.1 Sep 679.8 752.7 10.7 856.5 13.8 867.5 1.3 882.1 1.7 995.7 12.9 1035.2 4.0 Oct 549.8 667.7 21.4 713.5 6.9 701.9 1.6 728.5 3.8 796.6 9.3 873.6 9.7 Nov 498.5 579.0 16.1 585.7 1.2 630.9 7.7 680.6 7.9 718.4 5.6 764.0 6.3 Dec 566.9 581.4 2.6 673.8 15.9 676.0 0.3 751.4 11.2 754.1 0.4 869.5 15.3 PRC APERTURE CARD 1.1-153/154 Blank

PVNGS ER OL NEED FOR POWER LOS ANGELES DEPARTMENT OF WATER AND POWER Table 1.1-7 Monthly Peak Demand (MW)

COMPARISON OF MONTHLY PEAK DEMANDS Month 1972 1973 Change (%) 1974 Change (%) 1975 Change (%) 1976 Change (%) 1977 Change (%) 1978 Change AND ENERGY REQUIREMENTS

(%)

Jan 2899 3097 6.8 2586 -16. 5 2755 6.5 2790 1.3 2961 6.1 2998 1.2 Sheet 3 of 7 Feb 2799 2914 4.1 2356 -19.1 2658 12.8 2806 5.6 2798 -0. 3 2910 4.0 Mar 2800 2968 6.0 2381 -19.8 2634 10.6 2758 4,7 2707 -1. 8 2826 4.4 Apr 2776 2823 1.7 2543 10.2 2636 3.6 2783 5.6 2677 -3. 8 2767 3.4 May 3215 3165 -1.6 2539 -19.8 2826 11.3 3264 15.5 2974 -8.9 3398 14. 2 Jun 3249 3679 13.2 3292 -10.5 2930 -11.0 3809 30.0 3189 -16.3 3680 15.4 Jul 3630 3561 1.9 3500 -1.7 3466 -0.8 3634 4.8 3778 4.0 3912 3.5 Aug 3565 3492 -2.0 3259 -6.7 3531 8.3 3744 6.0 3700 -1.2 3814 3.1 Sep 3294 3293 0 3304 0.3 3594 8.8 3597 0.1 3769 4.8 4144 9.9 Oct 3155 3141 -0.4 3095 -1.5 3231 4.4 3232 0 3012 -6.8 3422 13.6 Nov 3021 3014 -0.2 2681 -11.0 2781 3.7 3168 13. 9 3064 -3,3 2949 -3.8 Dec 3174 2827 -10.9 2727 -3.5 2903 6.4 2928 0.9 3000 2.4 3044 1.5 Monthly Energy Requirements (GWh)

Month 1972 1973 Change (%) 1974 Change (%) 1975 Change (%) 1976 Change (%) 1977 Change (%) 1978 Change (%)

Jan 1530 1621 5.9 1343 17.1 1438 7.1 1531 6.5 1549 1. 2 1574 1.6 Feb 1413 1439 1.8 1189 -17.4 1302 9.5 1424 9.3 1363 -4.3 1422 4.3 Mar 1532 1590 3.8 1323 16.8 1429 8.0 1526 6.8 1534 0.5 1554 1.3 Apr 1449 1483 2.3 1281 -13.6 1407 9.8 1470 4.5 1438 -2.2 1499 4.2 May 1562 1562 0 1355 -13.2 1442 6.4 1532 6.2 1469 -4.1 1624 10.6 Jun 1592 1642 3.1 1442 -12.2 1429 -0.9 1643 15.0 1527 -7.1 10.9 Ju 1 1723 1696 -l. 6 1622 -4.4 1611 0.7 1714 6.4 1687 -l. 6 1693 1784 5.7 Aug 1757 1734 -1.3 1554 10.4 1563 0.6 1680 7.5 1761 4.8 1764 0.2 Sep 1559 1540 -1.2 1506 -2.2 1555 3.2 1617 4.0 1567 -3.1 1735 10.7 Oct 1552 1624 4.6 1457 10.3 1519 4.2 1609 5.9 1556 -3.3 1681 8.0 Nov 1519 1521 0.1 1348 -11.5 1429 6.0 1500 5.0 1486 0.9 1534 3.2 Dec 1612 1427 -11.5 1424 0.2 1528 7.3 1554 1.8 1560 0.4 1598 2.4 PRC PARTURE CARD 1.1-155/156 Blank

PVNGS ER-OL NEED FOR POWER EL PASO Table 1.1-7 Monthly Peak Demand (MW)

COMPARISON OF MONTHLY PEAK DEMANDS Month 1972 1973 Change (8) 1974 Change (%) 1975 Change (%) 1976 Change (%) 1977 Change (%) 1978 Change (%) AND ENERGY REQUIREMENTS Jan 426 462 8.5 457 (1.1) 492 7.7 495 .6 486 (1.9) 513 5.6 Sheet 4 of 7 Feb 418 471 12.7 448 (5.1) 466 4.0 489 4.9 473 (3-4) 492 4.0 Mar 417 455 9.1 438 (3-9) 471 7.5 486 3.2 468 (3. 8) 510 9. 0-Apr 431 458 6.3 504 10.1 480 (5. 0) 520 8.3 497 (4.6) 546 9.9 May 466 526 12.9 587 11.6 550 (6.7) 590 7.3, 601 1.9 614 2.2 Jun 513 618 20.5 638 5.1 630 (1. 3) 677 7.5 655 (3. 3) 688 5;0 Jul 538 607 12.9 635 4.6 635 0 637 .3 636 ( -2) 690 8.5 Aug 543 586 7.9 629 7.3 640 1.8 666 4.1 657 (1.4) 651 ( -9) -'

Sep 501 585 16.8 600 2.6 615 2.5 595 (3-3) 622 4.5 617 -8);

Oct 498 525 5.4 518 (1.4) 520 . 4- 504 (3-2) 527 4.6 527 0 Nov 447 485 8.5 478 (1.5) 490 2.5 537 9.6 490 (9-6) 509 3.9 Dec 472 466 (1. 3) 505 8.4 506 .-2 529 4.5 502 (5-4) 549 9.4 Monthly Energy Requirements (GWh)

Month 1972 1973 Change (8) 1974 Change (%) 1975 Change (%) 1976 Change (%) 1977 Change (0) 1978 Change (%)

Jan 226. 4 257. 5 13.7 258.5 .4 278. 0 7.5 281.8 1.4 273. 0 (3.2) 278.3 1.9 Feb 215.5 233.0 8.1 231.9 ( -5) 242. 5 4.6 -259. 6 7.1 241.0 (7-7) 250. 0 3.7 Mar 229.4 253.2 12.4 246.6 (2.7) 259. 5 5.2 276.4 6.5 269.0 (2-8) 274.0 1.9 Apr 225.2 247.7 10 251.4 1.5 258. 0 2.6 273.8 6. l. 262.0 (4.5) 275.0 5.0 May 245.6 271.0 10.3 295.1 8.9 280. 1 (5-4) 295.6 5.5 289.0 (2-3) 305.0 5.5 Jun 259. 6 297.6 14.6 324.5 9.4 321.9 ( .8) 340.0 5.6 330.0 (2-9) 349.0 5.8 Jul 288.2 316.4 9.8 323.5 2.2 336.6 4.1 341.5'59.3 1.5 329.0 , (3.7) 369.0 Aug 282.0 322-7 14.4 321.6 ( -3) 344.8 7.2 4.2 353.0 (1.8) 345.0 (2.3) .,

4.8 298.1 320.0 7.4 290.0 (9.4):

Sep Oct 251.6 252.7 239.

296.5 273.7 257.6 17.9 8.3 7.7 285.5 274.3 259.0 (3.7)

.2

.5 299.2 281.6 264.1 2.7 2.0 277.0 271.7

( -4)

(1;7) 2.9 274.0 262.0

'l.l)

(3.7) 286.0 269.0 4.4 2.7 Nov 2 Dec 248. 0 255.9 3.2 278.4 8.8 278.4 0 277.8 ( -2) 271.0 (2.5) 291.0 7.4 PR(;

APERTURE CAR'0 ...-

l. 1-157/158 Blank

lii Il lI II V t.C G~

PVNGS ER-OL NEED FOR POWER PUBLIC SERVICE COMPANY OF NEW MEXICO Table 1.1-7 Monthly Peak Demand (MW)

COMPARISON OF MONTHLY PEAK DEMANDS Month 1972 1973 Change (%) 1974 Change (0) 1975 Change (%) 1976 Change (%) 1977 Change (0) 1978 Change (%) AND ENERGY REQUIREMENTS Jan 438. 0 461.5 5.4 463 0.3 520 12. 3 529 1.7 605 14. 4 666 10. 1 Sheet 5 of 7 Feb 417.2 465.8 11.6 452 -3.0 500 10. 6 527 5.4 607 15.2 649 6.9 Mar 403.2 436.2 8.2 423 -3.0 455 7.6 525 15.4 575 9.5 602 4.7 Apr 405.0 428.7 5.9 437 1.9 460 5.3 499 8.5 564 13.0 600 6.4 May 422.4 424.0 0.4 502 18.4 483 -3.8 543 12.4 646 19.0 641 -0.8 Jun 467.4 528.0 13.0 583.4 10.5 566 -3.0 624 10.2 687 10.1 787 14.6 Jul 491.7 533.0 8.4 564 5.8 579 2.7 633 9.3 694 9.6 809 16.6 Aug 489.5 510.0 4.2 548 7.5 586 6.9 627 7.0 715 14.0 787 10.1 Sep 434.4 479. 0 10.3 548 14.4 582 6.2 581 0.2 664 14.3 742 11.7 Oct 441.0 442. 0 0 7 476 7.7 489 2.7 538 10.0 595 10 6 688 15.6 Nov 460. 9 464.0 0.7 480 3.4 537 11.9 608 13.2 620 2.0 705 13.7 Dec 475.4 481.0 1.2 508 5.6 547 7.7 632 15.5 648 2.5 741 14.4 Monthly Energy Requirements (GWh)

Month 1972 1973 Change (%) 1974 Change (%) 1975 Change (%) 1976 Change (%) 1977 Change (%) 1978 Change (%)

Jan 222.5 251.5 13. D 251.0 -0.2 297. 9 18.7 293. 9 1.3 369.0 25.6 408.1 10 6 Feb 207.6 218.7 5.3 226.5 3.6 264.3 16.7 277.9 5.1 328.6 18.2 350.8 6.8 Mar 221.9 240.1 8.2 237.5 -1.1 285.4 20.2 307.3 7.7 399.2 29.9 352.7 -11 6 Apr 210.6 227.9 8.2 230.8 1.3 262.6 13.8 285.4 8.7 375.0 31.4 354.0 5.6 May 229.0 244.6 6.8 258.1 5.5 266.9 3.4 307.0 15.0 397.2 29.4 374.8 -5.6 Jun 236.1 248.0 5.D 288.5 16.3 307.0 6.4 332.6 8.3 396.1 '9.1 411.1 3.8 Jul 251.6 271.6 7.9 292.4 7.7 328.0 12.2 353.5 7.8 402.1 13.7 469.0 16.6 Aug 250.0 275.0 10. 9 284.2 3.3 354.0 24.6 349.6 1.2 414.8 8.6 445.4 7.4 Sep 226.5 241.1 6.k 259.7 7.7 273.8 5.4 316.2 15.5 362.3 4.6 394.2 8.8 Oct 231.5 224.4 -3.1 255.4 13.8 299.0 17.1 325.7 8.9 354.0 8.7 401.0 13.3 Nov 235.6 232.6 -l. 3 252.4 8.5 271.5 7.6 335.4 23.5 343.5 2.4 403.2 17.4 Dec 248.1 237.8 -4. 2 276.5 16.3 310.1 12.2 379.4 22.3 376.5 -0.8 438.2 16.4 PRC APERTURE

",, CARD 1.1-159/160 Blank

PVNGS ER-OL NEED FOR POWER SALT RIVER PROJECT SYSTEM REQUIREMENTS AT SOURCE (Excludes Interruptible)

Table 1.1-7 Monthly Peak Demand (MW)

COMPARISON OF MONTHLY PEAK DEMANDS Month 1972 1973 Change (I) 1974 Change (%) 1975 Change (%) 1976 Change (%) 1977 Change (%) 1978 Change (8) AND ENERGY REQUIREMENTS Jan 778 830 7 908 9 1058 17 1045 -1 1213 16 1207 -1 Sheet 6 of 7 Feb 763 787 3 909 16 993 9 904 -10 1066 18 1115 5 Mar 809 812 0 852 5 955 12 1075 13 1104 3 971 -14 Apr 839 940 12 975 4 931 -5 1081 16 1244 15 1032 -21 May 1040 1271 22 1366 7 1300 -5 1436 10 1514 5 1510 0 Jun 1253 1448 1645 1460 -13 1685 15. 1681 Jul Aug 1360 1357 1446 1435 16 6

6 1595 1510 14 10 5

1598 1634 0

8 1732 1668 8

2 1675 1683 0

-3 0

1747 1854 1728 ll4 3

Sep 1251 1378 10 1602 16 1511 -6 1579 5 1731 10 1729 0 Oct 1004 1086 8 1306 20 1242 -5 1090 -14 1366 25 1503 10 Nov 740 838 13 872 921 1066 952 -12 Dec 901 842 -7 1012 4

20 995 -2 6

1102 ll 16 1089 -1 1108 1469 16 35 Monthly Energy Requirements (GWh)

Month 1972 1973 Change (%) 1974 Change (%) 1975 Change (%) 1976 Change (%) 1977 Change (%) 1978 Change (%)

Jan 428 469 10 495 6 605 22 572 -6 612 7 599 -2 Feb 401 395 -2 456 15 523 15 497 -5 533 534 0 Mar 440 449 2 494 10 545 10 570 5 613 7

8 553 -ll

-6 Apr 429 434 503 16 532 537 588 10 553 May Jun 506 604 570 662 1

13 10 634 796 ll 20 612 702

-4

-13 6

657 770 10 0

7 612 823

-7 7

672 855 lo 4

Jul 716 762 6 818 7 840 3 893 6 884 -1 952 8 Aug 669 775 16 807 4 840 4 874 4 914 5 941 3 Sep 585 629 8 738 17 725 2 723 0 771 7 814 6 Oct 441 508 15 583 15 553 -5 564 2 622 10 678 9 Nov 408 450 10 482 526 577 Dec 468 484 3 583 7

20 494 545 -7 2 530 603 ll7 580 -4 0

692 10 19 P R G APERTURE CARD 1.1-161/162 Blank

V I

%1

/'I P

PVNGS ER-OL NEED FOR POWER SALT RIVER PROJECT SYSTEM REQUIREMENTS AT SOURCE (Excludes Interruptible)

Table 1.1-7 Monthly Peak Demand (MW)

COMPARISON OF MONTHLY PEAK DEMANDS Month 1972 1973 Change (%) 1974 Change (0) 1975 Change (%) 1976 Change (%) 1977 Change (8) 1978 Change (8) AND ENERGY REQUIREMENTS Jan 778 830 7 908 9 1058 17 1045 -1 1213 16 1207 -1 ,Sheet 6 of 7 Feb 763 787 3 909 16 993 9 904 -10 1066 18 1115 5 Mar 809 812 0 852 5 955 12 1075 13 1104 3 971 -14 Apr 839 940 12 975 4 931 -5 1081 16 1244 15 1032 -21 May 1040 1271 22 1366 7 1300 -5 1436 10 1514 5 1510 0 Jun 1253 1448 16 1645 14 1460 -13 1685 15 1681 0 1747 4 Jul 1360 1446 6 1595 10 1598 0 1732 8 1675 -3 1854 11 Aug 1357 1435 6 1510 5 1634 8 1668 2 1683 0 1728 03 Sep 1251 1378 10 1602 16 1511 -6 1579 5 1731 10 1729 0 Oct 1004 1086 8 1306 20 1242 -5 1090 -14 1366 25 1503 10 Nov 740 838 13 872 921 1066 952 -12 1108 16 Dec 901 842 -7 1012 20 995 -2 6

1102 ll 16 1089 -1 1469 35 Monthly Energy Requirements (GWh)

Month 1972 1973 Change (%) 1974 Change (8) 1975 Change (8) 1976 Change (%) 1977 Change. (%) 1978 Change (8)

Jan 428 469 10 495 6 605 22 572 -6 612 7 599 -2 Feb 401 '395 -2 456 15 523 15 497 -5 533 534 0 Mar 440 449 2 494 lo 545 10 570 5 613 7

8 553 -ll

-6 Apr 429 434 1 503 16 532 6 537 0 588 10 553 May 506 570 13 634 11 612 -4 657 7 612 -7 672 10 Jun 604 662 10 796 20 702 -13 770 10 823 7 855 4 Jul 716 762 6 818 7 840 3 893 6 884 -1 952 8 Aug 669 775 16 807 4 840 4 874 4 914 5 941 3 Sep 585 629 8 738 17 725 2 723 0 771 7 814 6 Oct 441 508 15 583 15 553 -5 564 2 622 10 678 9 Nov 408 450 530 526 Dec 468 484 10 3

482 583 20 7 494 545 -7 2

603 ll7 580 -4 0 577 692 ..

10 19 PR(

APE-R TURp CAqg

1. 1-161/162 Blank

I j,'

1 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 of 8)

ARIZONA PUBLIC SERVICE Range of Capacity Power Plant and Unit Type Function Factors (%)

Four Corners 1 Steam Base 59-72 Four Corners 2 Steam Base 57-74 Four Corners 3 Stea'm Base 59-72 Cholla 1 Steam Base 61-75 Ocotillo 1 Steam Intermediate 15-27 Ocotillo 2 Steam Intermediate 15-27 Saguaro 1 ,Steam Intermediate 5-16 Saguaro 2 , Steam Intermediate 5-16 Yucca 1 Steam Intermediate 34-47 Four Corners 4 S tealll Base 40-69(,)

Four Corners 5 Steam Base 43-69(')

Navajo 1 Steam Base 58 78 c Navajo 2 Steam Base 58-78 c')

Navajo 3 Steam Base 58-79 West, Phoenix CC 1 ,Comb. Cycle Intermediate 2-13 West Phoenix CC 2 Comb. Cycle Intermediate 2-13 West. Phoenix CC 3 Comb. Cycle Intermediate 2-13 Cholla 2 Steam Base 62-78 Cholla 3 Steam Base 68-81 Cholla 4 Steam Base 63-74(')

Palo Verde 1 Steam Base 58-84( )

Palo Verde 2 Steam Base 58-84( )

Palo Verde 3 Steam Base 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)

Range of Capacity Power Plant and Unit Type Function Factors (%)

Hydro Base Owens Valley Hydro Base 52 Aqueduct Hydro Base 83 Harbor 1 Steam Intermediate 0 Harbor 2 Steam Intermediate 0 Harbor 3 Steam Intermediate 1 Harbor 4 Steam Intermediate 1-2 Harbor 5 Steam Intermediate 0-1 Valley 1 Steam Intermediate 1-6 Valley 2 Steam Intermediate 1-6 Valley 3 Steam Intermediate 5-14 Valley 4 Steam Intermediate 11-24 Scattergood 1 Steam Base 25-50 Scattergood 2 Steam Base 34-59 Scattergood 3 Steam Base 26-81 Haynes 1 Steam Base 37-68 Haynes 2 Steam Base 39-74 Haynes 3 Steam Base 54-68 Haynes 4 Steam Base 49-69 Haynes 5 Steam Base 55-79 Haynes 6 Steam Base 56-77 Mohave 1 Steam Base 42-65( )

Mohave 2 Steam Base 38-65(c)

Navajo 1 Steam Base 58-78( )

Navajo 2 Steam Base 58-78( )

Navajo 3 Steam Base 55-79 Coronado 1 Steam Base 71-81 Coronado 2 Steam Base 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)

Range of Capacity Power Plant and Unit Type Function Factors (%)

Intermountain 1 Steam Base 62-67 Intermountain 2 Steam Base 59-68 Intermountain 3 Steam Base 58-67 Intermountain 4 Steam Base 58-69 Palo Verde 1 Steam 'ase 58-84 Palo Verde 2 Steam Base 5S-S4 Palo Verde 3 Steam Base '8-84(')

il 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 Range of Capacity Power Plant and Unit Type Function Factors (%)

Rio Grande Steam Base 33 Newman 1 Steam Base 36 Newman 2 Steam Base 46 Newman 3 Steam Base 60 Newman 4 Steam Base 62 Four Corners 4 Steam Base 40-69 (c)

Four Corners 5 Steam Base ~ 43-69 ( )

Palo Verde '1 Steam Base 5S-S4 Palo Verde 2 Steam Base 5S-S4(')

Palo Verde 3 Steam Base 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 Range of Capacity Power Plant and Unit Type Function Factors (%)

Person 1 Steam Peaking (a)

Person 2 Steam Peaking (a)

Person 3 Steam Intermediate 13-22 Person 4 Steam Intermediate 20-30 Reeves 1 Steam Base 20-48 Reeves 2 Steam Base 29-49 Reeves 3 Steam , Base 32-52 Four Corners 4 Steam I Base 40-69(')

Four Corners 5 Steam I Base 43-69 I

San Juan 1 Steam I Base 62-74 San Juan 2 Steam i Base 56-73 San Juan 3 Steam Base 64-74 San Juan 4 Steam Base 61-7,5 Palo Verde 1 Steam Base 58 84(c)

Palo Verde 2 Steam Base 58-84 (c))

Palo Verde 3 Steam Base 58-84 (

Pumped Hydro Intermediate (b)

Storage 1 S 2 New Mexico Steam Base (b)

Station 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 Range of Capacity Power Plant, and Unit Type Function Factors (%)

Agua Fria 1 Steam Intermediate 6-25 Agua Fria 2 Steam Intermediate 4-17 Agua Fria 3 Steam Intermediate 20-38 Kyrene 1 Steam Intermediate 0-2 Kyrene 2 Steam Intermediate 2-6 Four Corners 4 Steam Base 40-69 <<)

Four Corners 5 Steam Base 43-69 (c)

Mohave 1 Steam Base 42-65( )

Mohave 2 Steam Base 38-65(c)

Navajo 1 Steam Base 58-78 (c)

Santan 1 Comb. Cycle Intermediate 1-5 Santan 2 Comb. Cycle Intermediate 1-5 Santan 3 Comb. Cycle Intermediate 1-5 Santan 4 Comb. Cycle Intermediate 1-5 Navajo 2 Steam Base 58-78 Hayden 2 Steam Base 75-86 Navajo 3 Steam Base 55-79 Craig 1 Steam Base 67-78 Coronado 1 Steam Intermediate 39>>58 Craig 2 Steam Base 66-78 Coronado 2 Steam Intermediate 38-58 Palo Verde 1 Steam Base 58-84( )

Palo Verde 2 Steam Base 58-84 Palo Verde 3 Steam Base 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)

Range of Capacity Power Plant and Unit Type Function Factors {%)

Southern Hydro Hydro Int/Base 62-69 Bishop Hydro Hydro Int/Base 49-56 Northern Hydro Hydro Int/Base 58<<73 Redondo 1-4 Steam Intermediate 8-28 Redondo 5,6 Steam Intermediate 3-38 Highgrove 1-4 Steam Intermediate 43-64

~ t Etiwanda 1,2 Steam Intermediate 8-28 Etiwanda 3,4 Steam Intermediate 38-.62 El Segundo 1,2 Steam Intermediate 3-38 El Segundo 3,4 Steam Intermediate 38-62 Alamitos 1,2 Steam Intermediate 3-38 Alamitos 3,4 Steam Intermediate 38-62 Alamitos 5,6 Steam Intermediate 43-64 San Bernardino 1,2 Steam Intermediate 8-28 Huntington Beach 1,4 Steam Intermediate 21-50 Mandalay 1,2 Steam Intermediate 21-50 Cool Water 1,2 Steam Intermediate 8-28 Garden State Comb. Turb. Intermediate N/A San Onofre 1 Nuclear Base 65-75 Long Beach 10 Steam Intermediate 8-28 Long Beach ll Steam Intermediate 8-28 Four Corners 4 Steam Base 40-69 )

Four Corners 5 Steam Base 43-69 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)

Range of Capacity Power Plant and Unit Type Function Factors (%)

Mohave 1 Steam Base 42>>65 Mohave 2 Steam Base 38-65 Ormond Beach 1 St.earn Intermediate 39-57 Ormond Beach 2 Steam Intermediate 39<<57 Long Beach 1-9 Comb. Cycle Intermediate 34 Cool Water 3,4 Comb. Cycle Intermediate 25-45 Co-Generation Co-Gen. Base N/A'0-70 San Onofre 2 Nuclear Base San Onofre 3 Nuclear Base 60-70 Axis Steam Steam Intermediate N/A Palo Verde 1 Nuclear Base 5s-s4( )

Palo Verde 2 Nuclear Base 5s-s4(')

Palo Verde 3 Nuclear Base 58-84 Geothermal 1-4 Geothermal Base 75 Combined Cycle Comb. Cycle Intermediate California Coal 1 Steam Base California Coal 2 Steam Base Combustion Turbines Comb. Turb., Peaking 1<<3 Supplement 1 1.1-190H September 1980

PNVGS ER-OL NEED FOR POWER Table l.l-ll COMPARISON OF PARTICIPANTS GENERATING CAPACITY, LOAD, AND ENERGY GENERATION (Sheet 1 of 6)

ARIZONA PUBLIC SERVICE Total 'otal Resources Projected Load Inter-Minus Minus ruptible Energy Firm Purchases Firm Purchases Load Generation Year (MW) (MW) (MW) (GWH) 1981 3412 2715 12656 1982 3311 2860 13754 1983 3573 2962 14304 1984 3808 3068 14985 1985 3816 3182 13 15670 1986 3923 16087 1987 4163 3474 17 17331 1988 4368 3676 27 18601 1989 4610 3847 30 19511 1990 4850 4011 30 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 Generating Peak Energy Capacity Demand Generation Year (MW) (MW) (GWH) 1981 5684 4220 14317 1982 5684 4351 14932 1983 5971 4223 16068 1984 5974 4292 16486 1985 6051 4382 16488 1986 6019 4453 16576 1987 6231 4536 16811 1988 6485 4636 17148 1989 6632 4737 17383 1990 6988 4862 17723 Supplement 3 1.1-224 July 198l

PNVGS ER-OL NEED FOR POWER Table l.l-ll I I I I I COMPAR SON OF PART C PANTS GENERAT NG CAPAC TY g LOAD, AND ENERGY GENERATION..(Sheet 3. of 6)

EL PASO ELECTRIC Generating Peak Energy Capacity Demand- Generation Year (MW) (MW) (GWH) 1981 895 742 4139 1982 920 776 4217 1983 1095 809 4346 1984 1289 847 4566

, 1985 1283 892 4804 1986 1477 936 5053 1987 1502 983 5313 1988 1502 1030 5591 1989 1484 1085 5884 1990 1468 1141 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 Generating Peak . Energy Capacity ', , Demand Generation Year (MW) (MW) (GWH) 1981 1235 997 6563 1982 1273 1061 8015 1983 1342 1086 9126 1984 1331 1109 9961 1985 1465 1187 10127 1986 1560 1257 10295 1987 1665 1344 10424 1988 1441 10362

'785

,1989 1855 1518 10240 1990 2068 1599 10475 C

Supplement 3 1.1-226 July 1981

PNVGS ER-OL NEED FOR POWER Table 1.1-11 COMPARISON OF PARTICIPANTS GENERATING CAPACITY, LOAD, AND ENERGY GENERATION (Sheet 5 of 6)

SALT RIVER. PROJECT Generating Peak Energy Capacity Demand, Generation Year (MW) (MW) (GWH) 1981 3300 2263 10368 1982 3221 2360 11579 1983 3576 2462 12510 1984 3932 2605 13243 1985 3869 2703, 13572 1986 4179 2822 13782 1987 4179 2905 14080 1988 4179 3015 14399 1989 4179 3121 14744 1990 4179 3225 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 Generating Peak Energy Capacity Demand Generation Year (MW) ~

(MW) (GWH) 1981 15471 13274 62970 1982 16184 13647 64300 1983 17446 13895 66980 1984 17837 14305 68590 1985 17535 14735 70380 1986 17889 15185 72210 1987 18491 15635 74290 1988 18941 16125 '6440 1989 19582 16599 78720 1990 20232 17129 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 Pro ected 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)... 1826 1948 2055 2163 2270 2359 2443 2516 2588 2658 2721 Peak Load (MW).............. 407.5 428.0 449.8 472.9 495.6 515.3 532.2 547.4 562 2 576.4 589.9 Resources:

San Onofre Units ¹2 & ¹3 34.8 69.5 69.5 69.5 69.5 69.5 69.5 69.5 69.5 IPP Units ¹1 - ¹4....... 76.7 153.4 230.1 306.8 306.8 SCPPA-Palo Verde Units ¹1 - ¹3...--..-- 5.6 11.3 11.3 16.9 16.9 16.9 16.9 16.9 Purchases. 407.5 428.0 422.3 413.5 431.8 451.5 406.2 363.5 320.4 276.8 290.3 .

Total. ~ ~ ~ ~ 407.5 428.0 457.1 488.6 512.6 532.3 569.3 603.3 636.9 670.0 683.5 Margin for Reserves/Losses.. 7.3 15.7 17.0 17.0 37.1 55.9 74.7 93.6 93.6 Margin.............. 1.6 3.3 . 3.4 3 ' 7.0 10.2 13.3 16.2 15.9 'ercent 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 Pro ected 1 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)... 166.0 183.8 190.0 196.1 202.4 208.6 215.7 223.1 230.7 238.5 246.6 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 Peak Resources:

SCPPA:

l Palo Verde.............. .8'.5 1.5 2.3 2.3 2.3 2.3 2.~ 3 o SCE Purchases (2).... ...

~ ~ 39.0 42.4 43.8 44.6 45.5 46.9 48.0 49.7 51.4 53.2 55.1 Total Resources (MW)........ 39.0 42.4 43.8 45.4 47.0 48.4 50.3 52.0 53.7 55.5 57.4 Margin for Reserves/Losses.. 0 0.2 0.3 0.3 0.5 0.5 0.5 0.5 0.5 Percent Margin.............. 0 0.4 0.6 0.6 1.0 1.0 0.9 0.9 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 Pro'ected 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)... 65.6 68.5 70.3 70.4 74. 7 76.6 78.7 80.7 82.9 85.0 87.1 Peak Load (MW).............. 18.1 16.9 17.4 18.0 18.5 19.1 19.6 20.2 20.7 21.3 21.9 Peak Resources:

SCPPA:

I tV Palo Verde........'...... .8 1.5 1.5 2.3 2.3 2.3 2.3 2.3 3 4)

SCE Purchases (1)......... 18.1 16.9 17.4 17.4 17.3 17.9 17.8 18.4 18.9 19.5 20.1 Total Resources (MW)........ 18.1 16.9 17.4 18.2 18.8 19.4 20.1 20.7 21.2 21.8 22.4 Margin for Reserves~osses 0.2 0.3 0.3 0.5 0.5 0.5 0.5 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 Pro ected 1 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Reguirenents (GWh)... 875 901 928 956 985 1014 1040 1066 1092 1120 1148 Peak Load (ÃW).............. 203 209 215 222 228 235 241 247 253 259 266 Resources:

On-Site:

Nagnolia Unit 03.. . ..~ ~ ~ 20 20 20 20 Magnolia Unit 84........ 28 28 28 28 28 28 28 28 Olive Unit 81........ - ~ ~ 42 42 42 42 42 42 42 42 42 42 42 Olive Unit <<2... ~ ~ ~ ~ ~ ~ ~ ~ 58 58 58 58 58 58 58 58 58 58 58

)(agnolia Unit 85" . . ~ ~ 22 22 22 22 22 22 22 22 22 22 22 Olive Unit 83...........

~ ~

19 19 19 19 19 19 19 19 19 '19 19 Olive Unit 84........... 33 33 33 33 33 33 33 33 33 33 33 Subtotal.............. 222 222 222 222 202 202 202 202 174 174 174 Off-Site:

5.1 S.l 5.1 5.1 5.1 5.1 5.1 5.1 5.1 5.1 5.1 BPA. 42.0 42.0 42.0 42.0 42.0 42.0 42.0 42.0 42.0 42.0 42. 0 Subtotal...... 47.1 47.1 47 ' 47.1 47.1 47.1 47.1 47.1 47.1 47 ' 47.1 Projects:

)nteaaountain Coal...... 12.8 25.6 38. 3 51,1 SCPPA-Palo Verde........ 3.0 6.0 6.0 9.0 9.0 9.0 9.0 9.0 White Pine Coal......... 9.7 AEPCO Coal.............. 25.0 25.0 50.0 Subtotal............ 0 21.8 59.6 72.3 119.8 Total Resources (RW) 269 269 269 272 25S 255 258 271 281 293 341 Nargin for Reserves/Losses.. 66 60 54 50 27 20 17 24 28 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 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)... 113.5 120.3 127.8 135.5 143.2 151.4 159.2 166 ' 174.2 181 ' 187.7 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 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)........ 28.6 29.2 31.0 33. 1 35.1 37.1 39.2 41.0 42.8 44 ' 46.1 Margin for Reserves/Losses.. 0 0 0.2 0.3 0.3 0.5 0.5 0.5 0.5 0.5 Percent Margin.............. 0 0.6 0.9 0.8 1.3 "

1.2 1.2

~(1 L-oad Forecast prepared Case 13, 1esc:

(2) - Southern California Edison provides for reserves and losses.

5 txj 0

0

Table l.l-l2 SCPPA MEMBERS LOADS AND RESOURCES (Sheet, 6 of ll)

CITY OF GLENDALE ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)

Actual Pro ected (1) 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)... 774 789 818 841 865 890 915 940 967 994 1022 Peak Load (MW).............. 189 195 201 207 213 220 226 233 240 248 2/5 Resources: (2) '0 Grayson Power Plant No. 3. 21 21 21 21 21 21 21 21 0 0 Grayson Power Plant No. 4. 47 47 47 47 47 47 47 47 47 47 47 I Grayson Power Plant No. 5. 49 49 49 49 49 49 49 49 49 49 ,

49 Grayson Power Plant No. 6. 23 23 23 23 23 23 23 23 23 23 23 l Grayson Power Plant No. 7 ~ 30 30 30 30 30 30 30 30 30 30 30 M Grayson Power Plant No. 8. 98 98 98 98 98 98 98 98 98 98 98

4) Hoover (3)................ 18 18 18 18 18 18 18 18 18 18 18 BPA Peaking Exchange (4).. 50 50 50 50 50 50 50 50 50 50 50 Intermountain Power Proj .. 0 0 0 0 0 0 11 23 35 47 47 Excess IPP ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 0 0 0 0 0 0 3 6 9 12 12 Arizona Electric Power Cooperative Project..... 0 0 0 0 0 0 0 0 25 25

'9 50 White Pane................ 0 0 0 0 0 0 0 0 0 18 SCPPA-Palo Verde (5)...... 0 -'0 0 3 6 6 9 9 9 9 9 Total Resources (MW).... 336 336 336 339 342 342 359 374 393 417 451 Margin for Reserves/Losses.. 147 141 135 132 129 122 133 141 '53 169 196 Percent Margin.............. 78 72 67 64 61 55 59 61 64 68 77 5

=

~1 - Forecast prepared June 1, 19el. 0 (2) - Capacity reduced by transmission losses.

(3) - Hoover contract subject to renewal in 1987.

(4) - BPA contract subject to renewal in 1986. 0 m (5) - Does not include transmission losses.

Table l.l-l2 SCPPA MEMBERS LOADS AND RESOURCES (Sheet 7 of ll)

CITY OF PASADENA ELECTRIC UTXLXTY SYSTEM (CALENDAR YEAR)

Actual Pro'ected 1 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (GWh)... 844 982 1009 1030 1086 1126 1163 1202 1246 1292 1341 Peak Load (MW).............. 197 215 215 218 225 232 239 246 254 263 272 Resources:

Broadway Broadway 2 l.(2) 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 0

45 Broadway 3. 71 71 71 71 71 71 71 71 71 71 71 Glenarm 9. 45 45 45 0 0 0 0 0 0 0 0 Gas Turbine l...........

2...........

26 26 26 26 26 26 26 26 26 26 26 Gas Turbine Hoover Azusa.

ll 26 15 26 11 15 26 ll 15 ll 26 15 26 ll 15 ll 26 15 26 11 15 26 ll 15 26 ll 15 ll 26 15 26 11 15 BPA. 30 30 30 30 30 30 30 30 30 30 30 Intermountain Power Proj 23 46 70 94 White Pine. 8 Arizona Electric Power Cooperative Project... 23 23 IPP Excess Power........ .19 29 39 38 SCPPA-Palo Verde........ 8 8 8 8 Total 314 314 314 271 274 274 277 319 352 409 395 Margin for Reserves/Losses.. 117 99 99 53 49 42 38 73 98 146 123 Percent Margin.............. 59 46 46 24 22 16 30 39 56

~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 Pro ected 1980 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 Units ¹2 6 <<3.. 19.7 39.4 39.4 39.4 39.4 39.4 39.4 39.4 39.4 IPP Units ¹1 - <<4.... ~ . ~ ~ ~ 51.1 102.3 153.4 204.5 204.5 SCCPA-Palo Verde Units <<1 <<3 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3.8 7.5 7.5 11.3 11.3 11.3 11.3 11.3 Purchases. 312.8 315.0 309.5 296.0 302.2 315.2 284.5 257.9 233.1 210.6 229.6 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.. 4.2 9.2 10.1 10.1 23.3 35.9 48.2 60.8 60.8 Percent Margin.............. 1.3 2.7 2.9 2.9 6.4 9.6 12.4 15.0 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 Pro ected 1980 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 Resources:

I Diesel <<1. 5 5 5 5 5 5 5 5 I Diesel <<2 5 5 5 5 5 5 "5 5 I

M Diesel <<3 5 5 5 5 5 5 5 5

4) Diesel ¹4. 5 5 5 5 5 5 5 5 5 Diesel ¹5 5 5 5 5 5 5 5 5 5

~ ~ ~ ~ ~ ~ ~ ~ ~ ~

SCPPA-Palo Verde 1. 3 3 3 3 3' .- 3 3 SCPPA-Palo Verde 2. 4 4 4 4 4 4 4 SCPPA-Palo Verde 3 ~ 3 3 3 3 3 SCE<<Purchase (1)... ~ ~ ~ ~ ~ ~ 236 226 222 207 204 204 201 201 201 201 201 Total. 236 231 232 235 '36 236 - 236 236 236 236 236 Margin for Reserves/Losses.. 6 6 M

~1- Southern California Edison provides for reserves and losses.

C

d. a

'8 0 8

a ff' 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 Pro ected 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requireaents (ash)... 1439 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 ~ ~ ~ ~ ~ ~ ~ 20 20 20 20 20 20 20 20 20 20 20 Unit Unit 2........... 32 32 32 32 32 32 32 32 32 32 32 3~ ~ ~ ~ ~ ~ ~ ~ 48 48 48 48 48 48 48 4s 48 48 48 Unit 4 o ~ ~ ~ ~ 80 80 80 80 80 80 80 80 80 80 80 Subtotal.............. 180 180 180 180 180 180 180 180 180 180 180 Das Turbine:

Bradley C.T. 1... 9 9 9 9 9 9 9 9 9 9 9 Bra@lay C.T. 2... 9 9 9 9 9 9 9 9 9 9 9 Coachella C.T. l. ~ ~ ~ ~ ~ ~ 20 20 20 20 20 20 20 20 20 20 20 Coachella C.T. 2. ~ \ ~ ~ ~ 20 20 20 20 20 20 20 20 20 20 20 Coachella C.T. 3. ~ ~ ~ 0 ~ ~ 20 20 20 20 20 20 20 20 20 20 20 Coachella C.T. 4. ~ \ ~ ~ ~ ~ 20 20 20 20 20 20 20 20 20 20 20 RocJwood C.T. 1.. ~ ~ ~ ~ ~ ~ 25 25 25 25 25 25 25 25 25 25 25 Rockwood C.T. 2.. ~ ~ ~ ~ ~ 25 25 25 25 25 25 25 25 25 25 Unnaned C.T...... \ ~ ~ ~ ~ 50 50 50 50 50 50 50 50 Subtotal.............. 123 148 148 198 198 198 198 198 198 198 198 Diesel:

Bradley Bravley l..

2..

.75 .75

.75

.75 .75 .75 .75

.75

.75

.75

~ 75 .75

.75

.75

.75

.75

.75

.75 .75 .75 .75 75 Bradley 3.. ~ ~ ~ ~ ~ ~ \ .75 .75 .75 .75 .75 ~ 75 .75 75 ~ 75 .75 .75 Brasley 4.. ~ ~ ~ ~ ~ ~ 1.50 1.50 1.50 1.50 1.50 1.5D 1.5D 1 5D 1.50 1.50 1.50 Brasley 5.. 1. 50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1. 50 1 ~ 50 1.50 Bradley 6.. 1.5 1.5 1.5 1.5 1.5 1.5 1.5 1.5 1.5 1.5 1.5 Bradley 7.. 2.625 2.625 2.625 2.625 2.625 2.625 2.625 2.625 2.625 2.625 2.625 Bra@lay 8.. 2 625 2.625 2.625 2.625 2.625 2.625 2.625 2.625 2.625 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 IMPERIAL IRIGATION DISTRICT ELECTRIC UTILITY SYSTEM (Sheet ll of 11)

(CALENDAR YEAR)

Page 2 of 2 Actual Pro ected 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Nydro:

Drop No. 4 Unit 1....... 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 Drop No. 4 Unit 2....... 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 Drop Drop No. 3 No. 3 Unit Unit l.......

2.......

3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75

.7. 5 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 Drop No. 2 Unit 1....... 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 Drop No. 2 Unit 2....... 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 3.75 Pilot Knob Unit 1....... 9.0 9.0 9.0 9.0 9.0 9.0 9.0 9.0 9.0 9.0 9.0 Subtotal... 39 39 39 39 39 39 39 39 39 Geothernal:

Additions {1)... 12 15 18 Nucleary Palo Verde 1... 3.5 3.5 3.5 3.5 3.5 3.5 3.5 3.5 Palo Verde 2... 3.5 3.5 3.5 3.5 3.5 3.5 3.5 Palo Verde 3... 3.5 3.5 3.5 3.5 3.5 Subtotal..........

Other:

WAP-Parker-Davis.. 33 33 33 33 33 33 33 33 33 33 33 SCE-Axis Plant.... ~ 25 25 25 25 25 25 25 25 25 25 25 Purchases......... 40 40 40 40 40 100 100 100 250 250 261 Subtotal 98 98 98 98 98 158 158 158 308 308 319 Total... 452 477 477 531 534 597 604 607 760 763 777 Nargin for Reserves/Losses.. 86 56 70 115 102 85 217 198 190 Percent Nargin... 23 22 13 19 15 20 16 35 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 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (Gwh)a ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 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 ~ ~ ~ ~ ~ ~ ~ ~ 54.4 54.2 49.5 49.5 49.5 49.5 49.5 49.5 49.5 49.5 49.5 Gas Turbine ... 39.0 53.4 98.0 98.0 98.0 98.0 98.0 98.0 98.0 98.0 98.0 Proposed Small hydro( 0.5 6.0 19.4 30.8 32.8 32.8 32.8 32.8 32.8 Geothermal 82.5 82.5 82.5 82.5 82.5 Harry Allen ... 30.0 60.0 90.0 120.0 120.0 ANP P ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 41.7 83.4 83.4 125.0 125.0 125.0 125.0 125.0 Purchases........ 258.3 236.4 272 ' 248.1 218 2 224 6 152.0 151.0 149.0 148.0 144.0 4'ot a1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 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 ~ ~ ~ ~ '0 0 22.2 29.3 37.5 39 ' 104.8 115.8 123.8 132.8 107.8 Percent Margin.......... 0 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 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (Gwh) 1609 1754 1858 1959 2052 2142 2234 2326 2415 2516 2612 Peak Load (MW)....... 265.6 297 314 331 347 262 378 394 409 426 442 Resources  : (MW)

Thermal Geothermal, NCPA. 60.4 60.4 60.4 60.4 60.4 78.4 78.4 78.4 78.4 Gas Turbine - Cogen 5.8 5.8 5.8 45.8 45.8 45.8 45.8 45.8 45.8 45.8 Small Hydro Black Butte...... 6.8 6.8 6.8 6.8 6.8 6.8 Stony Gorge...... 3.9 3.9 3.9 3.9 3.9 3.9 Large Hydro Calaveras........ 62. 0 62.0 62.0 62.0 62.0 62.0 Purchases.......... 265.6 291.2 261.0 278.0 266.6 224.8 255.6 253.6 268.6 345.1 345.1 To'tal o ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 265.6 297.0 327.2 344.2 372.8 403.7 434.5 450.5 465.5 542.0 542.0 Margin for Reserve/

Losses................ 13.2 13.2 25.8 41.7 56.5 56.5 56.5 116.0 100.0 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 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 Energy Requirements (Gwh). ~ ~ ~ ~ ~ ~ ~ ~ ~ 444.6 481.4 511.2 536.8 562.4 587.9 609.2 630.5 651 ' 673.1 690.2 Peak Load (NW).......... 105 113 120 126 132 138 143 148 153 158 162 Resources: (MW)

Thermal ANP P ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 8.3 16.6 16.6 25.0 25.0 25.0 25.0 25.0 Harry Allen.... 5.0 10.0 15.0 20.0 20.0 Geothermal..... 16.5 16.5 16.5 16.5 16.5 Small Hydro Whiskeytown.... 4.0 4.0 4.0 4.0 4.0 4.0 4.0 Saeltzer....... 0.9 0.9 0.9 0.9 0.9 0.9 Lake Redding... 14.0 14.0 14.0 14.0 14.0 Lake Red Bluff. 14.0 14.0 14.0 14.0 14.0 North Fork..... 6.0 6.0 6.0 6.0 Cottonwood..... 9.0 Large Hydro Calaveras......

Losses' 18.8 18.8 18.8 .18.8 18.8 18.8 Purchases........ 105 113 120 117 115.4 115.4 115.4 115.4 115.4 115.4 115.4 Total............... 105 113 120 126 136.0 155.7 213.6 224.6 229.6 234.6 243.6 Margin for Reserve/

.o ~ ~ . . ~ ..... 4.0 17.7 70.6 76.6 76.6 76.6 81.6 Percent Margin.......... 3.0 12.8 49.4 51.8 50.1 48.5 50.4

100 90 LOAD FACTOR 60.3%

80 YEAR MAXIMUMLOAD 1987 31,336 MW 70 I988 32,414 MW 60 50 O

cL 40 30 20 10 500 1000 2000 3000 4000 5000 6000 7000 8000 9000 HOURS 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 YEAR MAXIMUMLOAD 1987 4,200 MW 70 1988 4,394 MW O

I- 50 Z

0 40 30 20 10 0

500 1000 4000 5000 6000 8000 9000 HOURS 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 YEAR MAXIMUMLOAD 1987 1,223 MW 70 1988 1,275 MW 60 W

o 50 I

z

a. 40 30 20 10 0

500 1000 2000 3000 4000 5000 6000 7000 8000 9000 HOURS Palo Verde Nuclear Generating Station ER-OL Bl Paso Electric 1987-88 Coincident Load Duration Curve t

Figure 1.1-3 I

C Wa pM f

90 LOAD FACTOR 57 4~

80 YEAR MAXIMUMLOAD 1987 5,077 MW 70 1988 5230 MW 60 O

I- 50 Z

IL 40 30 20 10 0

500 1000 2000 3000 4000 5000 6000 8000 9000 HOURS 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 1

4 1

100 90 LOAD FACTOR 70 2%%d 80 YEAR MAXIMUMLOAD 1987 1,701 MW 70 1988 1839 MW 60 50 O

4 40 30 20 10 0

500 1000 2000 3000 4000 5000 6000 7000 8000 9000 HOURS 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 YEAR MAXIMUMLOAD 1987 16,051 MW 70 1988 16515 MW 60 O

I 50 Z

40 30 20 10 0

500 1000 2000 3000 4000 5000 6000 7000 8000 9000 HOURS 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 YEAR MAXIMUMLOAD 1987 2870 MW 1988 3,049 MW 70 so o

I- so Z

40 30 20 10 500 1000 2000 3000 5000 6000 7000 8000 9000 fi HOURS Palo Verde Nuclear Generating Station ER-OL Salt River Project 1987-88 Coincident Load Duration Curve Figure 1.1-6

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PVNGS ER-OL NEED FOR POWER SOUTHERN CALIFORNIA EDISON Table 1.1-7 Monthly Peak Demand (MW) COMPARISON OF MONTHLY PEAK DEMANDS Month 1972 1973 Change (%) 1974 Change (%) 1975 Change (%) 1976 Change (%) 1977 Change (%) 1978 Change (%) AND ENERGY REQUIREMENTS 8.6 3.6 Sheet 7 of 7 Jan 7972 8655 8094 (6-5) 8389 8268 (1.4) 8841 6. 9 8749 (1. 0)

Feb 7772 8235 6.0 7333 (11.0) 8022 9.4 8412 4.9 8481 0.8 8606 1.5 Mar 7812 8209 5.1 7310 (11.0) 7659 4.8 8329 8.7 8468 1.7 8421 (0.6)

Apr 7902 8233 4.2 7703 (6.4) 7668 (0-5) 8151 6.3 8340 2.3 8286 (0.6)

May 8686 9001 3.6 7814 (13.2) 8176 4.6 9447 15.5 9019 (4.5) 9893 9.7 Jun 8877 10253 15.5 9685 (5-5) 8527 (12.0) 11081 30.0 9809 (11.5) 10826 10.4 Jul 9815 9850 0.4 9997 1.5 9906 (0-9) 10653 7.5 11217 5.3 11429 1.9 Aug 9754 9659 (1. 0) 9500 (1.6) 10127 6.6 11069 9.3 11058 (0.1) 11337 2.5 Sep 8963 9272 3.4 9790 5.6 10193 4.1 10373 1.8 11247 8.4 11997 6.7 Oct 8561 8846 3.3 8819 (0-3) 9077 2.9 9221 1.6 8976 (2.7) 10061 12.1 Nov 8325 8581 3.1 8230 (4.1) 8342 1.4 9071 8.7 8705 (4.0) 9199 5.7 Dec 8995 8125 (9.7) 8264 1.7 8566 3.7 8849 3.3 8925 0.9 9633 7.9 Monthly Energy Requirements (GWh)

Month 1972 1973 Change (%) 1974 Change (%) 1975 Change (%) 1976 Change (%) 1977 Change (%) 1978 Change (%)

Jan 4336 4684 (8. 0) 4355 (7. 0) 4458 2.4 4542 1.9 4707 3.6 4740 0.7 Feb 4005 4129 3.1 3847 (6.8) 3978 3.4 4208 5.8 4205 (0. 1) 4257 1.2 5.4 (8.4) 2.9 6.4 Mar Apr'ay 4362 4202 4597 4420 5.2 5.4 4210 4135 (6 ')

(6.6) 4330 4268 3.2 (0.5) 4607 4443 4.1 6.1 4746 4569 3.0 2.8 4736 4518 (0.2)

(1.1) PRC Jun Jul 4495 4560 4966 4738 4918 5089 7.9 2.5 4424 4577 4985 (F 9)

(2.0) 4401 4416 4890 (3 ')

(1.9) 4669 4920 5180 11.4 5.9 4650 4933 5341 (0.4) 0.

3.1 3

4937 5247 5554 6.2 6.4 4.0 APEpygpp 5069 5162 1.8 4919 (4.7) 4857 (1.3) 5047 3.9 5605 11. 1 5605 0.0 Aug Sep 4560 4639 1.7 4753 2.5 4764 0.2 4712 (1.1) 4966 5.4 5237 5.5 C4RD Oct 4537 4789 5.6 4555 (4.9) 4599 1.0 4736 3.0 4887 3.2 5235 7.1 Nov 4370 4472 2.3 4236 (5.3) 4314 1.8 4517 4.7 4615 2.2 4896 6.1 Dec 4637 4306 (7.1) 4409 2.4 4532 2.8 4699 3.7 4755 1.2 5094 7.1 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 NEED FOR POWER PALO VERDE NUCLEAR GENERATING STATION Table 1.1-8 Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 1 of 13)

1. 1. 2 POWER SUPPLY (MW)

PVNGS 1,2,&3 PARTICIPANTS (1) PEAKING APS 311 3 11 113 151 345 614 649 624 624 619 619 619 619 619 619 669 669 769 769 769 769 EPE 140 140 140 140 139 66 77 43 109 109 110 110 183 151 151 117 125 125 125 157 240 LADWP 510 510 545 611 641 971 1303 1278 1331 1327 1327 1327 1327 1327 1327 1327 1327 1327 1323 1313 1303 PNM 44 44 44 44 44 64 64 64 58 53 53 53 42 42 31 31 31 31 31 20 20 SCE 515 950 1083 1106 1106 1106 1086 1188 1195 1195 1195 1195 1195 1235 1235 935 935 935 969 800 904 SRP 112 104 101 105 345 514 642 712 644 644 644 657 657 657 657 657 657 657 657 657 657 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 254 254 452 452 452 452 452 468 693 693 693 693 693 693 693 693 693 693 693 693 693 EPE 119 111 136 136 206 196 143 301 141 56 213 158 158 276 390 420 578 492 525 504 271 LADWP 969 969 969 969 962 972 968 968 968 968 924 924 924 924 924 924 924 924 924 924 924 PNM 114 114 114 114 114 114 114 114 114 96 96 96 96 96 96 96 96 96 96 246 360 SCE 8266 8478 8478 8478 9228 9978 9978 9871 10417 10777 10994 11025 11050 11050 11050 11050 11050 11730 12040 12480 12480 SRP 498 498 498 504 504 504 504 796 790 790 790 794 1284 1284 1494 1494 1494 1494 1494 1494 1494 TOTAL INTERMEDIATE 10220 10424 10647 10653 11466 12216 12159 12518 13123 13380 13710 13690 14205 14323 14647 14677 14835 15429 15772 16341 16222 (3) BASE LOAD APS 690 816 936 937 937 915 1038 1143 1248 1248 1483 1483 1725 2072 2428 2424 2780 2780 3136 3136 3614 285 366 366 411 478 496 496 690 725 577 617 EPE LADWP 236 2024 2407 2375 2197 2377 2816 3040 3189 3421 3421 3421 3451 636 3456 606 3456 637 3456 637 3456 645 3916 731 3843 898 3483 898 4099 1098 4355 PRC PNM 175 279 383 383 383 383 548 548 548 709 693 693 933 933 1529 1529 1659 1659 1789 1789 2025 SCE 408 408 1190 159 1616 236 2110 306 2042 318 2170 481 2271 644 2394 2399 1015 2399 1016 2399 1017 2416 1133 2550 1249 1467 4314 4514 4255 4503 4807 5483 APERTURE SRP 0 79 807 1464 1761 1755 2052 2052 2052 3533 4274 5409 5735 6524 6952 7773 8291 9108 9517 9589 9660 10299 11041 13121 CARO TOTAL BASE LOAD 13824 15275 15023 15861 16781 18627 INSTALLED RESOURCE 15385 16757 18082 18545 20610 22503 23753 24718 26192 26844 27247 27311 28527 29395 31788 32237 33854 34296 35507 36838 38742 NON-FIRM PURCHASES OUTSIDE ANPP 135 130 124 123 331 153 348 369 179 179 179 179 179 179 178 178 178 56 56 180 56 NON-FIRM SALES OUTSIDE ANPP 100 170 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 NEED FOR POWER PALO VERDE NUCLEAR GENERATING STATION Table 1.1-8 Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 1 of 13)

1. 1. 2 POWER SUPPLY (MW)

PVNGS 1,2,&3 PARTICIPANTS (1) PEAKING APS 311 311 113 151 345 61LI 649 624 624 619 619 619 619 619 619 669 669 769 769 769 769 EPE 140 140 140 140 139 66 77 43 109 109 110 110 183 151 151 117 125 125 125 157 240 LADWP 510 510 545 611 641 971 1303 1278 1331 1327 1327 1327 1327 1327 1327 1327 1327 1327 1323 1313 1303 PNM 44 44 44 44 44 64 64 64 58 53 53 53 42 42 31 31 31 31 31 20 20 SCE 515 950 1083 1106 1106 1106 1086 1188 1195 1195 1195 1195 1195 1235 1235 935 935 935 969 800 904 SRP 112 104 101 105 345 514 6 LI 2 712 644 644 644 657 657 657 657 657 657 657 657 657 657 TOTAL PEAKING 1632 2059 2026 2157 2620 3335 3821 3909 3961 3947 3948 3961 4023 4031 LI 020 3736 3744 3844 3874 3716 3893 (2) INTERMEDIATE APS 254 254 LI5 2 452 452 452 452 468 693 693 693 693 693 693 693 693 693 693 693 693 693 EPE 119 111 136 136 206 196 143 301 141 56 213 158 158 276 390 420 578 492 525 504 271 LADWP 969 969 969 969 962 972 968 968 968 968 924 924 924 924 924 924 924 924 924 92 LI 924 PNM 11LI 114 114 114 114 114 114 114 114 96 96 96 96 96 96 96 96 96 96 246 360 SCE 8266 8478 8478 8478 9228 9978 9978 9871 10417 10777 10994 11025 11050 11050 11050 11050 11050 11730 12040 12480 12480 SRP 498 498 498 504 504 504 50 LI 796 790 790 790 794 1284 1284 1494 1494 1494 1494 1494 1494 1494 TOTAL INTERMEDIATE 10220 10424 10647 10653 11466 12216 12159 12518 13123 13380 13710 13690 14205 14323 14647 14677 14835 15L129 15772 16341 16222 (3) BASE LOAD APS 690 816 936 937 937 915 1038 1143 1248 1248 1483 1483 1725 2072 2428 2424 2780 2780 3136 3136 3614 EPE 236 285 366 366 411 478 496 496 690 725 577 617 636 606 637 637 645 731 898 898 1098 LADWP 2024 2407 2375 2197 2377 2816 3040 3189 3421 3421 3421 3451 3456 3456 3L156 3456 3916 3843 3483 4099 4355 PNM 175 279 383 383 383 383 548 548 548 709 693 693 933 933 1529 1529 1659 1659 1789 1789 2025 SCE L108 408 1190 1616 2110 20 LI 2 2170 2271 2394 2399 2399 2399 2416 2550 4314 4514 4255 4503 4807 5483 SRP 0 79 159 236 306 318 LI 81 644 807 1015 1016 1017 1133 1249 1467 1464 1761 1755 2052 2052 2052 TOTAL BASE LOAD 3533 4274 5409 5735 6524 6952 7773 8291 9108 9517 9589 9660 10299 11041 13121 13824 15275 15023 15861 16781 18627 PRO INSTALLED RESOURCE 15385 16757 18082 18545 20610 22503 23753 24718 26192 26844 27247 27311 28527 29395 31788 32237 33854 34296 35507 36838 387LI2 APERTURE NON-FIRM PURCHASES OUTSIDE ANPP 135 130 124 123 331 153 348 369 179 179 179 179 179 179 178 178 CARD 178 56 56 180 56 NON-FIRM SALES OUTSIDE ANPP 100 170 CAPABILITY 15517 16884 18203 18666 20939 22654 24099 25087 26371 27023 27426 27490 28706 29 47 LI 31966 32415 34032 34352 35563 37018 38628 1.1-165/166 Blank

PVNGS ER-OL NEED FOR POWER Arizona Public Service Company Table 1.1-8 Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 CAPABILITY OF RESOURCES 1.1.2 Power Supply (MW) 1968 THROUGH 1988 (Sheet 2 of 13)

Plant and Unit Type Fuel Function ARIZONA PUBLIC SERVICE Childs 1 Hydr 0 Base 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 Page 1 of 3 Childs 2 Hydro Base 1.8 1.8 1.8 1.8 1.8 1.8 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 Childs 3 Hydr 0 Base 1.8 1.8 1.8 1.8 1.8 1.8 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 1.2 Irving 1 Hydro Base 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 1.3 Total Hydro 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 Four Corners 1 Steam Coal Base 175 175 175 175 175 175 175 175 175 175 175 175 175 175 175 175 175 175 175 175 175 Four Corners 2 Steam Coal Base 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 Four Corners 3 Steam Coal Base 213 220 220 220 220 220 220 220 220 220 220 220 220 220 220 220 220 220 220 220 220 Cholla 1 Steam Coal Base 120 120 120 120 120 116 116 116 116 116 116 116 116 116 116 116 116 116 116 116 116 Ocotillo 1 Steam Oil Inter. 115 115 115 115 115 115 115 115 115 115 115 115 115 115 115 115 115 115 115 115 115 Ocotillo 2 Steam Oil Inter. 114 114 114 114 114 114 114 114 114 114 114 114 114 114 114 114 114 114 114 114 114 Saguaro 1 (b) Steam Oil Pk/Inter.(e) 99 99 99 99 99 99 99 115 115 115 115 115 115 115 115 115 115 115 115 115 115 Saguaro 2 Steam Oil Pk/Inter.(e) 99 99 99 99 99 99 99 99 99 99 99 99 99 99 99 99 99 99 99 99 99 West Phoenix 4 Steam Oil Peak 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 West Phoenix 5(c) Steam Oil Peak 13 13 13 13 13 13 13 13 13 12 12 12 12 12 12 12 12 12 12 12 12 West Phoenix 6(c) Steam Oil Peak 67 67 67 67 67 67 67 67 67 63 63 63 63 63 63 63 63 63 63 63 63 Yucca 1 Steam Oil Inter. 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 Four Corners 4 Steam Coal Base 119 119 120 120 120 120 120 120 120 120 120 120 120 120 118 118 118 118 118 118 Four Corners 5 Steam Coal Base 120 120 120 120 120 120 120 120 120 120 120 120 120 118 118 118 118 118 118 Yuma GT 1 Comb. Turb. Oil Peak 19 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 Yuma GT 2 Comb. Turb. Oil Peak 19 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 22 Fairview GT 1 Comb. Turb. Oil Peak 18 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 21 Ocotillo GT 1(d)

Saguaro GT 1(d)

Comb.

Comb.

Turb Turb.

Oil Oil Peak Peak 57 56 64 60 57 60 56 55 56 55 56 55 56 55 56 55 56 55 56 55 56 55 56 55 56 55 56 55 56 55 56 55 56 55 PRC West Phoenix GT Yuma GT 1(d) 1(d) Comb.

Comb.

Turb.

Turb.

Oil Oil Peak Peak 57 64 60 58 60 56 57 56 57 56 57 56 57 56 57 56 57 56 57 56 57 56 57 56 57 56 57 56 57 56 57 56 57 APERTUR Ocotillo GT 2(d)

Saguaro GT 2(d)

Comb.

Comb.

Turb.

Turb.

Oil Oil Peak Peak 64 60 58 60 56 54 56 54 56 54 56 54 56 54 56 54 56 54 56 54 56 54 56 54 56 54 56 54 56 54 56 54 CARD West Phoenix GT 2(d) Comb. Turb Oil Peak 64 58 56 56 56 56 56 56 56 56 56 56 56 56 56 56 Yuma GT 4(d) Comb. Turb. Oil Peak 60 56 56 56 56 56 56 56 56 56 56 56 56 56 (a) Capacity shown includes resources installed as of July 1 of that year.

(b) Saguaro 1 upgraded 3/17/75.

(c) West Phoenix 5 and 6 downgraded 10/21/76.

(d) Gas Turbines downgraded 1975.

(e) Saguaro 1 and 2 changed from Peaking to Intermediate in 1970.

1.1-167/168 Blank

PVNGS ER-OL NEED FOR POWER Arizona Public Service Company Table 1.1-8 Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 3 of 13) 1.1.2 Power Supply (MW)

Plant and Unit Fuel Function ARIZONA PUBLIC SERVICE Page 2 of 3 Navajo 1 Steam Coal Base 105 105 105 105 105 105 105 105 105 105 105 105 105 105 105 Navajo 2 Steam Coal Base 105 105 105 105 105 105 105 105 105 105 105 105 105 105 Navajo 3 Steam Coal Base 105 105 105 105 105 105 105 105 105 105 105 105 105 West Phoenix CC 1 Comb. Cycle Oil Inter. 75 75 75 75 75 75 75 75 75 75 75 75 75 West Phoenix CC 2 Comb. Cycle Oil Inter. 75 75 75 75 75 75 75 75 75 75 75 75 75 West Phoenix CC 3 Comb. Cycle Oil Inter. 75 75 75 75 75 75 75 75 75 75 75 75 75 Cholla 2 Steam Coal Base 235 235 235 235 235 235 235 235 235 235 235 Cholla 3 S team Coal Base 242 242 242 242 242 242 242 242 242 Choll.a 4 Steam Coal Base 347 347 347 347 347 347 347 347 Palo Verde 1 S team Nuclear Base 356 356 356 356 356 356 356 Palo Verde 2 Steam Nuclear Base 356 356 356 356 356 Palo Verde 3 Steam Nuclear Base 356 356 356 Peaking Unit 1 Comb. Turb. Oil Peak 50 50 50 50 50 50 Peaking Unit 2 Comb. Turb. Oil Peak 50 50 50 50 Peaking Unit 3 Comb. Turb. Oil Peak 50 50 50 50 Palo Verde 4 Steam Nuclear Base 478 Palo Verde 5 Steam Nuclear Base Future Coal Steam Coal Inter.

(1) Peaking 311 311 113 151 345 614 649 624 624 619 619 619 619 619 619 669 669 769 769 769 769 (2) Intermediate 254 254 452 452 452 452 452 468 693 693 693 693 693 693 693 693 693 693 693 693 693 (3) Base Load 690 816 936 937 937 915 1038 1143 1248 1248 1483 1483 1725 2072 2428 2424 2780 2780 3136 3136 3614 PRC Installed Res. 1255 1381 1501 1540 1734 1981 2139 2235 2565 2560 2795 2795 3037 3384 3740 3786 4142 4242 4598 4598 5076 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 Table 1.1-8 Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 CAPABILITY OF RESOURCES 1.1.2 Power Supply (MW) 1968 THROUGH 1988 (Sheet 4 of 13)

Plant and Unit Fuel Function ARIZONA PUBLIC SERVICE Nonfirm Purchases Page 3 of 3 Outside ANPP PG&E Peaking Unknown Peak 50 Dave Johnston 4 (UP &I,) Steam Coal Base 125 Huntington Canyon 1 (UP&L) Steam Coal Base 100 100 Navajo Layoff Navajo 1, 2.3 Steam Coal Base 16 16 16 16 16 16 15 15 15 Unknown Pur-chase Unknown Base 124 SRP contingent Steam Oil Pk/Inter. (f) 62 62 62 62 62 62 62 62 62 62 62 62 62 62 62 62 62 62 San Juan 2 (TG&E) Steam Coal Base 27 Within PVNGS Total 62 62 237 62 189 162 78 78 78 78 78 78 77 77 77 62 62 186 62 Nonfirm Sales Outside PVNGS APA (Saguaro 1,2) Steam Oil Inter. (3) (3) (3) (2) (2) (2) (2)

Layoff (100) (170) PRC Within PVNGS APERTURE Capability 1314 1440 1560 1600 1969 2041 2326 2397 2643 2638 2873 2873 3115 3362 3817 3863 4219 4304 4660 4784 4968 CARD (a) Capacity shown includes resources installed as of July 1 of that year.

(b) Saguaro 1 upgraded 3/17/75.

(c) West Phoenix 5 and 6 downgraded 10/21/76.

(d) Gas Turbines downgraded 1975.

(e) Saguaro 1 and 2 changed from Peaking to Intermediate in 1970.

(f) SRP contingent changed from Peaking to Intermediate in 1971.

1.1-171/172 Blank

PVNGS ER-OL NEED FOR POWER LOS ANGELES DEPARTMENT OF WATER AND POWER Table 1.1-8 Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 ] 97g 1980 1981 1982 1983 1984 1985 1986 1987 1988 CAPABILITY OF RESOURCES 1 ~ 1. 2 Power Supply (MW) (a) 1968 THROUGH 1988 (Sheet 5 of 13)

Plant and Unit Fuel Function LOS ANGELES DEPARTMENT PNW Hydro Water Base 17 400 324 0 260 525 525 525 525 525 525 350 350 350 350 350 350 350 350 350 350 OF WATER AND POWER Castaic Pumped Strge Water Peaking 0 0 0 0 24 228 560 535 630 630 630 630 630 630 630 630 630 630 630 630 630 Page 1 of 2 Hoover Hydro Water Peaking 400 400 435 501 507 553 553 553 511 511 511 511 511 511 511 511 511 511 507 497 487 Owens Gorge Hydro Water Peaking 110 110 110 110 110 110 110 110 110 110 110 110 110 110 '110 110 110 110 110 110 110 Owens Valley Hydro Water Base 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Aqueduct Hydro Water Base 50 50 63 57 66 73 74 74 74 74 74 74 74 74 74 74 74 74 74 74 74 Harbor 1 Steam Gas/Oil Intermediate 78 78 78 78 78 78 78 78 78 78 72 72 72 72 72 72 72 72 72 72 72 Harbor 2 Steam Gas/Oil Intermediate 79 79 79 79 79 79 79 79 79 79 67 67 67 67 67 67 67 67 67 67 67 Harbor 3 Steam Gas/Oil Intermediate 96 96 96 96 96 96 92 92 92 92 86 86 86 86 86 86 86 86 86 86 86 Harbor 4 Steam Gas/Oil Intermediate 96 96 96 96 96 96 92 92 92 92 86 86 86 86 86 86 86 86 86 86 86 Harbor 5 Steam Gas/Oil Intermediate 96 96 96 96 96 96 94 94 94 94 87 87 87 87 87 87 87 87 87 87 87 Valley 1 Steam Gas/Oil Intermediate 99 99 99 99 95 95 101 101 101 101 94 94 94 94 94 94 94 94 94 94 94 Valley 2 Steam Gas/Oil Intermediate 99 99 99 99 99 101 101 101 101 101 101 101 101 101 101 101 101 101 101 101 101 Valley 3 Steam Gas/Oil Intermediate 163 163 163 163 163 171 171 171 171 171 171 171 171 171 171 171 171 171 171 171 171 Valley 4 Steam Gas/Oil Intermediate 163 163 163 163 160 160 160 160 160 160 160 160 160 160 160 160 160 160 160 160 160 Scattergood 1 Steam Gas/Oil Base 175 175 175 175 179 179 179 179 179 179 179 179 179 179 179 179 179 179 179 179 179 Scattergood 2 Steam Gas/Oil Base 179 179 179 179 0 179 179 179 179 179 179 179 179 179 179 179 179 179 179 179 179 Scattergood 3 Steam Gas/Oil Base 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 460 460 460 460 460 Haynes 1 Steam Gas/Oil Base 232 232 233 233 232 193 232 222 222 222 222 222 222 222 222 222 222 222 222 222 222 Haynes 2 Steam Gas/Oil Base 232 232 236 236 219 219 232 232 232 232 232 232 232 232 232 232 232 232 232 232 232 Haynes 3 Steam Gas/Oil Base 222 222 232 232 220 220 220 220 220 220 220 220 220 220 220 220 220 220 220 220 220 Haynes 4 Steam Gas/Oil Base 222 222 236 236 232 227 227 227 227 227 227 227 227 227 227 227 227 227 227 227 227 Haynes 5 Steam Gas/Oil Base 343 343 344 344 344 344 344 344 344 344 344 344 344 344 344 344 344 344 344 344 344 Haynes 6 Steam Gas/Oil Base 343 343 344 344 344 344 344 344 344 344 344 344 344 344 344 344 344 344 344 344 344 Mohave 1 Steam Coal Base 152 152 152 158 158 158 158 158 158 158 158 158 158 158 158 158 158 158 PRC Mohave 2 Steam Coal Base 0 120 152 158 158 158 158 158 158 158 158 158 158 158 158 158 158 158 APERTURE Navajo 1 Steam Coal Base 159 159 159 159 159 159 159 159 159 159 159 159 159 159 159 Navajo 2 Steam Coal Base 0 159 159 159 159 159 159 159 159 159 159 159 159 159 159 CARD Navajo 3 Steam Coal Base 0 0 159 159 159 159 159 159 159 159 159 159 159 159 159 Navajo Layoff Steam Coal Base 0 0 73 73 73 73 73 73 73 73 73 0 0 0 0 Turbines Comb. Turb. Distillate Peaking 80 80 80 80 76 76 76 76 76 76 76 76 76 76 76 76 Coronado Steam Coal Base 205 210 210 140 140 70 70 (a) Power supply is based on net capacity.

1.1-173/174 Blank

PVNGS ER-OL NEED FOR POWER LOS ANGELES DEPARTMENT OF WATER AND POWER Table 1.1-8 Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 CAPABILITY OF RESOURCES 1.1.2 Power Supply (MW) 1968 THROUGH 1988 (Sheet 6 of 13)

Plant and Unit Type Fuel Function LOS ANGELES DEPARTMENT IPP 1 Steam Coal Base 256 256 OF WATER AND POWER IPP 2( Steam Coal Base 0 256 Page 2 of 2 IPP 3 Steam Coal Base 0 0 IPP 4 Steam Coal Base 0 0 Palo Verde 1 Steam Nuclear Base 70 70 70 70 70 70 70 Palo Verde 2 Steam Nuclear Base 0 0 70 70 70 70 70 Palo Verde 3 Steam Nuclear Base 0 0 0 0 70 70 70 Peaking 510 510 545 611 641 971 1303 1278 1331 1327 1327 1327 1327 1327 1327 1327 1327 1327 1323 1313 1303 Intermediate 969 969 969 969 962 -972 968 968 968 968 924 924 924 924 924 924 924 924 924 924 924 Base Load 2024 2407 2375 2197 2377 2816 3040 3189 3421 3421 3421 3451 3456 3456 3456 3456 3916 3843 3483 4099 4355 Installed Resources 3503 3886 3889 3777 3980 4759 5311 5435 5720 5716 5672 5702 5707 5707 5707 5707 6166 6094 6090 6336 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 PVNGS ER-OL Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 NEED FOR POWER 1.1.2 Power Supply (MW) Table 1.1-8 Plant and Unit Type Fuel Function CAPABILITY OF RESOURCES Rio Grande ¹1((c) Steam Fossil Peaking 20 20 20 20 20 20 13 13 13 13 13 13 13 13 13 13 1968 THROUGH 1988 (Sheet 7 of 13)

Rio Grande ¹2((c) Steam Fossil Peaking 24 24 24 24 24 24 13 13 13 13 13 13 13 13 13 13 Rio Grande ¹3 (c) Steam Fossil Peaking 22 22 22 22 22 22 (f) 17 17 17 17 18 18 18 18 18 18 18 18 18 18 EL PASO ELECTRIC COMPANY Rio Grande ¹4 (((c) c) Steam Fossil Peaking 37 37 37 37 36 37 34 (d) 34 (e) (d) 34 34 '4(d) 34 34 34 34 (e) 34 (d) 34( 34 34 Rio Grande ¹5 Steam Fossil Peaking 37 37 37 36 36 32 (e) 32 (e) 32 (d) 32 (d) 32 (d) 32 32 (e) 32 (e) 32 (e) 32 (e) 2(e) 32(e) 32 (d) 32 (d)

Rio Grande ¹6( (

Steam Fossil B/I/P 32 24 49 49 28 20 42 42 42 47 47 47 47 47 47 47 47 4 '7 47 47 47 Rio Grande ¹7,(c) Steam Fossil B/ I/P 31 24 49 49 28 20 42 42 42 32 32 28 33 47 33 33 33 3 33 36 36 Rio Grande Steam Fossil Bas e 160 160 138 138 138 93 102 91 105 147 106 106 106 106 106 114 114 Newman ¹1(cI Ic Steam Fossil Base 87 87 87 87 86 86 82 82 82 82 82 82 82 82 82 82 82 82 82 82 82 Steam Fossil Base Newman Newman Newman

¹2(b)(

¹3

¹4 (b)

)

Steam Combined Cycle Fossil Fossil Base Base 93 112 93 112 93 112 93 112 ill 92 92 111 86 106 86 106 124 86 106 224 86 106 224 86 106 224 86 106 224 86 106 224 86 106 224 86 106 224 86 106 224 86 106 224 86 106 224 86 106 224 86 106 224 86 106 224 Four Corners ¹4 Steam Fossil Base 56 56 56 56 56 56 56 56 56 56 56 56 56 56 54 54 54 54 54 54 Four Corners ¹5 Steam Fossil Base 56 56 56 56 55 55 55 55 55 55 55 55 55 53 53 53 53 53 53 Copper Combustion Fossil Peaking 73 73 73 73 73 73 73 73 73 Turbine Future ¹1 Steam Coal Base Future ¹2 Steam Coal Base PVNGS ¹1 Steam Nuclear Base 200 200 200 200 200 200 200 PVNGS ¹2 Steam Nuclear Base 200 200 200 200 200 PVNGS ¹3 Steam Nuclear Base 200 200 200 PVNGS ¹4 Steam Nuclear Base 50 PVNGS ¹5 Steam Nuclear Base Total Installed Resources 495 536 642 642 756 740 716 840 940 890 900 885 977 1033 1178 1174 1348 1348 1548 1559 1609 Total Peaking 140 140 140 140 139 66 77 43 109 109 110 110 183 151 151 117 125 125 125 157 240 Total Intermediate (e) 119 111 136 136 206 196 143 301 141 .56 213 158 158 276 390 420 578 492 525 504 271 Total Base Load( 236 285 366 366 411 478 496 496 690 725 577 617 636 606 637 637 645 731 898 898 1098 Purchase Within ANPP Sale Within ANPP Capability (IR + P S) 495 536 642 756 740 716 840 940 890 900 885 977 1033 1178 1174 1348 1348 1548 1559 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.

(e) Operated as intermediate unit

( f)

Operated as base load unit. 1.1-177/178 Blank

PUBLIC SERVICE COMPANY OF NEW MEXICO PVNGS-ER-OL Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 NEED FOR POWER 1.1.2 Power Supply (MW)

Table 1.1-8 Plant and Unit Type Fuel Function CAPABILITY OF RESOURCES prager 6 Steam Fossil Peaking 6 6 6 6 6 6 6 6 0 Prager 7 Steam Fossil Peaking 7 7 7 7 7 7 7 7 7 6 6 6 0 1968 THROUGH 1988 (Sheet 8 of 13)

Fossil Peaking Prager Prager 8

9 Steam Steam Fossil Peaking 7

12 12 7 7 12 7

12 7

12 7

12 7

12 7

12 7

12 11 5 5 11 5

11 ll 0 PUBLIC SERVICE COMPANY OF NEW MEXICO Santa Fe 1 Steam Fossil Peaking .6 5.5 5.5 5.5 5.5 5.5 5.5 5.5 5.5 5.5 5.5 Santa Fe 2 Steam Fossil Peaking 6 5.5 5.5 5.5 5.5 5.5 5.5 5.5 5.5 5.5 5.5 Person 1 Steam Fossil Intermediate 22 22 22 22 22 22 22 22 22 18 18 18 18 18 18 18 18 18 18 18 0 Person 2 Steam Fossil Intermediate 22 22 22 22 22 22 22 22 22 18 18 18 18 18 18 18 18 18 18 18 0 Person 3 Steam Fossil Intermediate 35 35 35 35 35 35 35 35 35 28 28 28 28 28 28 28 28 28 28 28 28 Person 4 Steam Fossil Intermediate 35 35 35 35 35 35 35 35 35 32 32 32 32 32 32 32 32 32 32 32 32 Reeves 1 Steam Fossil Base Load 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 Reeves 2 Steam Fossil Base Load 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 50 Reeves 3 Steam Fossil Base Load 75 75 75 75 75 75 75 75 75 75 75 75 75 75 75 75 75 75 75 75 75 Four Corners 4 Steam Fossil Base Load 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 Four Corners 5 Steam Fossil Base Load 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 104 Las Vegas GT Comb. Turb. Fossil Peaking 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 San Juan 1 Steam Fossil Base Load 165 157 157 157 157 157 157 157 157 157 157 157 San Juan 2 Steam Fossil Base Load 165 165 165 161 153 153 153 153 153 153 153 153 153 153 153 San Juan 3 Steam Fossil Base Load 240 240 234 234 234 234 234 234 234 San Juan 4 Steam Fossil Base Load 472 472 472 472 472 472 472 PV 1 Steam Nuclear Base Load 130 130 130 130 130 130 130 PV 2 Steam Nuclear Base Load 130 130 130 130 130 PV 3 Steam Nuclear Base Load 130 130 130 Pumped Storage 1-2 Pumped Storage PS Intermediate 150 150 Pumped Storage 3-4 Pumped Storage PS Intermediate 150 Mexico Station Fossrl Base Load 236 New Steam PRC APERTURE CARD 1.1-179/180 Blank

PVNGS ER-OL SALT RIVER PROJECT NEED FOR POWER Year 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 1.1.2 Power Supply (MW)

Plant and Unit Type Fuel Function CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 9 of 13)

Roosevelt Hydro Peaking 19 19 21 36 36 36 36 36 36 36 36 36 36 36 36 36 36 SALT RIVER PROJECT Mormon Flat ¹1 Hydro Peaking 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 Page 1 of 3 Mormon Flat ¹2 Pumped Storage Peaking 49 50 50 50 50 44 44 44 44 44 44 44 44 44 44 44 Horse Mesa ¹1, 2, 3 Hydro Peaking 30 30 26 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 Horse Mesa ¹4 Pumped Storage Peaking 94 97 97 97 96 96 96 93 93 93 93 93 93 93 93 93 Stewart Mt. Hydro Peaking 10 10 10 10 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 Cross Cut Hydro Peaking Agua Fria ¹1 Steam Oil/Gas Intermediate 106 106 106 109 109 109 109 109 109 109 109 Agua Fria ¹2 Steam Oil/Gas Intermediate 106 106 106 109 109 109 109 109 109 109 109 Agua Fria ¹3 Steam Oil/Gas Intermediate 182 182 182 182 182 182 182 182 180 180 180 180 180 180 180 180 180 180 180 180 180 Kyrene ¹1 Steam Oil/Gas Intermediate 34 34 34 34 34 34 34 34 34 34 34 34 34 34 34 34 34 34 34 Kyrene ¹2 Steam Oil/Gas Intermediate 70 70 70 70 70 70 70 70 70 70 70 70 70 70 70 70 70 70 70 70 70 Crosscut ¹1, 2, 3, 4 Steam Oil/Gas Peaking 34 34 34 34 34 34 34 34 32 32 32 32 32 32 32 32 32 32 32 32 Crosscut (a) Internal Comb. Oil Peaking Diesel Four Corners ¹4 Steam Coal Base 79 80 80 80 80 80 80 80 80 80 80 80 80 80 79 79 79 79 79 79 Four Corners ¹5 Steam Coal Base 79 80 80 80 80 80 80 80 80 80 80 80 80 78 78 78 78 78 Mohave ¹1 Steam Coal Base 76 76 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 PRC Mohave ¹2 Steam Coal Base 70 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 APE/ j /pe Kyrene ¹3 Comb. Turb. Oil/Gas Peaking 56 63 63 63 48 48 48 51 51 51 51 51 51 51 51 51 51 cARD Retired 8/15/68 1.1-181/182 Blank

PVNGS ER-OL SALT RIVER PROJECT NEED FOR POWER Year 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 1.1.2 Power Supply (MW)

Plant and Unit Type Fuel Function CAPABILITY OF RESOURCES Turb. Oil/Gas Peaking 61 61 48 1968 THROUGH 1988 (Sheet 10 of 13)

Kyrene ¹4 Comb. 56 61 48 48 51 51 51 51 51 51 51 51 51 51 SALT RIVER PROJECT Kyrene ¹5 Comb . Tu rb . Oil/Gas Peaking 58 58 58 42 42 42 47 47 47 47 47 47 47 47 47 Page 2 of 3 Kyrene ¹6 Comb. Turb. Oil/Gas Peaking 57 57 57 42 42 42 47 47 47 47 47 47 47 47 Navajo ¹1 Steam Coal Base 163 163 163 163 163 163 163 163 163 163 163 163 163 163 163 Agua Fria ¹5 Comb. Turb. Oil Peaking 64 64 66 66 66 64 64 64 64 64 64 64 64 64 64 Agua Fria ¹6 Comb. Turb. Oil Peaking 64 64 66 66 66 64 64 64 64 64 64 64 64 Santan ¹1 Com. Cycle Oil Intermediate 73 72 72 72 72 72 72 72 72 72 72 72 72 72 Santan ¹2 Com. Cycle Oil Intermediate 73 72 72 72 72 72 72 72 72 72 72 72 72 72 Santan ¹3 Com. Cycle Oil Inter'mediate 73 72 72 72 72 72 72 72 72 72 72 72 72 Santan ¹4 Com. Cycle Oil Intermediate 73 72 72 72 72 72 72 72 72 72 72 72 72 72 Agua Fria ¹4 Com. Turb. Oil Peaking 70 66 69 69 69 69 69 69 69 69 Navajo ¹2 Steam Coal Base 163 163 163 163 163 163 163 163 163 163 163 163 163 163 Hayden ¹2 Steam Coal Base 208 209 210 210 210 131 131 131 125 125 125 125 Navajo ¹3 Coal Base 163 163 163 163 163 163 163 163 163 163 163 163 163 Steam'team Craig ¹1 Coal Base 116 116 116 116 116 116 116 116 116 Coronado ¹1 Steam Coal Intermediate 245 245 350 350 350 350 350 350 350 PRg Craig ¹2 Steam Coal Base 116 116 116 116 116 116 116 116 APppyp~~

Coronado ¹2 Steam Coal Intermediate 245 245 350 350 350 350 350 350 350 ~ARO Palo Verde ¹1 Steam Nuclear Base 297 297 297 297 297 297 297 Palo Verde ¹2 Steam Nuclear Base 297 297 297 297 297 1.1-183/184 Blank 4%%w~wm xm~ -Ac)

PVNGS ER-OL SALT RIVER PROJECT NEED FOR POWER Year 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 1.1.2 Power Supply (MW) CAPABILITY OF RESOURCES Plant and Unit Type Fuel Function 1968 THROUGH 1988 (Sheet 11 of 13)

Palo Verde ¹3 Steam Nuclear Base 297 297 297 SALT RIVER PROJECT Total Peaking 112 104 101 105 345 514 642 712 644 644 644 657 657 657 657 657 657 657 657 657 657 Page 3 of 3 Total Intermediate 498 498 498 504 504 504 504 796 790 790 790 794 1,284 1,284 1,494 1,494 1,494 1,494 1,494 1,494 1,494 Total Base 79 159 236 306 318 481 644 807 1,015 1, 016 1,017 1,133 1,249 1,467 1,464 1,761 1 755 2,052 2,052 2,052 Installed Resources 610 681 758 845 1, 155 1, 336 1,627 2, 152 2, 241 2,449 2,450 2,468 3,074 3,190 3,618 3 615 3 912 3 906 4,203 4, 203 4, 203 Nonfirm Purchases Outside ANPP Arizona Power Authority 50 50 50 56 55 56 56 56 56 56 56 56 56 56 56 56 56 56 56 Colorado-Ute Elec. 85 80 74 67 71 50 50 Plains Electric G&T 30 30 USBR-Navajo Layoff 85 163 107 107 107 107 107 107 107 107 107 Nonfirm Purchases Within ANPP Southern California Edison 80 0 0 0 0 0 Total Nonfirm Purchases 135 130 124 203 156 153 221 269 163 163 163 163 163 163 163 163 163 56 56 56 56 Nonfirm Sales Outside ANPP Nonfirm Sales Within ANPP Arizona Public Service (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) PRO Los Angeles Dept. of Water a ~~Earuap Power 0 0 0 0 (140) (140) (70) (70) 0 CARD Total Nonfirm Sales (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (62) (202) (202) (132) (132) (62) (62) (62)

Capability (IR+NFP-NFS) 683 749 820 986 1,249 1,427 1,786 2,359 2,342 2,550 2,551 2,569 3,175 3,291 3,579 3,576 3,943 3,830 4,197 4,197 4,197 1.1-185/186 Blank

PVNGS ER-OL NEED FOR POWER Southern California Edison Company Table 1.1-8 Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 CAPABILITY OF RESOURCES 1968 THROUGH 1988 (Sheet 12 of 13) 1.1.2 Power Supply (MW)

Plant and Unit TYpe Fuel Function SOUTHERN CALIFORNIA EDISON Big Creek Plant Hydro Intermediate 530 530 530 530 530 530 530 530 530 530 530 530 561 561 561 561 561 561 561 561 561 Page 1 of 2 Portal Hydro Intermediate 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 Mammoth Pool Hydro Intermediate 150 150 150 150 150 150 150 150 150 150 150 150 150 150 150 150 150 150 150 150 150 Santa Ana Hydro Base 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 Ontario HYdro Base 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Mill Creek Hydro Base 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Lytle Creek Hydro Base 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Kern-Borel Hydro Base 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 Kern River Hydro Base 61 61 61 61 61 61 61 61 61 61 61 61 61 61 61 61 61 61 61 61 61 Tule River Hydro Base 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 Kaweah Hydro Base 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Fontana Hydro Base 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 Sierra Hydro Base 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 San Gorgonio Hydro Base 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 Bishop Creek Hydro Intermediate 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 29 Lundy Hydro Intermediate 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 Rush Creek Hydro Intermediate 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 Poole Hydro Intermediate 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 10 Hoover-SCE Hydro Peaking 277 277 277 277 277 277 277 331 331 331 331 331 331 331 331 331 331 331 331 0 0 I2 Hoover MWD Hydro Intermediate 310 310 310 310 310 310 310 315 315 315 315 315 315 315 315 315 315 315 315 315 315 Hydro Hydro Intermediate 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 140 140 140 140 Oroville-Thermal r 'to Hydro Peaking 0 284 296 319 319 319 319 319 326 326 326 326 326 326 326 0 0 0 0 0 0 Edwards AFB Exch ange Hydro Peaking 0 0 0 0 0 0 0 0 0 0 0 0 0 18 18 18 18 18 0 0 0 Vernon Diesel Oil Peaking 20 20 20 20 20 20 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Gabbs Diesel Oil Peaking 6 6 6 6 6 6 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1-8 Steam Oil Intermediate 1602 1602 1602 1602 1602 1602 1602 1602 1602 Redondo Highgrove 1-4 Steam Oil Intermediate 154 154 154 154 154 154 154 154 1602 154 154 1602 154 1602 154 1602 154 1602 154 1602 154 1602 154 1602 154 1602 154 1602 154 1602 154 1602 154 PRC Etiwanda 1-4 Steam Oil Intermediate 904 904 904 904 904 904 904 904 904 904 904 904 904 904 904 904 904 El Segundo 1-4 Alamitos 1 6 Steam Steam Oil Oil Intermediate Intermediate 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 1020 1950 904 1020 1950 904 1020 1950 904 1020 1950 904 1020 1950 APppyp~~

San Bernardino 1 2

~ Steam Oil Intermediate 126 126 126 126 126 126 126 126 126 126 216 126 126 126 126 126 126 126 126 126 126 Ching Huntington Beach 1-4 Steam Oil Intermediate 870 870 870 870 870 870 870 870 870 870 870 870 870 870 870 870 870 870 870 870 870 Mandalay 1,2 Steam Oil Intermediate 430 430 430 430 430 430 430 430 430 430 430 430 430 430 430 430 430 430 430 430 430 Cool Water 1,2 Steam Oil Intermediate 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 Garden State Comb. Turb. Oil Intermediate 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 San Onofre 1 Nuclear Nuclear Base 308 308 344 344 344 344 344 344 344 349 349 349 349 349 349 349 349 349 349 349 349 Long Beach 10 Steam Oil Intermediate 106 106 106 106 106 106 106 50 50 106 106 106 106 106 106 106 106 106 106 106 106 Long Beach 11 Steam Oil Intermediate 106 106 106 106 106 106 106 50 50 50 50 106 106 106 106 106 106 106 106 106 106 Etiwanda 5 Comb. Turb. Oil Peaking 0 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 Huntington Beach Comb. Turb. Oil Peaking 0 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 Alamitos 7 Comb. Turb. Oil Peaking 0 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 1.1-187/188 Blank March 1981 Supplement 2

PVNGS ER-OL NEED FOR POWER Southern California Edison Company Table 1.1-8 Year 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 19'79 1980 1981 1982 1983 1984 1985 1986 1987 1988 CAPABILITY OF RESOURCES 1.1.2 Power Supply (MW) 1968 THROUGH 1988 (Sheet 13 of 13)

Plant and Unit Typ e Fuel Function SOUTHERN CALIFORNIA EDISON Mandalay 3 Comb. Turb. Oil Peaking 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 121 Page 2 of 2 Four Corners 4 Steam Coal Base 373 373 373 373 373 373 373 373 373 373 373 373 366 366 366 366 366 366 366 Four Corners 5 Steam Coal Base 373 373 373 373 373 373 373 373 373 373 373 373 366 366 366 366 366 366 366 Mohave 1 Steam Coal Base 0 426 426 426 442 442 442 442 442 442 442 442 442 442 442 442 442 442 442 Mohave 2 Steam Coal Base 0 0 494 426 443 443 443 443 443 443 443 443 443 443 443 443 443 443 443 Ormond Beach 1 Steam Oil Intermediate 0 0 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 Ormond Beach 2 Steam Oil Intermediate 0 0 0 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 Navajo Layoff Steam Coal Base 0 0 0 0 95 196 319 319 319 319 312 266 263 263 263 0 0 0 0 I2 Ellwood Comb. Turb. Coal Peaking 0 0 0 0 0 54 54 54 54 54 54 54 54 54 54 54 54 54 54 Long Beach 1-9 Comb. Cycle Coal Intermediate 0 0 0 0 0 0 0 490 490 543 543 543 543 543 543 543 543 543 543 Cool Water 3,4 Comb. Cycle Coal Intermediate 0 0 0 0 0 0 0 0 360 468 468 468 468 468 468 468 468 468 468 Co-Generation Co-Generation Base 0 0 0 0 0 0 0 0 0 0 24 28 32 37 41 45 49 53 57 San Onofre 2 Nuclear Nuclear Base 0 0 0 0 0 0 0 0 0 0 0 176 880 880 880 880 880 880 880 San Onofre 3 Nuclear Nuclear Base 0 0 0 0 0 0 0 0 0 0 0 0 176 880 880 880 880 880 880 Axis Steam Steam Oil Intermediate 0 0 0 0 0 0 0 0 0 0 0 25 25 25 25 25 25 25 25 Axis CT Comb. Turb. Oil Peaking 0 0 0 0 0 0 0 0 0 0 0 22 22 22 22 22 22 22 22 Palo Verde 1 Nuclear Nuclear Base 0 0 0 0 0 0 0 0 0 0 0 0 187 187 187 187 187 187 187 Palo Verde 2 Nuclear Nuclear Base 0 0 0 0 0 0 0 0 0 0 0 0 0 0 187 187 187 187 187 Palo Verde 3 Nuclear Nuclear Base 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 188 188 188 Wind 1 4 Wind Base 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 3 8 18 Fuel Cells 1 19 Fuel Cell Oil Peaking 0 0 0 0 0 0 0 0 0 0 0 0 0 26 26 26 78 130 234 Geothermal 1-4 Geothez'mal Base 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 9 63 108 108 Combined Cycle Comb. Cycle Oil Intermediate 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 540 850 1290 1290 California Coal 1 Steam Coal Base 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 250 250 California Coal 2 Steam Coal Base 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 250 Combustion Turbines Comb. Turb. Oil Peaking 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 110 110 Palo Verde 4 Nuclear Nuclear Base 0 0 0 0 0 0 0 .

0 0 0 0 0 0 0 0 0 0 0 412 Peaking 515 950 1083 1106 1106 1106 1086 1188 1195 1195 1195 1195 1195 1235 1235 935 935 935 969 800 904 Intermediate 8266 8478 8478 8478 9228 9978 9978 9871 9871 10417 10777 10994 11025 11050 11050 11050 11050 11730 12040 12480 1 2480 Base Load 408 408 1190 1616 2110 2042 2170 2271 2394 2399 2399 2399 2416 2550 3604 4314 4514 4255 4503 4807 5483 Adverse Year Hydro Derate (101) (112) (112) (92) (100) (100) (100) (203) (213) (213) (213) (213) (213) (213) (213) (193) (193) (193) (193) (139) (139)

Ppg Installed Resources 9088 9724 0639 11108 12344 13026 13134 13127 13247 13798 14158 14375 14423 14622 15676 16106 16306 16727 17319 17948 18728 PPp ~

Cgq~ E 1.1-189/190 Blank March 1981 Supplement 2

PVNGS ER-OL ARIZONA NEW MEXICO POWER AREA NEED FOR POWER Thermal Plant Name, Unit No., New Capability Location (MW) Primary Fuel Alternate Fuel Thermal Table 1.1-9 Unit WESTERN SYSTEMS COORDINATING COUNCIL Hydro Plant Name (No. of Units) Unit Fuel Delivery Fuel Delivery Commercial Org. Location Type Summer Winter Type Methods Type Methods Operation Comments EXISTING GENERATION CAPABILITY AS OF JANUARY 1, 1979 AEPC Apache CC 1, Cochise, AZ CA 75 75 F02 TK NG PL 1965 AEPC Apache CC 1, Cochise, AZ CT 10 10 F02 TK NG PL 1965 Sheet 1 of 11 AEPC Apache GT 2, Cochise, AZ GT 20 20 F02 TK MG PL 1972 ARIZONA NEW MEXICO POWER AREA AEPC Apache GT 3, Cochise, AZ GT 63 63 F02 TK NG PL 1974 (Page 1 of 4)

APS Childs (3), Camp Verde, AZ HY 4 4 WAT APS Irving (2), Camp Verde, AZ HY 1 1 WAT APS Cholla 1, Joseph City, AZ ST 116 116 SUB RR, TK None 1962 APS Cholla 2, Joseph City, AZ ST 235 235 SUB RR,TK None 1978 APS Douglas GT 1, Douglas, AZ GT 21 21 F02 TK Mone 1972 Formerly called Fairview.

APS Four Corners 1, Farmington, NM ST 175 175 SUB RR,TK None 1963 APS Four Corners 2, Farmington, NM ST 177 177 SUB RR,TK None 1963 APS Four Corners 3, Far'mington, NM ST 220 220 SUB RR,TK None 1964 APS Four Corners 5, Farmington, NM ST 800 800 SUB RR,TK None 1970 APS 15% PNM 13% SRP 10%

EPE 7%p TGE 7%~ SCE 48%

APS Phoenix CC 1, Phoenix, AZ CS 24 24 WH 1976 APS Phoenix CC 1, Phoenix, AZ CT 51 51 F02 RR, TK Top RR,TK 1976 APS Phoenix CC 2, Phoenix, AZ CW 24 24 WH 1976 APS Phoenix CC 2, Phoenix, AZ CT 51 51 F02 RR, TK Top RR,TK 1976 APS Phoenix CC 3, Phoenix, AZ CY 24 24 WH 1976 APS Phoenix CC 3, Phoenix, AZ CT 51 51 F02 RR,TK Top RR,TK 1976 APS Phoenix 4, Phoenix, AZ ST 33 33 F06 RR,TK NG PL 1948 APS Phoenix 5, Phoenix, AZ ST 12 12 F06 RR,TK MG PL 1949 APS Phoenix 6, Phoenix, AZ ST 63 63 F06 RR~TK NG PL 1950 APS Phoenix GT 1, Phoenix, AZ GT 56 56 F02 RR,TK NG PL 1972 APS Phoenix GT 2, Phoenix, AZ GT 56 56 F02 RR,TK NG PL 1973 APS APS

'Ocotillo Ocotillo 1, Tempe, AZ 2, Tempe, AZ ST ST 115 115 115 115 F06 F06 RR,TK RR,TK NG PL PL 1960 1960 PRC APS Ocotillo GT 1, Tempe, AZ GT 56 56 F02 RR,TK NG NG PL 1972 "F'ER APS APS Ocotillo Saguaro GT 2, Tempe, AZ 1, Red Rock, AZ GT ST 56 115 56 115 F02 F06 RR,TK NG PL 1973 TuRE APS Saguaro 2, Red Rock, AZ ST 99 99 F06 RR~TK RR,TK NG NG PL PL 1954 1955 CARO APS Saguaro GT 1, Red Rock, AZ GT 55 55 F02 RR,TK NG PL 1972 APS Saguaro GT 2, Red Rock, AZ GT 55 55 F02 RR~TK MG PL 1973 APS Tapco 1, Clarkdale, AZ ST 0 0 F06 TK None 1917 7 MW capability Not available APS Yuma 1, Yuma, AZ ST 75 75 F06 RR, TK PL 1959 Ownership: APS 33.3%,

APS Yuma GT 1, Yuma, AZ SCE 33 3%, IID 33 3%

GT 22 22 F02 RR, TK MG PL 1971 APS Yuma GT 2, Yuma, AZ GT 22 22 F02 RR,TK NG PL 1971 APS Yuma GT 3, Yuma, AZ GT 57 57 F02 RR,TK NG PL 1973 1.1-191/192 Blank

PVNGS ER OL ARIZONA NEW MEXICO POWER AREA NEED FOR POWER Thermal Plant Name, Unit No., New Capability Location (MW) Primary Fuel Alternate Fuel Thermal Table 1.1-9 Hydro Plant Name (No. of Units)

Unit WESTERN SYSTEMS COORDINATING COUNCIL Unit Fuel Delivery Fuel Delivery Commercial Org Location Type Summer Winter Type Methods Type Methods Operation Comments EXISTING GENERATION CAPABILITY AEPC Apache 1, Cochise, AZ 75 AS OF JANUARY 1, 1979 CC CA 75 F02 TK NG PL 1965 AEPC Apache CC 1, Cochise, AZ CT 10 10 F02 TK NG PL 1965 Sheet 1 of 11 AEPC Apache GT 2, Cochise, AZ GT 20 20 F02 TK NG PL 1972 AEPC Apache GT 3, Cochise, AZ GT 63 63 F02 ARIZONA NEW MEXICO POWER AREA TK NG PL 1974 (Page 1 of 4)

APS Childs (3), Camp Verde, AZ HY 4 4 WAT APS Irving (2), Camp Verde, AZ HY 1 1 WAT APS Cholla 1, Joseph City, AZ ST 116 116 SUB RR, TK None 1962 APS Cholla 2, Joseph City, AZ ST 235 235 SUB RR, TK None 1978 APS Douglas GT 1, Douglas, AZ GT 21 21 F02 TK None 1972 Formerly called Fairview.

APS Four Corners 1, Farmington, NM ST 175 175 SUB RR,TK None 1963 APS Four Corners 2, Farmington, NM ST 177 177 SUB RR,TK None 1963 APS Four Corners 3, Farmington, NM ST 220 220 SUB RR,TK None 1964 APS Four Corners 5, Farmington, NM ST 800 800 SUB RR,TK None 1970 APS 15% PNM 13% SRP 10%>

EPE 7%i TGE 7% SCE 48%

APS Phoenix CC 1, Phoenix, AZ CS 24 24 WH 1976 APS Phoenix CC 1, Phoenix, AZ CT 51 51 F02 RR, TK Top RR,TK 1976 APS Phoenix CC 2, Phoenix, AZ CW 24 24 WH 1976 APS Phoenix CC 2, Phoenix, AZ CT 51 51 F02 RR, TK Top RR,TK 1976 APS Phoenix CC 3, Phoenix, AZ CY 24 24 WH 1976 APS Phoenix CC 3, Phoenix, AZ CT 51 51 F02 RR~TK Top RR, TK 1976 APS Phoenix 4, Phoenix, AZ ST 33 33 F06 RR,TK NG PL 1948 APS Phoenix 5, Phoenix, AZ ST 12 12 F06 RR,TK NG PL 1949 APS Phoenix 6, Phoenix, AZ ST 63 63 F06 RR,TK NG PL 1950 APS Phoenix GT 1, Phoenix, AZ GT 56 56 F02 RR,TK NG PL 1972 APS Phoenix GT 2, Phoenix, AZ GT 56 56 F02 RR,TK NG PL 1973 APS 'Ocotillo 1, Tempe, AZ ST 115 115 F06 RR,TK NG PL 1960 APS Ocotillo 2, Tempe, AZ ST 115 115 F06 RR,TK APS APS Ocotillo Ocotillo GT 1, Tempe, AZ GT 2, Tempe, AZ GT GT 56 56 56 56 F02 F02 RR,TK NG NG PL PL 1960 1972 PRC RR,TK NG PL 1973 APS APS Saguaro Saguaro 1, Red Rock, AZ 2, Red Rock, AZ ST ST 115 99 115 99 F06 F06 RR,TK RR,TK NG PL 1954 ~~ERTURE NG PL 1955 APS APS Saguaro Saguaro GT 1, Red Rock, AZ GT 2, Red Rock, AZ GT GT 55 55 55 55 F02 F02 RR,TK RR,TK NG PL PL 1972 CARD NG 1973 APS Tapco 1, Clarkdale, AZ ST 0 0 F06 TK None 1917 7 MW capability APS Yuma 1, Yuma, AZ Not available ST 75 75 F06 RR,TK NG 1959 Ownership: APS 33.3%,

APS Yuma GT 1, Yuma, AZ SCE 33 3% IID 33 3%

GT 22 22 F02 RR, TK NG PL 1971 APS Yuma GT 2, Yuma, AZ GT 22 22 F02 RR,TK NG PL 1971 APS Yuma GT 3, Yuma, AZ GT 57 57 F02 RR,TK NG PL 1973 1.1-191/192 Blank

PVNGS ER OL NEED FOR POWER ARIZONA NEW MEXICO POWER AREA Table 1.1-9 Thermal Plant Name, Unit No., New Capability Thermal WESTERN SYSTEMS COORDINATING COUNCIL Location (MW) Primary Fuel Alternate Fuel Unit EXISTING GENERATION CAPABILITY Hydro Plant Name (No. of Units) Unit Fuel Delivery Fuel Delivery Commercial Org. Location Type Summer Winter Type Methods Type Methods Operation Comments AS OF JANUARY 1, 1979 APS Yuma GT 4, Yuma, AZ GT 56 56 F02 RR,TK Top RR~ TK 1974 Sheet 2 of 11 ARIZONA NEW MEXICO POWER AREA Citizens 1-4, Nogales, AZ IC F02 TK NG PL 1959 (Page 2 of 4)

EPE Newman 1, El Paso, TX ST 82 82 NG PL F04 TK 1960 EPE Newman 2, El Paso, TX ST 86 86 NG PL F04 TK 1963 EPE Newman 3, El Paso, TX ST 106 106 NG PL F04 TK 1969 EPE Newman 4, El Paso, TX CT 59 59 NG PL F02 TK 1975 EPE Newman 4, El Paso, TX CT 59 59 NG PL F02 TK 1975 EPE Newman 4, El Paso, TX CW 106 106 WH 1975 EPE Rio Grande 1, Near El Paso, TX ST 13 13 NG PL F04 TK, RR 1930 EPE Rio Grande 2, Near El Paso, TX ST 13 13 NG PL F04 TK, RR 1929 EPE Rio Grande 3, Near El Paso, TX ST 19 19 F04 TK, RR NG PL 1949 EPE Rio Grande 4, Near El Paso, TX ST 34 34 F04 TK~ RR NG PL 1951 EPE Rio Grande 5, Near El Paso, TX ST 32 32 F04 TK, RR NG PL 1954 EPE Rio Grande 6, Near El Paso, TX ST 47 47 F04 TK, RR NG PL 1957 EPE Rio Grande 7, Near El Paso, TX ST 47 47 F04 TK, RR NG PL 1958 EPE Rio Grande 8, Near El Paso, TX ST 147 147 F02 TK, RR NG PL 1972 IID Drop 2 (2), Holtville, CA HY 8 0 WAT Minimum 14 MW total cap.

IID Drop 3 (2), Holtville, CA HY 8 0 WAT Available from IID hydro gen IID Drop 4 (2), Holtville, CA HY 16 0 WAT According to 5 yr history I ID Pilot Knob (2), Winterhaven, CA HY 7 0 WAT IID Brawley GT 1, Brawley, CA GT 11 11 F02 TK None 1962 IID Brawley GT 2, Brawley, CA GT 11 11 F02 TK None 1962 IID Brawley Diesel 1-8, Brawley, CA IC 12 12 F02 TK None 1939 IID Coachella GT 1, Coachella, CA GT 20 20 F02 TK NG PL 1973 IID IID Coachella GT 2, Coachella, CA Coachella GT 3, Coachella, CA GT GT 20 20 20 20 F02 F02 TK TK NG NG PL PL 1973 1974 PRC IID Coachella GT 4, Coachella, CA GT 20 20 F02 TK NG PL 1977 APE IID El Centro 1, El Centro, CA ST 22 22 F06 TK NG PL 1949 IID El Centro 2, El Centro, CA ST 30 30 F06 TK NG PL 1952 CARg IID El Centro 3, El Centro, CA ST 48 48 F06 TK NG PL 1957 IID El Centro 4, El Centro, CA ST 80 80 F06 TK NG PL 1968 Los Alamos Station, Los Alamos, NM ST 16 16 PL F02 TK 1946 PEGT Algodones 1, Algodones, NM ST 15 15 NG PL F06 TK 1954 PEGT Algodones 2, Algodones, NM ST 15 15 NG PL F06 TK 1954 PEGT Algodones 3, Algodones, NM ST 15 15 NG PL F06 TK 1959 Las Vegas Unit 1, Las Vegas, NM GT 20 20 PL F02 TK 1973 PNM plans to test all units 1.1-193/194 Blank

PVNGS ER-OL NEED FOR POWER ARIZONA NEW MEXICO POWER AREA Table 1.1-9 Thermal Plant Name, Unit No., New Capability Thermal WESTERN SYSTEMS COORDINATING COUNCIL Location (NW) Primary Fuel Alternate Fuel Unit Unit Fuel Delivery Fuel Delivery Commercial EXISTING GENERATION CAPABILITY Hydro Plant Name (No. of Units)

Org. Location Type Summer Winter Type Methods Type Methods Operation Comments AS OF JANUARY 1, 1979 Person Unit 1, Albuquerque, NM ST 18 18 MG PL F02 TK, RR, PL 1952 In the near future to obtain Sheet 3 of 11 PNM PNM Person Unit 2, Albuquerque, NN ST 18 18 NG PL F02 TK,RR,PL 1953 summer and winter ratings. ARIZONA NEW MEXICO POWER AREA PNM Person Unit 3, Albuquerque, NM ST 28 28 NM PL F04 TK, RR 1954 This comment applies to all of 4)

PMM units in this report. (Page 3 PNM Person Unit 4, Albuquerque, NN ST 32 32 NG PL F04 TK, RR 1957 PNM Prager Unit 7, Albuquerque, NM ST 6 6 MG PL F02 TK, RR 1945 For the past 3 years, all PNM Prager Unit 8, Albuquerque, NM ST 5 5 NG PL F02 TK, RR 1947 fuel oil deliveries have PNN Prager Unit 9, Albuquerque, NM ST 11 11 NG PL F02 TK, RR 1948 been by tanker truck. This PNM Reeves Unit 1, Albuquerque, NM ST 50 50 NG PL F04 TK, RR 1960 comment applies to units PNM Reeves Unit 2, Albuquerque, MN ST 50 50 NG PL F04 TK, RR 1959 with rail and/or pipeline PNM Reeves Unit 3, Albuquerque, NM ST 75 75 NG PL F04 TK, RR 1962 delivery methods in addition PNM Santa Fe Unit 1, Santa Fe, NM ST 5 5 MG PL F02 TK 1949 to trucking.

PNM Santa Fe Unit 2, Santa Fe, NM ST 6 6 NG PL F02 TK 1949 PNN San Juan Unit 1, Waterflow, NM ST 314 314 BIT TK None 1976 San Juan 1 s 2 ownership.

PNM San Juan Unit 2, Waterflow, NM ST 306 306 BIT TK None 1973 PNM 50%< TGE 50%

Units rerated in 1978.

SCIP Coolidge Dam (2), Gila, Co., AZ 10 10 WAT SRP Crosscut (1), Tempe, AZ WAT Water supply not dependable for full 2 MW.

SRP Horse Mesa (1), Salt River, AZ PS 96 96 WAT SRP Horse Mesa (3), Salt River, AZ HY 33 30 WAT SRP Mormon Flat (1), Salt River, AZ PS 44 44 WAT SRP Mormon Flat (1), Salt River, AZ HY 10 10 WAT SRP Roosevelt (1), Salt River, AZ HY 36 36 WAT SRP Stewart Mtn (1), Salt River, AZ HY 13 0 WAT Agua Fria 1, Glendale, AZ ST 109 111 F06 TK, RR NG PL 1958 SRP SRP SRP Agua Fria 2, Glendale, AZ Agua Fria 3, Glendale, AZ ST ST 109 180 111 182 F06 F06 TK, RR TK, RR NG MG PL PL 1957 1961 PRC SRP Agua Fria 4, Glendale, AZ GT 66 69 F02 TK,RR,PL None 1975 APER SRP Agua Fria 5, Glendale, AZ GT 66 69 F02 TK,RR,PL None 1974 SRP 8RP Agua Fria 6, Glendale, AZ Crosscut, Tempe, AZ GT ST 66 32 69 32 F02 F02 TK,RR,PL TK,RR,PL None NG PL 1974 1941 Four 8 MW units CARD SRP Kyrene 1, Tempe, AZ ST 34 34 F02 TK, RR, PL NG PL 1952 SRP Kyrene 2, Tempe, AZ ST 70 70 F02 TK,RR,PL NG PL 1954 SRP Kyrene GT 3, Tempe, AZ GT 48 60 F02 TK,RR,PL NG PL 1972 SRP Kyrene GT 4, Tempe, AZ GT 48 60 F02 TK,RR,PL MG PL 1971 SRP Kyrene GT 5, Tempe, AZ GT 42 53 F02 TK,RR,PL NG PL 1973 SRP Kyrene GT 6, Tempe, AZ GT 42 53 F02 TK,RR,PL NG PL 1973 SRP Navajo 1, Page, AZ ST 750 750 SUB RR,TK None 1974 Navajo 1, 2, 3 ownership:

SRP Navajo 2, Page, AZ ST 750 750 SUB RR,TK None 1975 SRP 21 7% USBR 24 3%+ LDWP SRP Navajo 3, Page, AZ ST 750 750 SUB RR,TK None 1976 21 2% APS 14%g NEVP 11 3%~

TGE 7.5%.

1.1-195/196 Blank

PVNGS ER-OL ARIZONA NEW MEXICO POWER AREA NEED FOR POWER Thermal Plant Name, Unit No., New Capability Thermal Table 1.1-9 Location (MW) Primary Fuel Alternate Fuel Unit WESTERN SYSTEMS COORDINATING COUNCIL Hydro Plant Name (No. of Units) Unit Fuel Delivery Fuel Delivery Commercial EXISTING GENERATION CAPABILITY Org. Location Type Summer Winter Type Methods Type Methods Operation Comments AS OF JANUARY 1, 1979 SRP San Tan 1, Gilbert, AZ CW 24 26 WH 1974 Sheet 4 of 11 SRP San Tan 1, Gilbert, AZ CT 48 52 F02 TK,RR,PL None 1974 ARIZONA NEW MEXICO POWER AREA SRP San Tan 2, Gilbert, AZ CW 24 26 WH 1974 SRP San Tan 2, Gilbert, AZ CT 48 52 F02 TK,RR,PL None 1974 (Page 4 of 4)

SRP San Tan 3, Gilbert, AZ CW 24 26 WH 1974 SRP San Tan 3, Gilbert, AZ CT 48 52 F02 TK,RR,PL None 1974 SRP San Tan 4, Gilbert, AZ CW 24 26 WH 1975 SRP San Tan 4, Gilbert, AZ CT 48 52 F02 TK,RR,PL None 1975 TGE Demoss Petrie 1, Tucson, AZ ST 15 15 F06 RR,TK NG PL 1949 TGE Demoss Petrie 2, Tucson, AZ ST 13 13 F06 RR,TK NG PL 1949 TGE Demoss Petrie 3, Tucson, AZ ST 24 24 F06 RR,TK NG PL 1953 TGE Demoss Petrie 4, Tucson, AZ ST 46 46 F06 RR,TK NG PL 1954 TGE Demoss Petrie GT 1, Tucson, AZ GT 47 47 F02 RR,TK,PL NG PL 1973 TGE Irvington 1, Tucson, AZ ST 81 81 F06 RR,TK,PL NG PL 1958 TGE Irvington 2, Tucson, AZ ST 81 81 F06 RR~TK,PL NG PL 1960 TGE Irvington 3, Tucson, AZ ST 104 104 F06 RR,TK,PL NG PL 1962 TGE Irvington 4, Tucson, AZ ST 156 156 F06 RR,TK,PL NG PL 1967 TGE Irvington GT 1, Tucson, AZ GT 24 24 F02 RR,TK,PL NG PL 1972 TGE Irvington GT 2, Tucson, AZ GT 25 25 F02 RR,TK,PL NG PL 1972 TGE Irvington GT 3, Tucson, AZ GT 25 25 F02 RR,TK,PL NG PL 1973 TGE North Loop GT 1, Marana, AZ GT 25 25 F02 TK NG PL 1972 TGE North Loop GT 2, Marana, AZ GT 25 25 F02 TK NG PL 1972 TGE North Loop GT 3, Marana, AZ GT 23 23 F02 TK NG PL 1972 TGE North Loop GT 4, Marana, AZ GT 25 25 F02 TK NG PL 1973 USLC Davis (5), Bullhead City, AZ Hoover A3 a A4 (2), Boulder City, 268 268 WAT Revised operating limit USLC NV 165 165 WAT operated by LDWP for Arizona Power Authority USLC Parker (4), Parker, AZ HY 104 104 Operated by USBR; USBR-52 MW, MWD-52 MW USSW Elephant Butte (3), T. or C. NM 15 15 PRC APERTURE caaD g~c %~M~ xsE 1.1-197/198 Blank

PVNGS ER-OL SOUTHERN CALIFORNIA NEVADA POWER AREA NEED FOR POWER Thermal Plant Name, Unit No., Net Capability Table 1.1-9 Location (MW) Primary Fuel Alternate Fuel Thermal Hydro Plant Name (No. of Units)

Unit WESTERN SYSTEMS COORDINATING COUNCIL Unit Fuel Delivery Fuel Delivery Commercial Org. Location Type Summer Winter Type Methods EXISTING GENERATION CAPABILITY Type Methods Operation Comments AS OF JANUARY 1, 1979 BURB Magnolia 3, Burbank, CA ST 21 21 F06 TK NG PL 1949 Sheet 6 of 11 BURB Magnolia 4, Burbank, CA ST 28 28 F06 TK NG PL 1953 BURB Magnolia 5, Burbank, CA GT 22 22 TK NG PL 1970 SOUTHERN CALIFORNIA NEVADA POWER AREA BURB Olive 1, Burbank, CA ST 46 46 F06 TK NG PL 1959 (Page 1 of 6)

BURB Olive 2, Burbank, CA ST 53 53 F06 TK NG PL 1964 BURB Olive 3, Burbank, CA GT 24 24 JF TK NG PL 1974 BURB Olive 4, Burbank, CA GT 31 31 JF TK NG PL 1976 CDWR Devil Canyon (2), San Bernardino, CA 120 120 WAT GLEN Grayson 1, Glendale, CA CW 11 11 WH 1941 GLEN Grayson 2, Glendale, CA CW 12 12 WH 1947 GLEN Grayson 3, Glendale, CA ST 21 21 F06 TK NG PL 1953 GLEN Grayson 4, Glendale, CA ST 47 47 F06 TK NG PL 1959 GLEN Grayson 5, Glendale, CA ST 49 49 F06 TK NG PL 1964 GLEN Grayson 6, Glendale, CA GT 23 23 F02 TK NG PL 1972 GLEN Grayson 7, Glendale, CA GT 30 30 F02 TK NG PL 1975 GLEN Grayson 8, Glendale, CA CT 75 75 F02 TK NG PL 1977 LDWP Aqueduct (12), Saugus, CA 74 74 San Francisqui o 1 s, 2, San Fernando, Foothill, Castaic (7), Castaic, CA and Franklin power plants LDWP PS 1247 1247 WAT LDWP Hoover (8), Boulder City, NV HY 755 755 WAT 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.

LDWP Owens Gorge (3), Bishop, CA 110 110 WAT Owens Valley (7), Big Pine, CA LDWP 9 9 WAT Haiwee, Cottonwood, Division Creek, Big Pine and PRC Pleasant Valley power plants LDWP Harbor Harbor 1, Wilmington, CA ST 72 72 F06 TK, PL,WA NG PL 1944 APERTURE LDWP 2, Wilmington, CA ST 67 67 F06 TK, PL ~WA NG PL 1948 LDWP Harbor Harbor 3, Wilmington, Wilmington, CA ST 86 86 F06 TK, PL,WA NG PL 1949 CARD LDWP 4, CA ST 86 86 F06 TK~PL,WA NG PL 1949 LDWP Harbor 5, Wilmington, CA ST 87 87 F06 TK,PL,WA NG PL 1949 LDWP Harbor 6, Wilmington, CA GT 19 19 F02 TK,PL NG PL 1972 LDWP Harbor 7, Wilmington, CA GT 19 19 F02 TK,PL NG PL 1972 LDWP Harbor 8, Wilmington, CA GT 19 19 F02 TK~PL NG PL 1972 LDWP Harbor 9, Wilmington, CA GT 19 19 F02 TK,PL NG PL 1972 1.1-201/202 Blank

PVNGS ER-OL NEED FOR POWER SOUTHERN CALIFORNIA NEVADA POWER AREA Thermal Plant Name,. Unit No., Net Capability Thermal Table 1.1-9 Location (MW) Primary Fuel Alternate Fuel Unit WESTERN SYSTEMS COORDINATING COUNCIL Hydro Plant Name (No. of Units) Unit Fuel Delivery Fuel Delivery Commercial EXISTING GENERATION CAPABILITY Org. Location Type Summer Winter Type Methods Type Methods Operation Comments AS OF JANUARY 1, 1979 LDWP Haynes 1, Long Beach, CA ST 222 222 F06 TK, PL,WA NG PL 1962 Sheet 7 of 11 LDWP Haynes 2, Long Beach, CA ST 232 23 2 F06 TK,PL,WA NG PL 1963 220 220 F06 TK,PL,WA 1964 SOUTHERN CALIFORNIA NEVADA POWER AREA LDWP Haynes 3, Long Beach, CA ST NG PL LDWP Haynes 4, Long Beach, CA ST 227 227 F06 TK,PL,WA NG PL 1964 (Page 2 of 6)

LDWP Haynes 5, Long Beach, CA ST 344 344 F06 TK,PL,WA NG PL 1966 LDWP Haynes 6, Long Beach, CA ST 344 344 F06 TK,PL,WA NG PL 1967 LDWP Scattergood 1, Playa del Rey, CA ST 179 179 F06 TK,PL NG PL 1958 LDWP Scattergood 2, Playa del Rey, CA ST 17. 9 179 F06 TK,PL NG PL 1959 LDWP Scattergood 3, Playa del Rey, CA ST 284 284 NG PL None 1974 LDWP Valley 1, Sun Valley, CA ST 94 94 F06 TK, RR NG PL 1954 LDWP Valley 2, Sun Valley, CA ST 101 101 F06 TK, RR NG PL 1954 LDWP Valley 3, Sun Valley, CA ST 171 171 F06 TK, RR NG PL 1955 LDWP Valley 4, Sun Valley, CA ST 160 160 F06 TK, RR NG PL 1956 Hoover (3), Boulder City, NV HY 261 261 Units N5, N6, and N7 owned by USBR and operated by LDWP NEVP Clark 1, Las Vegas, NV ST 48 48 NG PL F06 TK 1955 NEVP Clark 2, Las Vegas, NV ST 72 72 NG PL F06 TK 1956 NEVP Clark 3, Las Vegas, NV ST 73 73 NG PL F02 TK 1961 NEVP Clark 4, Las Vegas, NV GT 59 59 NG PL F02 TK 1973 NEVP Reid Gardner 1, Moapa, NV ST 110 110 BIT RR F02 TK, RR 1965 NEVP Reid Gardner 2, Moapa, NV ST 110 110 BIT RR F02 TK, RR 1968 NEVP Reid Gardner 3, Moapa, NV ST 110 110 BIT RR F02 TK, RR 1976 NEVP Sunrise 1, Las Vegas, NV ST 83 83 NG PL F06 TK, RR 1964 NEVP Sunrise 2, Las Vegas, NV GT 69 69 NG PL F02 TK 1974 NEVP Westside Diesels, Las Vegas, NV IC 30 30 F02 TK None 1963 PASA PASA Azusa Dam (1), Azusa, Broadway 1, Pasadena, CA CA HY ST 45 2

45 2 WAT F06 TK NG PL 1954 PRC PASA PASA Broadway 2, Pasadena, Broadway 3, Pasadena, CA CA ST ST 45 71 45 71 F06 F06 TK TK NG NG PL PL 1957 1965 APERTURE PASA Glenarm 8, Pasadena, CA ST 14 14 F06 TK NG PL 1932 PASA Glenarm 9, Pasadena, CA ST 45 45 F06 TK NG PL 1949 CARD PASA Glenarm 1, Pasadena, CA GT 26 26 F02 TK NG PL 1976 PASA Glenarm 2, Pasadena, CA GT 26 26 F02 TK NG PL 1976 1.1-203/204 Blank N

PVNGS ER-OL SOUTHERN CALIFORNIA NEVADA POWER AREA NEED FOR POWER Thermal Plant Name, Unit No., New Capability Table 1.1-9 Location (MW) Primary Fuel Alternate Fuel Thermal Unit WESTERN SYSTEMS COORDINATING COUNCIL Hydro Plant Name (No. of Units) Unit Fuel Delivery Fuel Delivery Commercial Org. Location Type Winter EXISTING GENERATION CAPABILITY Summer Type Methods Type Methods Operation Comments AS OF JANUARY 1, 1979 SCE Median Year Adjustment -41 -82 Edison does not have summer/

winter median year capacity Sheet 8 of 11 data by plants as individual SOUTHERN CALIFORNIA NEVADA POWER AREA plant capacity varies in (Page 3 of 6) response to maintenance sched-ules and water diversions.

Nameplate ratings are SCE Big Creek No. 1 (4), Big Creek, CA reported.

HY 81 81 WAT SCE Big Creek No. 2 (4), Big Creek, CA HY 66 66 WAT SCE Big Creek No. 2A (2), Big Creek, CA HY 96 96 WAT 8CE Big Creek No. 3 (4), Big Creek, CA HY 138 138 WAT SCE Big Creek No. 4 (2), Big Creek, CA HY 91 91 WAT SCE Big Creek No. 8 (2), Big Creek, CA HY 58 58 WAT SCE Bishop Creek No.2 (3), Bishop, CA HY 7 7 WAT SCE Bishop Creek No.3 (3), Bishop, CA HY 8 8 WAT SCE Bishop Creek No.4 (5), Bishop, CA HY 8 8 WAT SCE Bishop Creek No.5 (2), Bishop, CA HY 4 4 WAT SCE Bishop Creek No.6 (1), Bishop, CA HY 2 2 WAT SCE Borel (3), Kernville, CA HY 10 10 WAT SCE Fontana (2), San Bernardino, CA HY 2 2 WAT SCE Hoover (4), Boulder City, NV HY 331 331 WAT A5 95MWg A6 95MWf A7 95MW~

A8-46NW. Units owned by USBR and operated by SCE SCE Kaweah No.l (1), Three Rivers, CA HY 2 2 WAT SCE Kaweah No.2 (1), Three Rivers, CA HY 2 2 WAT SCE Kaweah No.3 (2), Three Rivers, CA HY 4 4 WAT SCE Kern R. 1 (4), Bakersfield, CA HY 25 25 WAT SCE Kern R. 3 (2), Bakersfield, CA HY 36 36 WAT SCE Lower Tule (2), Springville, CA HY SCE SCE Lundy (2), Lee Vining, CA Lytle Cr. (2), San Bernardino, CA HY HY 2

3 1

2 3

1 WAT WAT WAT PRC SCE SCE Mammoth Pool (2), Big Creek, CA Mill Creek No.l (1), Redlands, CA HY HY 150 1

150 1

WAT WAT APERTURE SCE Mill Creek No.2 (1), Redlands, CA HY 1 1 WAT CARD SCE Mill Creek No.3 (3), Redlands, CA HY 2 2 WAT SCE Ontario No.l (3), Ontario, CA HY 1 1 WAT SCE Ontario No.2 (1), Ontario, CA HY 1 1 WAT SCE Pool (1), Lee Vining, CA HY 10 19 WAT SCE Portal (1), Big Creek, CA HY 10 10 WAT SCE Rush Creek (2), Lee Vining, CA HY 10 10 WAT SCE San Gorgonio No.l (1),Banning, CA HY 1 1 WAT 1.1-205/206 Blank

PVNGS ER-OL SOUTHERN CALIFORNIA NEVADA POWER AREA NEED FOR POWER Capability Table 1.1-9 Thermal Plant Name, Unit No., New Thermal Location (MW) Primary Fuel Alternate Fuel Unit WESTERN SYSTEMS COORDINATING COUNCIL Hydro Plant Name (No. of Units) Unit Fuel Delivery Fuel Delivery Commercial EXISTING GENERATION CAPABILITY Org. Location Type Summer Winter Type Methods Type Methods Operation Comments AS OF JANUARY 1, 1979 SCE San Gorgonio No. 2 (1), Banning, CA HY 1 1 WAT Sheet 9 of 11 SCE Santa Ana No. 1 (4), Redlands, CA HY 4 4 WAT SOUTHERN CALIFORNIA NEVADA POWER AREA SCE Santa Ana No.2 (2), Redlands, CA HY 1 1 WAT SCE Santa Ana No.3 (1), Redlands, CA HY 2 2 WAT (Page 4 of 6)

SCE Sierra (2), Ontario, CA HY 1 1 WAT SCE Alamitos 1, Long Beach, CA ST 175 175 F04 PL NG PL 1956 SCE Alamitos 2, Long Beach, CA ST 175 175 F04 PL NG PL 1957 SCE Alamitos 3, Long Beach, CA ST 320 320 F04 PL NG PL 1961 SCE Alamitos 4, Long Beach, CA ST 320 320 F04 PL NG PL 1962 SCE Alamitos 5, Long Beach, CA ST 480 480 F04 PL NG PL 1966 SCE Alamitos 6, Long Beach, CA ST 480 480 F04 PL NG PL 1966 SCE Alamitos 7, Long Beach, CA GT 121 121 F02 TK NG PL 1969 SCE Cool Water 1, Dagget,'A ST 65 65 F04 TK NO PL 1961 SCE Cool Water 2, Dagget, CA ST 81 81 F04 TK NG PL 1964 SCE Cool Water 3 CC, Dagget, CA CT 120 120 F02 TK NG PL 1978 Two 60MW Units SCE Cool Water 3 CC, Dagget, CA CA 60 60 F02 TK NG PL 1978 SCE Cool Water 4 CC, Dagget, CA CT 120 120 F02 TK NG PL 1978 Two 60MW Units SCE Cool Water 4 CC, Dagget, CA CA 60 60 F02 TK NG PL 1978 SCE Ellwood 1, Santa Barbara, CA GT 54 54 F02 TK NG PL 1974 SCE El Segundo 1, El Segundo, CA ST 175 175 F04 PL NG PL 1955 SCE El Segundo 2, El Segundo, CA ST 175 175 F04 PL NG PL 1956 SCE El Segundo 3, El Segundo, CA ST 335 335 F04 PL NG PL 1964 SCE El Segundo 4, El Segundo, CA ST 335 335 F04 PL NG PL 1965 SCE Etiwanda 1, Etiwanda, CA ST 132 132 F04 PL NG PL 1953 SCE Etiwanda 2, Etiwanda, CA ST 132 132 F04 PL NG PL 1953 SCE Etiwanda 3, Etiwanda, CA ST 320 320 F04 PL NG PL 1963 SCE Etiwanda 4, Etiwanda, CA ST 320 320 F04 PL NG PL 1963 SCE Etiwanda 5, Etiwanda, CA GT 121 121 F02 TK NG PL 1969 SCE Garden State 1, Pomona, CA GT 12 12 F02 TK NG PL 1967 SCE Highgrove 1, Colton, CA ST 32 32 F04 TK NG PL 1952 SCE SCE Highgrove 2, Colton, CA Highgrove 3, Colton, CA ST ST 33 44 33 44 F04 F04 TK TK NG NG PL PL 1952 1953 PRO SCE SCE Highgrove 4, Colton, CA Huntington Beach 1, Hunt. Bch, CA ST ST 45 215 45 215 F04 F04 TK PL,WA NG NG PL PL 1955 1958 APERTURE SCE Huntington Beach 2, Hunt. Bch, CA ST 215 215 F04 PL,WA NG PL 1958 CARD SCE Huntington Beach 3, Hunt. Bch, CA ST 215 215 F04 PL,WA NG PL 1961 SCE Huntington Beach 4, Hunt. Bch, CA ST 225 225 F04 PL,WA NG PL 1961 SCE Huntington Beach 5, 'Hunt. Bch, CA GT 121 121 F02 TK NG PL 1969 SCE Long Beach 8 CC, Long Beach, CA CT 200 200 F02 TK NG PL 1976 Four 50MW Units SCE Long Beach 8 CC, Long Beach, CA CW 79 82 WH 1976 SCE Long Beach 9 CC, Long Beach, CA CT 150 150 F02 TK NG 1977 Three 50MW Units SCE Long Beach 9 CC, Long Beach, CA CW 60 60 WH 1977 1.1-207/208 Blank

PVNGS ER-OL NEED FOR POWER SOUTHERN CALIFORNIA NEVADA POWER AREA Thermal Plant Name, Unit No., New Capability Table 1.1-9 Location (MW) Primary Fuel Alternate Fuel Thermal Unit WESTERN SYSTEMS COORDINATING COUNCIL Hydro Plant Name (No. of Unrts) Unit Fuel Delivery Fuel Delivery Commercial EXISTING GENERATION CAPABILITY Org. Location Type Summer Winter Type Methods Type Methods Operation Comments AS OF JANUARY 1, 1979 SCE Long Beach 10, Long Beach, CA ST 106 106 F04 PL,WA NG PL 1928 Sheet 10 of 11 SCE Long Beach 11, Long Beach, CA ST 50 50 F04 PL,WA NG PL 1930 SCE Mandalay 1, Oxnard, CA ST 215 215 F04 WA NG PL 1959 SOUTHERN CALIFORNIA NEVADA POWER AREA SCE Mandalay 2, Oxnard, CA HT 215 215 F04 WA NG PL 1959 (Page 5 of 6)

SCE Mandalay 3, Oxnard, CA GT 121 121 F02 TK NG PL 1970 SCE Mohave 1, Lauflin, NV ST 790 790 BIT PL NG PL 1971 Mohave i&2 Ownership:

SCE Mohave 2, Lauflin, NV ST 790 790 BIT PL NG PL 1971 SCE 56%, LDWP 20%, NEVP 14%,

SRP 10%. Coal is delivered by slurry pipeline.

SCE Ormond Beach 1, Oxnard, CA ST 750 750 F04 WA NG PL 1971 SCE Ormond Beach 2, Oxnard, CA ST 750 750 F04 WA NG PL 1973 SCE Redondo Beach 1 Redondo Bch, CA ST 74 74 F04 PL NG PL 1948 SCE Redondo Beach 2 Redondo Bch, CA ST 74 74 F04 PL NG PL 1948 SCE Redondo Beach 3 Redondo Bch, CA ST 70 70 F04 PL NG PL 1949 SCE Redondo Beach 4 Redondo Bch, CA ST 74 74 F04 PL NG PL 1949 SCE Redondo Beach 5 Redondo Bch, CA ST 175 175 F04 PL NG PL 1954 SCE Redondo Beach 6 Redondo Bch, CA ST 175 175 F04 PL NG PL 1957 SCE Redondo Beach 7 Redondo Bch, CA ST 480 480 F04 PL NG PL 1967 SCE Redondo Beach 8 Redondo Bch, CA ST 480 480 F04 PL NG PL 1967 SCE San Bernardino 1, San Bern., CA ST 63 63 F04 TK NG PL 1957 SCE San Bernardino 2, San Bern., CA ST 63 63 F04 TK NG PL 1958 SCE San Onofre 1, S an Clemente, CA NP 436 436 UR 1968 Ownership: 80% SCE, 20%

EDGE SDGE Division GT 1, San Diego, CA GT 16 20 F02 TK NONE 1968 SDGE El Cajon GT 1, El Cajon, CA GT 17 21 F02 TK NG PL 1968 SDGE Encina 1, Carlsbad, CA ST 100 100 F06 WA NG PL 1954 SDGE Encina 2, Carlsbad, CA ST 102 102 F06 WA NG PL 1956 SDGE Encina 3, Carlsbad, CA ST 102 102 F06 WA NG PL 1958 SDGE Encina 4, Carlsbad, CA ST 287 287 F06 WA NG PL 1973 EDGE Encina 5, Carlsbad, CA ST 320 320 F06 WA NONE 1978 SDGE Encina GT 1, Carlsbad, CA GT 16 20 F02 TK NG PL 1968 EDGE Kearny GT 1, San Diego, CA GT 17 21 F02 TK NG PL 1972 EDGE Kearny GT 2(ABCD), San Diego, CA GT 65 81 F02 TK NG PL 1969 EDGE EDGE Kearny GT 3(ABCD), San Diego, CA Miramar GT 1(AB), San Diego, CA GT GT 65 38 81 46 F02 F02 TK TK NG NG PL PL 1969 1972 PRC SDGE EDGE Naval Station GT 1, San Diego, CA North Island GT 1, Coronado, CA GT GT 25 21 32 23 F02 F02 TK TK NONE NONE 1976 1972 APERTURE(

EDGE EDGE North Island GT 2, Coronado, CA NTC GT 1, San Diego, CA GT GT 20 16 23 20 F02 F02 TK TK NONE NG PL 1972 1968 CARD EDGE Silver Gate 1, San Diego, CA ST 38 38 F02 PL NG PL 1943 EDGE Silver Gate 2, San Diego, CA ST 64 64 F02 PL NG PL 1948 EDGE Silver Gate 3, San Diego, CA ST 64 64 F02 PL NG PL 1950 1.1-209/210 Blank

PVNGS ER-OL NEED FOR POWER SOUTHERN CALIFORNIA NEVADA POWER AREA Capability Table 1.1-9 Thermal Plant Name, Unit No., New Thermal Location (MW) Primary Fuel Alternate Fuel Unit WESTERN SYSTEMS COORDINATING COUNCIL Hydro Plant Name (No. of Units) Unit Fuel Delivery Fuel Delivery Commercial EXISTING GENERATION CAPABILITY Org. Location Type Summer Winter Type Methods Type Methods Operation Comments AS OF JANUARY 1, 1979 SDGE Silver Gate 4, San Diego, CA ST 64 64 F02 PL NG PL 1952 Sheet 11 of 11 BDGE South Bay 1, Chula Vista, CA ST 140 140 F06 WA NG PL 1960 SOUTHERN CALIFORNIA NEVADA POWER AREA SDGE South Bay 2, Chula Vista, CA ST 142 142 F06 WA NG 1962 SDGE South Bay 3, Chula Vista, CA ST 198 198 F06 WA NG PL 1964 (Page 6 of 6)

SDGE South Bay 4, Chula Vista, CA ST 220 220 F06 WA NG PL 1971 SDGE South Bay GT 1, Chula Vista, CA GT 18 22 JF TK None 1966 SDGE Station B, San Diego, CA ST 87 87 F02 PL NG PL 1941 Header plant with 4 main turbogenerators and 1 house turbogenerator. Capability shown is boiler limited SNEV Stauffer Chemical, Henderson, NV ST 10 10 NG PL F02 TK,RR 1970 SNEV Stauffer Chemical, Henderson, NV GT 15 15 NG PL F02 TK,RR 1970 PRC APERTURE CARD 1.1-211/212 Blank

PVNGS ER OL NEED FOR POWER ARIZONA NEW MEXICO POWER AREA Net Capability Primary Fuel Commercial Table 1.1-10 (MW)

Alt. Operation Date WESTERN SYSTEMS COORDINATING COUNCIL Unit Fuel Deliv. Fuel Org. Plant Name, Unit No., Location Type Summer Winter Type Method Type Prev. New Date Stat Comments

SUMMARY

OF GENERATION ADDITIONS Sheet 1 of 5 AEPC Apache 2, Cochise AZ ST 175 175 SUB RR,TK None 6-78 Yes 1 79 E Testing delay. ARIZONA NEW MEXICO POWER AREA IID Brawley GT 1, Brawley CA GT 2 FO2 TK None 1 79 D Capability change summer only IID Brawley GT 2, Brawley CA GT 2 FO2 TK None 1 79 D Capability change summer only (Page 1 of 2)

IID Magma GEO 1, Holtville CA GE 10 10 GST PL 4 79 G IID will purchase and sell KWH of plant SCE Axis GT 1, Yuma AZ GT 22 22 FO2 TK NG 4-79 No 4-79 G SCE Main system 4-1-81 AEPC Apache 3, Cochise AZ ST 175 175 SUB RR,TK None 4-79 No 4-79 G SRP Coronado 1, St. Johns AZ ST 350 350 SUB RR None 4-79 Yes 6 79 G Participation unit until 5-82, SRP 70%, LDWP 30%

IID Rockwood GT 1, Brawley CA GT 20 20 FO2 TK None 6-79 No 6 79 T PNM San Juan 3, Waterflow NM ST 480 480 BIT TK None 5-79 Yes 11-79 G Joint project; PNM 50% and TGE 50'4 PNM Prager 7&8, Albuquerque NM ST 11 11 NG PL FO2 5-79 Yes 11-79 R Retiring 2 units SRP Coronado 2, St. Johns AZ ST 350 350 SUB RR None 4-80 No 4 80 T Participation unit until 5-82, SRP 70%, LDWP 30%

EPE Copper Station 1, El Paso TX GT 73 73 FO2 PL NG 5-80 No 5-80 P APS Cholla 3, Joseph City AZ ST 242 242 SUB RR, TK None 6-79 Yes 6-80 G Reduced load forecast IID Geothermal 1, CA GE 50 50 GST 6-80 No 6-80 P Plant site is undetermined IID Rockwood GT 2, Brawley CA GT 20 20 FO2 TK None 6-80 No 6-80 P APS Cholla 4, Joseph City AZ ST 347 347 SUB RR, TK None 6 80 Yes 6-81 G Reduced load forecast.

PNM San Juan 3, Waterflow NM ST -12 12 BIT TK None 5-81 Yes 5-82 D Addition of SO2 equipment PNM San Juan 4, Waterflow NM ST 472 472 BIT TK None 5-81 Yes 5-82 T Unit will come on-line with S02 equipment PNM Prager 9, Albuquerque NM ST -11 -11 NG PL FO2 5-81 Yes 5-82 R Retiring 1 unit APS Palo Verde 1, Wintersburg AZ NP 1270 1270 UR None 5 82 No 5-82 T Participation: APS 29.1%

SCE 15.8%, SRP 23.4%, LDWP 5.7%, EPE 15.8%, & PNM 10.2%

APS Four Corners 4, Farmington NM ST 15 15 SUB RR,TK None 7-82 No 7-82 D Scrubber derating APS Four Corners 5, Farmington NM ST 15 -15 SUB RR,TK None 1-83 No 1-83 D Scrubber derating PEGT Combustion Turbine, NM GT 50 50 FO2 TK None 5-83 P APS Undetermined, AZ GT 50 50 FO2 RR,TK None 5-83 P Peaking unit IID Geothermal 2, CA GE 50 50 GST 6-83 No 6-83 P Plant site is undetermined EPE Rio Grande 1&2, near El Paso TX ST 26 -26 FO2 TK, RR NG 5-83 Yes 1-84 R Retiring 2 units PEGT APS Escalante 1, Pruit NM Palo Verde 2, Wintersburg AZ ST NP 210 1270 210 1270 BIT UR RR None None 5-84 No 5-84 5-84 P

T Participation: APS 29.1%

PRG SCE 5

15.8%,

7%~ EPE SRP 15 23.4%,

8%~ &

LDWP PNM 10 2%

gppp,JURE APS Undetermined, AZ GT 50 50 FO2 RR,TK None 5-85 Peaking unit CARD APS Undetermined, AZ GT 50 50 FO2 RR,TK None 5-85 Peaking unit 1.1-213/214 Blank

PVNGS ER-OL ARIZONA NEW MEXICO POWER AREA NEED FOR POWER Net Capability Primary Fuel Alt. Commercial Table 1.1-10 Unit (MW)

Fuel Deliv. Fuel Operation Date WESTERN SYSTEMS COORDINATING COUNCIL Org. Plant Name, Unit No., Location Type Summer Winter Type Method Type Prev. New Date Stat Comments

SUMMARY

OF GENERATION ADDITIONS TGE Springerville 1, AZ ST 330 330 SUB RR NONE 5-85 NO 5-85 T Sheet 2 of 5 APS Palo Verde 3, Wintersburg, AZ NP 1,270 1,270 UR NONE 5-85 NO 5-85 T Participation: APS 29.1%, ARIZONA NEW MEXICO POWER AREA SCE 15.8%, SRP 23.4%, LDWP 5.7%, EPE 15.8%, & PNM 10.2%

(Page 2 of 2)

IID Geothermal 3, CA GE 50 50 GST 6-86 NO 6-86 P Plant site is undetermined PNM Santa Fe 1&2, Santa Fe, NM ST 11 11 NG PL FO2 5-86 YES 10-86 R Retiring 2 units PNM Pumped Storage Plant, NM PS 300 300 WAT 5-85 YES 5-87 P Location, Number and size of units not yet determined TGE Springerville 2, AZ ST 330 330 SUB RR NONE 6 87 P PNM New Mexico Station, Bisti, NM ST 472 472 BIT TK NONE 5-83 YES 5-88 P Joint Project-50% PNM, 15.7%

EPE & 34.3% not allocated PNM Person 1&2, Albuquerque, NM ST -36 36 NG PL F02 5-88 R Retiring 2 units PNM Pumped Storage Plant, NM PS 300 300 WAT 5-88 P Planned addition PEGT Escalante 2, Pruit, NM ST 210 210 BIT RR NONE 5-88 P APS Palo Verde 4, Wintersburg, AZ NP 1,270 1,270 UR NONE 5 88 K 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%.

IID Geothermal 4, CA GE 50 50 GST PL 6-88 P Plant site is undetermined PRC APER CARD 1.1-215/216 Blank

PVNGS ER-OL SOUTHERN CALIFORNIA NEVADA POWER AREA NEED FOR POWER Net Capability Primary Fuel Commercial Table 1.1-10 (MW)

Alt. Operation Date Unit Fuel Deliv. Fuel WESTERN SYSTEMS COORDINATING COUNCIL Org. Plant Name, Unit No., Location TYpe Summer Winter Type Method Type Prev. New Date Stat Comments ADDITIONS

SUMMARY

OF GENERATION PASA Glenarm 8, Pasadena, CA ST 14 -14 F06 TK NG 7-78 YES 1-7 9 M Retire from service Sheet 3 of 5 MWD Greg Ave 1, Burbank, CA HY 1 1 WAT 10-78 YES 4-79 T Conduit Hydro, nameplate NEVADA POWER AREA SOUTHERN CALIFORNIA rating SCE Cool Water 3CC, Dagget, CA CT +54 +69 F02 TK NG 6-79 A (Page 1 of 3)

SCE Cool Water 4CC, Dagget, CA CT +54 +69 F02 TK NG 6 79 A SCE Long Beach SCC, Long Beach, CA CT +31 +38 F02 TK NG 6-78 YES 6-7 9 A Rerate of GT portion SCE Long Beach 9CC, Long Beach, CA CT +22 +27 F02 TK NG 6 78 YES 6-79 A Rerate of GT portion NEVP Clark 5, Las Vegas, NV GT 70 70 NG PL F02 6-79 NO 6-7 9 G NEVP Clark 6, Las Vegas, NV GT 70 70 NG PL F02 6-79 NO 6-7 9 G SCE Long Beach No.ll, Long Beach, CA ST +56 +56 F06 PL NG 1-79 YES 7-79 A Rerate unit from 50MW to 106MW SCE Big Creek 3 Unit 5, Big Creek, CA HY 31 31 WAT 3-80 NO 3-80 MWD Lake Mathews 1, Arlington, CA HY 5 5 WAT 3-80 NO 3-80 Conduit Hydro, nameplate rating SCE Co-Generation, CA zz 24 24 WH 6-80 MWD Foothill FDR 1, L.A., CA HY 5 5 WAT 7-80 YES 6-80 Conduit Hydro, nameplate rating MWD Foothill FDR 2, L.A., CA HY WAT 7 80 YES 6-80 P Conduit Hydro, nameplate rating NEVP Clark 7, Las Vegas, NV GT 70 70 NG PL F02 6 80 NO 6-80 K Formerly Sunrise 3 SCE San Onofre 2, San Clemente, CA NP 220 220 UR 10-80 NO 10-80 G Operation 20% of full power Ownership: 80% SCE, 20% SDGE San Dimas 1, La Verne, CA HY 10 10 WAT 11-80 YES 10-80 P Conduit Hydro, nameplate rating Yorba Linda FDR 1,Yorba Linda, CA HY WAT 3-81 YES 2-81 P Conduit Hydro, nameplate rating Sepulveda Canyon 1, L.A., CA HY WAT 5-81 NO 5-81 P Conduit Hydro, nameplate rating SCE Co-Generation, CA zz 4 4 WH 6 81 P NEVP Clark 8, Las Vegas, NV GT 70 70 NG PL F02 6 81 NO 6-81 K Formerly Sunrise 4 MWD Venice 1, Culver City, CA HY 10 10 WAT 9-81 NO 9-81 P Conduit Hydro, nameplate rating SCE San Onofre 2, San Clemente, CA NP +880 +880 UR 10-81 10-81 Unit rerated to full Temescal, Corona, 11-81 NO 11-81 P

capability 1100MW PRC NR CA HY WAT NO P Conduit Hydro, nameplate SCE San Onofre 3, San Clemente, CA NP 220 220 UR NONE 1 82 NO 1-82 G rating formerly L Feeder A 1 Operation 20% of full power APERTURE CDWR Pyramid 2, Caswell, CA HY 38 38 WAT 1-82 NO 1 82 P ownership: 80% SCE, 20% SDGE Calif. State Water Project CARD Recovery Plant CDWR Pyramid 1, Caswell, CA HY 38 38 WAT 10-81 YES 3-82 L Calif. State Water Project Recovery Plant Corona, NR Corona, CA HY WAT 3-82 NO 3-82 P Conduit Hydro, nameplate rating formerly L Feeder B 1 SCE Co-Generation, CA zz WH 9 81 YES 6-82 P 1.1-217/218 Blank

PVNGS ER-OL NEED FOR POWER SOUTHERN CALIFORNIA NEVADA POWER AREA Table 1.1-10 Net Capabilrty Primary Fuel Alt. Commercial (MW) Operation Date WESTERN SYSTEMS COORDINATING COUNCIL Unit Fuel Deliv. Fuel Org. Plant Name, Unit No., Location Type Summer Winter Type Method Type Prev. New Date Stat. Comments

SUMMARY

OF GENERATION ADDITIONS Sheet 4 of 5 CDWR Cottonwood 1, Los Angeles Co., CA HY 15 15 WAT 9-81 YES 9-82 Calif State Water Project Recovery Plant SOUTHERN CALIFORNIA NEVADA POWER AREA MWD Santiago CR 1, Orange, CA HY 3 WAT 6-82 YES 11-82 Conduit Hydro, nameplate (Page 2 of 3) rating SCE San Onofre 3, San Clemente, CA NP +880 +880 UR NONE 1-83 NO 1-83 Unit rerated to full capability 1100MW Rio Hondo 1, Southgate, CA HY 2 WAT 11-82 YES 3-83 Conduit Hydro, nameplate rating SCE Wind 1, CA WM 4 4 WND 1-86 YES 6 83 Expected capacity 1MW SCE Co-Generation, CA zz 5 5 WH 6 83 NEVP Warner Valley 1, St. George, UT ST 250 250 BIT RR NONE 6 83 NO 6 83 Joint Project: NEVP 25%

PG&E 25%, SCE 25%,

uncommitted 25%.

NEVP Reid Gardner 4, Moapa, NV ST 250 250 BIT RR F02 6-83 K SCE Fuel Cell 1, CA FC 26 26 UNK XX 7-83 NO 7-83 P Fifteen 26MW fuel cells are under consideration for use at various locations not yet determined fuel undetermined.

MWD Covina 1, Covina, CA HY 3 WAT 3-83 YES 7-83 Conduit Hydro, nameplate rating Coyote CR 1, La Habra, CA HY 3 WAT 7-83 YES 11-83 Conduit Hydro, nameplate rating PASA Glenarm 9, Pasadena, CA ST -45 -45 F06 TK NG 7-87 YES 1 84 M Retire from service SCE Geothermal 1, Brawley, CA GE 9 9 GST 6-84 P SCE Co-Generation, CA zz 4 4 WH 6-84 P NEVP Warner Valley 2, St. George, UT ST 250 250 BIT RR NONE 6 84 NO 6 84 P Joint project: NEVP 25%,

PG&E 25% ~ SCE 25%

uncommitted 25%.

LDWP Scattergood 3, Playa Del Rey, CA ST +176 +176 F06 TK NG 6-84 Convert existing natural gas unit to oil-burning capability BURB Magnolia 3, Burbank, CA ST 21 21 F06 TK NG 10-84 Retire from service SCE Combined Cycle GT 1-9, LUC VY, CA GT 540 549 F02 TK NONE 6-85 NO 6-85 Various combustion and steam turbines during 1981 1987.

A total of 1290MW in 3 430MW PRC combined cycle units.

SCE Balsam Meadow Hydro, CA HY 140 140 6-85 6 85 Formerly Hydro SCE Co-Generation, CA zz 4 4 WAT WH NO 6 85 APERTURE NEVP Allen 1, Las Vegas, NV ST 500 500 BIT RR NONE 6 85 NO 6-85 Joint project: NEVP 8%,

PG&E 46%, SCE 46%. CARD SCE Fuel Cells 2&3, CA FC 52 52 UNK XX 5 86 NO 5 86 See comments for fuel cell 1 SCE Combined Cycle CC-ST, LUC VY, CA CA 130 133 F06 TK NONE 6 86 NO 6-86 Portion of combined cycle unit 1.1-219/220 Blank

PVNGS ER OL NEED FOR POWER SOUTHERN CALIFORNIA NEVADA POWER AREA Net Capabilrty Primary Fuel Commercial Table 1.1-10 (MW)

Alt. Operation Date WESTERN SYSTEMS COORDINATING COUNCIL Unit Fuel Deliv. Fuel Org. Plant Name, Unit No., Location Type Summer Winter Type Method Type Prev. New Date Stat Comments

SUMMARY

OF GENERATION ADDITIONS Sheet 5 of 5 SCE Combined Cycle GT, Lucerne Vy, CA GT -300 305 F02 TK NONE 6-86 NO 6 86 P Convert to combined cycle SOUTHERN CALIFORNIA NEVADA POWER AREA SCE Combined Cycle GT 10-12,LUC V, CA GT 180 183 F02 TK NONE 6 86 NO 6-86 P SCE Wind 2, CA WM 6 6 WND 1 87 YES 6 86 P Expected capacity 2MW. (Page 3 of 3)

SCE Combined Cycle CT, Lucerne Vy, CA CT 300 305 F02 TK NONE 6-86 NO 6 86 P SCE Geothermal 2, Niland, CA GE 54 54 GST 6 86 P SCE Geothermal 3, Heber, CA GE 45 45 GST 6 86 P Replaces previous geothermal SCE Co-Generation, CA ZZ 4 4 WH 6-86 P NEVP Allen 2, Las Vegas, NV ST 500 500 BIT RR NONE 6-86 NO 6 86 P Joint project: NEVP 8%,

PG&E 46%, SCE 46%.

LDWP Intermountain 1, Millard Co., UT ST 750 750 BIT RR NONE 10-86 YES 7 86 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%.

SCE Fuel Cells 4&5, CA FC 52 52 UNK XX 1 87 YES 5-87 See comments for fuel cell 1 SCE Wind 3, CA WM 15 15 WND 6 87 Expected capacity 5MW.

SCE Combined Cycle CC-ST, LUC Vy, CA CA 260 266 F06 TK NONE 6-87 NO 6-87 Portion of combined cycle unit SCE Combined Cycle CT, Lucerne Vy, CA GT 180 183 F02 TK NONE 6 87 NO 6 87 P SCE Combined Cycle GT, Lucerne Vy, CA GT -600 -610 F02 TK NONE 6 86 NO 6-87 P Convert to combined cycle unit SCE Combined Cycle CT, Lucerne Vy, CA CT 600 610 F02 TK NONE 6-87 NO 6 87 P SCE Combustion Turbine 1-2, CA GT 110 110 F02 TK NONE 6 87 NO 6-87 P SCE Co-Generation, CA ZZ 4 4 WH 6 87 P SCE Calif Coal 1, CA ST 250 250 BIT RR NONE 6-87 P NEVP Allen 3, Las Vegas, NV ST 500 500 BIT RR NONE 6-87 NO 6-87 P Joint project: NEVP 8%,

PG&E 46%, SCE 46%.

LDWP Intermountain 2, Millard Co., UT ST 750 750 BIT RR NONE 10-87 YES 7-87 P 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%.

SCE Fuel Cells 6-9, CA FC 104 104 UNK XX 5-88 See comments for fuel cell 1 PRC SCE Wind 4, CA WM 30 30 WND 6 88 Expected capacity 10MW.

Co-generation, 6-88 SCE SCE Calif.

CA Coal 2, CA Allen 4, Las Vegas, ZZ ST 250 4 4 250 WH BIT RR NONE 6 88 APERTUpp NEVP NV ST 500 500 BIT RR NONE 6-88 Joxnt pro3ect: NEVP 8%, --.- CARD PG&E 46%, SCE 46%.

LDWP Intermountain 3, Millard Co., UT ST 750 750 BIT RR NONE 7-88 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.

GLEN Grayson 3, Glendale, CA ST 21 -21 F06 TK NG 7 88 M Retire from service BURB Magnolia 4, Burbank, CA ST 28 -28 F06 TK NG 10-88 M Retire from service 1.1-221/222 Blank

EXPLANATION LITHOLOGI DESCRIPTIONS A. UPPER ALLUVIAL UNIT SITE SITE SILTY AHD GRAVELLY SANDS, WITH SOME SILTS AHO CLAYS (LZ-5)

BOUHDARY BOUHOARY SOUTH NORTH B. IIIIDDLE FINE GRAINED UNIT (AOUITARD)

I 12OO 1200 I CJ CJI I

44 JJ I CJ 44 '4J i I4 44 i i I UPPER ZONE: SILTY CLAYS WITH SOME SILTS AND SILT'Y SAHDS (LZ-4)

I C CJ 44 44 CJ CI 1000 IOOO I LOWER ZONE: PALO VERDE CLAY (LZ-3) 000 800 ~ C. LOWER COARSE GRAINED UNIT UJ ll \4 SILTY SANO SANO AHO GRAVELLY SANO (LZ 2) 600 600 I

FAHGLOMERATE (LZ-I) 400 400 VOLCANIC FLOWS ANO FLOW BRECCIA 200 4 CJ 4~ ~

200 44 4 CJ4 BRECCIA CC 4

"'.,-I I I-IJI./ ',il I I-I I/C I cl ./,Ic/,-Il I TUFFACEOUS AHD ARKOSIC SAHDSTOME TUFF D. BASEMENT COMPLEX SCALE I

/4/ /4

/ I GRAHITIC AHD METAMORPHIC ROCKS PRC HORIZOHTAL:

I" =

I" 2000'ERTICAL APERTURE

=400'ERTICAL EXAGGERATIOH: 5X WATER LEVELS MARCH 1979 CARD EXAGGERATED. PERCHEO WATER ZONE HOTE: DIP OF VOLCANIC FLOW BEDDING IS HOT REGIONAL AQUIFER Palo Verde Nuclear Generating Station ER-OL GENERALIZED HYDROGEOLOGIC CROSS-SECTION OF THE SITE Figure 2.4-1

800 800 I

YIELD: 2,460 m 3-2-69 YIELD: 2,700 gpm 7-22-53 YIELD: 880 gpm 9-13-61 YIELD: 2,000 gpm 7-22-53 780 2,840 gpm 7-13-53 1,360 gpm 8-6-68 1,250 gpm 8-10-61 780 760 760 I 140 740 I UJ IU 720 720 700 700 UJ UJ 680 680 IRRIGATION WELL IRRIGATION WELL IRRIGATION WELL 660 IRRIGATION WELL 660 (C-1-6) 14dbb (C-1-6) 18bbb (C-1-6) 21cbb2 (8-1-6) 27ddc 640 640 860 860 YIELD: 1,950 gpm 7-13-55 YI ELD: 3, 490 gpm 7-20-49 840 840 1,360 gpm 8-09-61 2,260 gpm 8-05-68 PRC 820 820 APERTURE 800 800 CARD I I UJ UJ UJ UJ 180 780 760 760 UJ UJ NOTE:

740 740 WELL DATA PRIOR TO 1973 TAKEN FROM BTULIK WATER-LEVEL DATA AFTER 1973 OBTAINED BY FUGRO, INC.

IRRIGATION WELL UNUSED WELL IRRIGATION WELL 720 720 (8-1-6) 20dbb (8-1-6) 26baa (8-1-6) 34abb BORING PV-7 Palo Verde Nuclear Generating Station 700 700 ER-OL HYDROGRAPHS OF DEEP WELLS IN THE SITE AREA Figure 2.4-6

$ 1$ $ 3$

$$ 9

$$ 2 soe $ 1$

eso eae 7-

=7 77

$ 7$ eoe I 1 4

$$2 eoe sle eoo $ $$

$ 73 ese $ $8 I12 ess $$2

$ 7O

$9 ~ $$ $

see PV-14H PV 21H PV 22H ese 4$ 2 4II 17

>>>>t! I!18!9 li! I et! f till ili 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 9! I I t!!I I 3 1 il 4$ $

asses!!tie!a edict!a!I!sita!tet!t!13!t 1878 1$ 75 sf! ! 913 197$

1$ 71 7

93! I et! 2318!3 ! .*I 3 9!! t I 197$

3 e 8 I! I I! t I e

197$

1 3 I 9 32 9 et! ! tie!a 1$ 73 3 st 9 t!!tle ise I Isle 9 et! ! tls! I! est!! ! lait 3! tet! ! tla i 1$ 75 3

Idle 1411 3 3 e I 3 t! ttl as i 1113 3 e 9 2 t! t t la is 1$ 'ls 1$ 73 1$ 11 1$ 75 187$ 1$ 77 1$ 1$ 191$ 1$ 13

$ 1$

$ 3$

PRC eoe

$ 2$

APERTURE

$$$ $ 28 HOTES:

CARD Vi ON SITE IRRIGATION CEASED SEPTEMBER, IG75.

eoe $ 23 V WELL RESPOHSE TO FLUSHING.

IRRIGATIOH WELL B-1-6-34acc, LOCATEO AT A DISTANCE OF 214'ROM

$ 2$

PV-24H AHD JJ MILE FROM PV-25H, WAS SEALEO BY GROUTING IH JULY IB76. THE SUODEH RISE IH THE MEASURED WATER LEVELS soo S le INDICATES THAT THESE WELLS WERE LOCATED WITHIN THE COHE OF DEPRESSIOH CAUSED BY PERCHEO WATER CASCADING THROUGH THE

$ 1$

IRRIGATION WELL.

ese su 3$ 1 $ 12 Palo Verde Nuclear Generating Station ER-OL PV-24H -. P V-2 5H

$$ 2 $ 1$

HYDROGRAPHS OF OBSERVATION WELLS IN THE PERCHED-WATER ZONE II4 sssetlstlsis 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!! 18 I! I I!

2 9 tl 3 2 3 1 8! 8 3! I 3 t '! 31 8 I 3

$ $4 I! set! !ale ta I! !ef!! alia!Ill!1st! 2318131! set! 3!lease! I et!!3!assai!! I!!!Iie! 1!!et!ttlieii 3 (Sheet 1 of 5)

Isla ten 1$ 71 197$ 1$ 1$

Fioture 2.4-7 1$ 73 1$ 7 ~ 1$ 75 IS7$ 1$ 77 1$ 7$ 191$ 1913 1315

124 920 070 914 02 ~ 010 022 922 91 ~

910 920 912

, 1 IL 910 070 Lie 110 L', 916 I '.I-L 000 sn 01 ~ soe 1.7.

012 912 004 810 910 001 PV-28H PV-29H PV-30H a00 008 000 PRC 0a0 I 2 6 3 I lt I I 1013 8 I ll I 4 I 3 I l 2 I I 8 I !I I 1 I I I lS 1014 1975 1 l8 I il iciefltllale 12 I ellis!'3 6182 I 1970 1977 1 I 2I 1

1070 li I!I 1979 040 1 2 I 1 f .'f la I 1973 8

1074t 1075 1976 1 2 I 3 I 3 1071 Ill li I i! I 8 I 3 I l 2 I lii I it 1910 4 I 5 Il 2 2 lI I I 1979 000 I 4 I 3 I l 2 I I 8 I I 1 I I 1 f 2 f I t I I it I 4 I 5 I ! 8 I ls I I I 2 I 3 I l I I l 8 I it 3 I I 1013 1974 1015 1018 3 8 I 8 1077 I I i I I I 3 I l 2 I tt 3 I I II 8 1070 8 .' 3 I l 2 S I li I I 107S APERTURE CARD 001 110 104 01e 000 00 ~

00 ~ NOTES:

01 ~

V OH SITE IRRIGATION CEASED SEPTEMBER, IOTB.

011 00e V CYCLIC SEASONAL VARIATIONS REFLECT RECHARGE 900 FROM SEDIMENTATIOH BASIN LOCATED NEAR THE 014 00 ~ CEHTER OF THE SITE. ALL SURFACE RUNOFF 090 WITHIN THE NORTHERN HALF OF THE SITE IS LS COLLECTED IN THE REGIMENTATION BASIN.

090 eoe 090 09 ~

90 ~ 00e 092 902 + 00e TE =+ Palo Verde Nuclear Generating Station Soa

- PV-31H 090 PV-33H '-; e04 PV-34H ER-OL I

000 HYDROGRAPHS OF OBSERVATION WELLS

'57 001 18 lillt lail I 4 t if st lie>> I 3 I ia I tll ii citillf1ltiiia*'cliffltiaiii fiif.'tfllia a II 1 I .' 2 tt 8 II 0

3 4>> I l t ll 4 III 4>> S I 3 II8 III c>>tent! Ie I I 8 4 416 '1 flail !esesltrlall c 1 I 1 I l 2 I I I!I 1

001 iciifltelats 8 2 I 3 I l 2 I tt I I I ! I 6 I l 2 8 2 tt 3 I II 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 iciialtflail IN THE PERCHED-WATER ZONE of 1973 7974 1975 1976 1977 1970 7018 1973 1974 1075 1976 1977 1010 1970 1073 1014 1075 7070 1077 1110 1019 (Sheet 2 5)

Figtize 2.4-7

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I 04 ~ 022 NOTES:

902 020 V OH SITE IRRIGATION CEASED SEPTEMBER, 1975, 400 920 910 Y OBSERVATIOH WELL CEHTER OF UNIT U3-PTW-I, LOCATED NEAR THE 3, WAS ABANDONED IM OCTOBER 1977

+

BECAUSE OF THE POWER BLOCK EXCAVATION. MONITORING ne 420 970 OF WATER LEVELS IN THE AREA WAS CONTINUED IN WELL PV-O3, INSTALLED AT THE EDGE OF THE EXCAVATION IN soe 418 018 JANUARY 1979. THE STEEP DECLINE OF VJATER LEVELS OBSERVED IH PV-93 REFLECTS THE LOCALIZED EFFECT eea 922 SI 2 PRC'pppYURF. OF DEWATERING IN THE EXCAVATION.

442 020 970 CARD 0$ 0 Palo Verde Nuclear Generattng Station

=

910 400 ER-OL PV-TR-1 PV-TR- U3-PTW-1 eee 910 988 HYDROGRAFHS OF OBSERVATION WELLS I IN THE PERCHED-WATER ZONE 044 8>> a 8 l! 2 2 a i2 I i2 t1 t2 l8 a a 2 I! l 2 t t 2!i 2 i 21 1 a t 2 S l 1 2 l S a 2 ef ~

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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 I

flow 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 LITHOLOGIC LITHOLOGIC MAGNETIC MAGNETIC MAGNETIC TIME SCALE MAP SYMBOLS UNIT AGE THICKNESS LOCATION DESCRIPTION WORLDWIDE PALEOMAGNETIC TIME SCALE SYMBOL POLARITY ZONE anterpretation for Pab Verdo area)

LZ 6 Brown gravel in a loose to medium dense silt Period Epoch Age Event Qsu Holocene- 8 to l5 North and '0' 0 '.'

Young Fan and sand matrix, poorly sorted moderately stratified Pleistocene feet east of site Deposits Volcanic, granitic, and metamorphic clasts. o)

R) O ol o p v h C: c0 oo-:

QTb Arlington Basalt Flow 2 ill.y.

(Best K-Ar date) 5 to 200.

feet (estimate)

Arlington Dark gray, hard, slightly porphyritic olivine basalt.

.. ~ 'o.,'

1 ('1 IO

)

Rial LZ-5 UN CONFORMITY Brown, medium dense silty sand and gravel; MZ 5 Matuyama Rl ~ 0.69 "Upper" Sand and Gravel 2m y. Up to 50 feet Palo Verde basin predominantly quartz sand with volcanic gravel; weathered mica common; localy calcareous

' ' Epoch C

0)

O O

~

~ 0.87 0.92 Jaramillo PARACONFORMITY )h Rl Palo Verde Brown, medium dense to dense silt and clayey Q.

'50 basin and silt with generally minor interbedded fine 2.imam.y.

LZ-4 > 2m.y. to 200 Reversal O south and scattered Designation R IO E sand; fine weathered mica common; Upper Silt to 2.8m.y. feet southeast toward local calcareous cement; coarse sand and O

O

~ l.7l

~ I.60 MZ-4 L-IO Horizon Arling ton gravel paleosols locally at base of unit. Series of developed near upper contact. Gauss Epoch;;

~ I.86 Olduvai PARACONFORMITY MZ 2.8m.y. ~2.00 Reunion Central part of R 8 IO Reversal LZ 3 2.8 m.y. 20 to I36 'I P.V..basin and Red-brown, very stiff, calcareous, silty Des nation 5.08m.y.

')

Palo Verde Cia at top feet south and south clay; interbedded clastic wedges near west QTbf

-east toward edge. of basin.Paleosols devebped at upper Arlington contact.

MZ 2 LZ 2 Central part of Brown to red-brown, stiff to very stiff, Lower Silt ) 3m'. 20 to 97 I P.V. basin 8 sout ~?.90 Kaena feet and southeast toward Arlington sandy and clayey silt, locally grading sand and gravel at base of unit.

to

~ 3.00 3 085 Mammoth MZ-I -3.5. m.y.?

C IOto 4

Lower 3m.y. 30'eet Palo Verde Brown, dense, silty and clayey sand and R.... o~,o.': v 4)

V basin gravel of volcanic origin, poorly sorted. Gitbert, O Sand 8 Gravel UNCONFORMITY Epach?

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Note:

a Tvfn In dura te d m.y. 35 to 285 Palo Verde erate composed of volcanic ciasts derived from e m ~ 3.82 Cochitl Fanglomerate (K<r date of int

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v

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>Not exposed in MAJOR UNCONFORMITY site area

'V iI- Palo Verde Nuclear Generating Station Grdnitic and Palo Verde Granite, granitic gneiss and metamor- i rI

//~ ER-OL Metamorphic Precambrian Unknown Hills phosed volcanic and sedimentary Basement Subsurface vi-rocks. $ iv V 1) STRATZGRAPHTC CHART OF SITE AREA g i Si V I'r- Figure 2.5-3

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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 ARCHAEOLOGICAL 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 and the State Historic Preservation Officer indicate 'ibrary, 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

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.

2. 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)

Nearest Reclamation Cooling Nearest Transformer Water Direction Tower Unit (Switchboard) Pumps N 1.2 1.4 1.8 0.9 NNE 1.7 1.8 2.1 1.2 NE 1.8 1.9 2.1 1.3 ENE 2.7 2.7 2.7 2.4 E 3.3 3.2 3.0 3.1 ESE 3.7 3.5 3.2 3.6 SE SSE 4.0 3.9 3.6 4.5 3.7 3.7 3.7 4.7 SSW 2.9 2.9 3.2 4.1 SW 3.6 3.7 4.0 4.8 WSW NW '.0 2.2 2.3 2.4 2.6 2.8 2.1 2.0 March 1981 Supplement 2 2~7 2

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PVNGS ER-OL APPENDIX 2A RESPONSES TO NRC UESTIONS

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PVNGS ER-OL TABLE OF CONTENTS P acute ll Question 2A.1 (NRC comment. on section 2. 1. 2. 3) (6/18/80) 2A-1 Question 2A.2 (NRC comment on section 2. 3) (6/18/80) 2A-1 Question 2A.3 (NRC comment on section 2. 3) (6/18/80) 2A-3 Question 2A.4 (NRC No. 291.15) 2A-3 Question 2A.5 (NRC No. 291.16) 2A-4 Question 2A.6 (NRC No. 310.3) 2A-4 Question 2A:7 (NRC No. 310.4) 2A-4 Question 2A.8 (NRC No. 310.5) 2A-5 Question 2A.9 (NRC No. 310.6) 2A-6 Question 2A.10 (NRC No. 311.1) 2A-6 Question 2A.ll (NRC No. 311.2) 2A-7 Question 2A.12 (NRC No. 311.3) 2A-8 Question 2A.13 (NRC No. 311.4) 2A-9 Question 2A.14 (NRC No. 311. 5) 2A-9 Question 2A.15 (NRC No. 450. 1) 2A-10 March 1981 2A-i Supplement 2

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PVNGS ER-OL ll * (

School children should be included

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in table 2.1-3.

RESPONSE: The response is given in revised section 2.1.2.3 and table 2.1-3.

l( (6/18/80) 2.3

(

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 (6/18/80) 2,.3 No monthly mixing height data.

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 in the Environmental Report - Construction Permit 'rovided Stage (ER-CP) for Units 1-3 and the ER-CP for Units 4-5. In all dispersion calculations o Z was constrained to values less II 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 .

City of Phoenix, Arizona, Interim 1985 Plan.

5. 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 30-40 20 - 30 0-5 N NNE ESE SE SE SSE NW NNW CP-1970 0 2698 125 0 OL-1978 3397 358 0 174 CP-1980 0 4261 955 0 534 0 197 0 OL-1980 3623 381 0 916 0 502 0 186 II CP-1990 0 6291 1439 0 788 0 291 0 OL-1990 4621 187 0 1168 0 640 0 237 CP-2000 0 8682 1986 0 1088 0 402 0 OL-2000 5935 625 0 1500 0 822 0 304 CP-2010 0 11983 2741 0 1501 0 555 0 OL-2010 7622 803, 0 1927 0 1055 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 (a) . Section 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

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5]<<]4 5 )'20 ~ 5 DIRECT]Ok) ~ 5 ~ 14 ~ 75 1 ~ 5 1 ~ 51 ? ~ 5 2 ~ 5] 3 5 3 ~ 5] " b 4

~ Sf<<b 5 S ~ 5]<<n ~

'5 6 ~ '51 8 ~5 8 ~ 51<<11 ~ '5 11 ~ ~ 5 14 ~ 51~20 ~ I (/1 AL

<<i( f.S PER k!Ok;fl ti 7 ]49 385 So9 bh9 S]u 2vS 113 107 45 25 1 Zu54 6 118 337 SVH S85 44t) 295 8 115 6$ 27 I 2799 kE 5 94 3') 5 068 575 299 ]9$ ]75 105 39 54 2 1!I I E~E ?35 359 $ )9 2$ v flu lb2 Il 39 9 ]HS1 E 12 ] uk) 27/ a3? II 4 6 3'b 7 26a 38k) Sk)4  ? 7'b f92 S3 $ 170 HS 3(h ubZ anH 38u 27I) $ 45 zs'5 57 28 10 27u1 ESE 5 Sl 1! 7 3l 5 a<<4 Sn] S55 )91 225 11 24 ]7 8 zu17 SSE '5 77 350 55k) 278 2)3 159 H] ju $0 lu 1922 S 9 9)! 31 t) 545 455 399 29V 2hb ]63 84 /3 12 2 lab SS<< 4 9b 254 347 552 3ob 212 488 ba3 25$ 244 nb 52uu 8>> 4 85 21 l zoo 524 SS7 da2 1151 75o b95 /7 495o kI8 Y 4 HV 2SS 21? 2bu Phn 224 bo< 529 411 215 Zb S39b 7 Hf 20u 2$ 0 2]fk 2oo 19o 39'b 4$ 2 189 113 12 2219

'<< kyle 5 71! ]b3 175 142 130 1v5 199 2S5 f49 ]63 45 lb9$

be 6 92 2S8 262 )bj 165 94 lu7 145 140 ]29 $8 1640 Pl,<< 4 113 3vn 572 304 220 114 14'5 12S 74 73 10 1861 0 0 0 0 0 u 0 0 0 VA>IASLE 0 0 0 40801

'T ',! T A L S 94 la98 439o 6076 5658 aab7 3450 4956 4965 2683 2000 3ab 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 I) E F 7 '~ 6 ~ 6A F 97 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 SfaBILITy CLass) . 4 ELEdlfI(lN) i?00 FEET pFLTa T ( Zunian ~ 35 ~ 0) FEEf OI RECT IDN ~ 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

<)LES PEN tttiVN N n 0 T 0 4 1 8 6 3 28 ttwE 0 -n 1 4 -S 5 6 lt '

6 4

'4 0 40 NE. V n 2 1 2 2 2 4 0 8 40 EtlE 0 0 2 4 -.7 10 7 11 12 13 70 E n 1' 0 5. 11 6 tu 22 31 72 52 )P9 ESE n 1 4 13 11 )5 51 23 27 11 .4 130 SE 0 2 )5 12 21 '5 13 -8 3 0 l)6 ssE 0 0 '

7 13 )2 15 26 lf 3 0 150 3 0 2 7

.7 ll7 27 47 46 46 124 26 29 9 212 SSH 0 0 6 17 103 11P . 59 46P 3>> 0 0 ~ I 5 14 12 65 162 t74 253 82 768 h$ h 0 .-

0 1 3 13 18 77 74 . 78 23 293 0 0 1 3 4 ) El 41 42 42 1'6 172 QHh 0 0 9 1 -2 2 2 7 fO 10 37 24 99 Nh 0 0 1 1 1 5 5 12 21 71 NNH 0 1 1 1 1 . 2 1 5 7 20 l6 7.2 V<RI >t)LE 0 n 0 0 ,0 0 0 0 0 .0 TnfaLS 0 3 f4 57 91 101 155 344 599 556 725 2)5 2018 PERI(>f)3 QF CALNS Hl)(IR3 DIRECTION STAHILITy CLASS)

ELEvlll)UNT Zuu FEET 5 ~ 74 ~ 75~) ~ 5 ),5)~2 ' 2 '1 l)FLTA 3 ' 3 ')

T ( 200 4 5 4

' ~

'1 5

'3')

' '1 5 FEET 6 ' 6 51 8 5 8 51 11 ~ 5 11 51 14 ' 14 51 i?0 5 >2' ruriL

<ILES PF.R H()UN N 0 1 3 2 6 7 7 1 53 NWE 1 1 5 5 t) ll 6 5 6 1 42 NE 6  ? 7 f4 10 9 5 6 .0 61 ENE 3 )4 )6 7 19 19 9 13 3 105 iE )5 13 10 17 en bS 57 Of 14 289 ESE 0 25 28 SS 5) )4 4 2 2i? 3 SE ¹ 15 29 34 35 4¹ )9 1 3 190 SSF. 20 57 Iln 32 25 4 1 177 S 15 22 i?3 51 61 i? 6 7 5 251

.SSh ln Zt 25 -b7 V9 55 25 3)9

.-Sr 7 17 i?5 6V 9¹ 86 04 Zf 410 W 3 I>> 2 6 9 18 29 64 64 20 )0 251 2 2 9 Tu 17 )2 30 i?3 8 154 Wtsh 2 ) 6 4 11 f¹ 27 P 7P Ha 2 5 5 6 1 5 11 47 t4 flH 2 ) 5 & 9 8 ¹ 48 VaRIAt)LE n 0 0 0 4 iJ 0 0 V 0 T(iT AL3 fuh ) ti9 259 PHP ¹nN ibZ 396 Suv luS 263'9 PER)t>n3 l)F ('h('is n. Nfl'tNS

81AHTI.TTv r(.aSSI .C DIRECT lfill ELE<raiTUNI 200 FEE I l)ELLA I ( ZVO ~ 0 <<35 ~ 0)

I ~ 51<<? ~ 5 2 ~ '51<<5 ~ 5 3 ~ 5l 4 ~ ) 4 ~ 51<<5 ~ 5 5 ~ 51 FEI T 6<') 6 ~ 51<<8 ~ 5 8 ~ 51 5(<<14

~ 5 ~ 74 ~ 75<<1 ~ 5 11 ~ 5 11 ~ ~ S 14 ~ 51<<20 ~ 5 )Zv ~ 5 T(ITAL l<lLl$ PF.R l< I <UN N I 5 4 0 7 1 5 2 1 2 39 IIhE 0 5 3 H 8 5 5 0 47 F<8 6 13 18 12 10 4 5 4 2 75 EIIF. n 1

ll 15 2U 18 2?. L5 64 10 3 1<?4 E n 7 i? 4 33 32 37 65 SH 28 10 338 ESE 2  ? ZL 4$ 54 <IU 47 Sl 14 9 3 Zde SE 0 0 25 37 31 35 49 lS 5 3 2 Z15 SSE 0 28 31'3 47 3U 51 15 2 2 1 215 8

SSN 0

n 5

6 27 9 22 35 40 32 31 42 63 29 bo 24 ll 25 15 1 ?22 295 SN 0 14 lv 28 ?4 73 lU5 63 55 ZL 397 NSN 0 4 lv lb 42 57 40 25 lo 215 1 3 8 13 12 20 17 21 120 NNN 0 3 6 2 6 11 15 13 27 9 92 0 1 5 7 2 16 17 8 9 69 NNN n 1 7 6 3 6 6 10 2 45 YARTASLE 0 0 0 0 0 0 0 0 0 T(IT AL8 5 53 187 282 363 .312 518 467 257 238 94 2716 PER 1 IIDS DF C AL ~:s 0 HI3UIIS DlRECl Jr>> ~

S I

%- ~ 74 AB1LT lT CLASS L ELEVATIIIII

.75 1 ~ 5 PVO FEET L,SL-'2.5 0

DELTA T ( Zvo ~ 0 << 35 ') FEET 2 ~ 51<<3 ~ 5 3 ~ 51<<4 ~ 5 4 ~ 51 5 ~ 5 5 F 51<<6 ' 6 ~ 51<<e ~ 5 8 ~ 51 11 ~ 5 11 ~ 5'I<<14 ~ 5 14 ~ 51<<20 ~ 5 >20 ~ 5 TUTAL HILLS PER H(I(IR N 0 6 25 27 1'1 IS 10 h 5 LS 2 136 NNE 2 26 25 31 16 11 21 9 13 6 2o5

. NE, 2 5 ?i? 63 51 Zv Sh ZL 14 9 13 302 ENF 2 7 35 eo 94 h3 46 $6 bL 29 Zd 18 507 E S 8 58 'I 21 1ZH 'I ZS 98 (34 LS7 0S 77 <?0 Loop ESE 7. 11 79 LUO 133 H9 76 121 88 SZ 21 lv 766 SE 2 I7 78 LLO 1?4 111 85 dv 37 lb 10 6 660 SSE 1 L7 75 Lvb lv5 79 51 42 ZZ 9 7 13 522 8 U 8 62 Lvh 1 Ia 08 79 62 S5 28 Sb Sn 658 SSN 0 13 53 'I V5 80 99 51 03 lvo 69 87 1'U5 870 S<< v SS 56 Hl 73 lv5 19a 15S ?52 LS2 1165 NSN 0 6 25 40 4<3 4U Th lvb 08 107 SB 642 0 27 S4 av ?H ZH ab b5 64 57 S2 427 WNh 0 h lv 20 13 lb 1H Sd S6 22 64 65 315 h<< 0 5 I i? 21 15 L1 12 lh 19 13 27 24 181 hNN vARTAHI.E 0 15 21 18 lv 0 le 0

ll 10 11 9 LSb 0

0 <I n n v <) 0 0 7<IT AL8 la 121 644 LVVO LUTU v5( 1 LH 91Fl 0>S h<<4 817 5$ 2 65vo PERT(IDS l<F CAL<:8 5 i<DI<RS

STA(if(.f )Y rLASS) E I LEVA t f(IIII 76(I F f f t r)FL) A I ( c?VO ~ V <<5'I ~ 'I) FF ft t) 1 RECT f()cc ~ 5 F 74 ~ 75<<1 ~ 5 I ~ 5)<<c. ~ 5 ?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 t( )AL H]LES Pf.t( Hl. VH H)IF, ~

v 1"

3 Il, ll 1 II lj 22 17

]7 ZA 9 15 12 25 13 26 -1'5 8 ?8 25 lb 6

151 fPZ HE 0 5. )0 58 52" 2~ 74 43 54 ,15 Zo lo 240 EHf. ~ 4 24 24 21. 20, 35 55 b8, 36 45. 0 349'ol E 7 6 I')I 54 42 37 29 ~ 63. ((4 7.5 26 ESF, 1 25 29 26'5 56 52 =

30 4 ?67 SE 1 6- 74 jv 20 2) 26 ]P 21 20,  ?

]8 ]8

'v7 SSE 1 2 II 2r 27 28 12 la'6 17 8 1 3cl 3? ?4 ?n *. 47,i 45 i?8 0 501,',

SS>> 1 6 3 (I'7 26 21 55 lv3 fn5 163 Sb 6 ]a 0 7 23 56 30 Sv 'I 1'5 lea 258. 431'32 145 ]315 II8W 0- 7 )9 17. 15 22 52 75 122 ]ei 55 757 aa

'7 H 0 10 14 15 21 15 16 74 1] 1 '1 14 449 HH>>" I) h lh ]5 l2 11' lu 24 cl 3 35 133 59 364 .

Hlc I 3 I] 0- 12 13 50 10 36- 03 69 302

)IHH 1 4 13 1? fa 5 12 c?0 f7 15 i?6 147 VAR]A)c(r Il 0 I) n -n 0 = 0 0 0 0 0 0 T(lt AL8 ]~ ?ol 5 7 cl jh? jhl 330 6ov 012 orS 1469 Sva 6309 PER 1(I(IS I'r q AL)"8 Ht)VRS (I) St Ae]L 1 t ~ CI. ASS t F LEVA I fll)II ?nn r F f 'I Pf L)A I ( 2I!4 ~ n 55 ~ 0) FFFT I) 1af C T]r"..5-. 7a,7S-I.S I.S) -?.5 Z ~ 5] 3 ~ ) 3 F 51<<4 ' u ~ 5) <<5 ~ 5 5 ~ Sl<<h ~ 5 51 ec5 8 51 l]IS 11 Sl 14 ~ 5 14 51 Zo 5 >i?VS 5 T()tAL II 1 I. f !l P F 4 I I I) (J 4 H v 7 25 ) 5 )7 )7 20 20 10 18 1 ]pe HHF. 7. 9 29 Zb 30 25 45 55 54 28 20 537 Hf 2 Il 20 ah 5) 70 51 76 46 17 18 1? 420 E 'lE 2 H 25 44 4 Il 5A 41 44 56 ?I 21 8 552 E 2 20 74 45 55 jh 45 Sf( hl 42 7 414 ESF 0 0 5CI Zw 26 75 42 27 fe ]1 5 250 SE I I? 23  ? II ?1 ?I 52 14 2 fbo SSE I) 9 77 I?5 72 ]h lr ]7 20 ll 4 i? ]65 ln 7)I 8

SS>>

8 II II 0

1 A

7 ?2 22 5)I 53 Sa 3(

42 40 jj

?cl 55 lan h)$

51 ra 2I)7 185 Zn 69 72 13 4

9 258 461 955 II S g 7 74 Zl 45 4 55 09 ]au t?7 3 659 7 72 ju ZS IIH Sc I ]4 'I vv 63 476 IIH>I I)H 1

0 7 lj ]8 lr 7)1 lb

.5 5 Ih

) r (9 I) 4 jl

~ IZ Sb

'I r Sh 59 76 0

7 1

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VAR) All( F.

A Il n I 5 4 I' 14

~ I c 2 (I n II 55 52 v

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4 i? 25 v

aM Tl)T ALS 17 )47 (hcl II 4 i)ra ucc ( 47u AS? I0 Scc II] I 7hh 97 Sobb PER f I I(le III Ctl .'I

0)RECT I(!'I ~ 5 STAIILLT'fY CLASS) 8 ELFVA'( TII(r) 2VV FEE T

~ 74' VEL(h 20v ~ 0 35 ') FEEI 14 I JS I ~ 5( 2 ~ 5 ? ~ Sl S ~ > 3 ~ 51"" ~ b a.b)-5.b 5 c5(~la ~ 5 6 ~ 'bl 8 ~ 5 8 ~ bf I I ~ 5 I I ~ 51 ) rl ~ 5 Iac51~20 ~ 5 >20 ~ 5 f<fAL hlLES Pt.h h( IUH Ic I 74 18 06 09 bR lav Vf 30 31 4 784 Nr(E I (I 32 74 )03 134 110 153 248 219 72 70 28 1326

'1 77 HH )51 lhf ?VH P.OS 524 2$ 7 85 48 IH 1551 ERE c i? V 01 127 134 lbl )35 184 98 25 31 2 995 F ) 28 ( VP. 103 12$ )10 7$ 116 b5 2$ 17 3 754 E RF. 3 PR 76 e0 b0 32 47 2f 13 5 I 473 SE 7 21 IJ 3 76 56 4$ Ie ?2 12 2 I 0 $$6 SSE. 7R 72 7(c Se. 53 21 17 7 0 1 31'9 8 I 20 7r( 1vl 76 50 Sl a0 22 3 0 469 SSW i? 32 HL 1L ae aH 76 $0 17 fflb Sw 2 P.3 73 7H 77 hv 44 75 b3 3i? 25 543 wSH 0 20 7R HH 60 49 75 70 37 5 0 55b w 3 24 61 73 55 42 37 60 68 32 7 0 462 wow 17 42 bv 5$ Sl 24 57 40 22 a 2 323 Hw 0 24 (JS 71 7i? 40 78 75 52 ?9 2 'bb3 tJ>JW 24 55 9) RO 67 5$ 114 99 26 2 hbS VARTARLE 0 (1 V 4 0 0 0 0 T(ITALS cl 3 397 ))9) 147S lseb fP78 1v22 1625 1199 501 310 65 ~f0498 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 2(IV ~ 0 35 ~ 0) F EE T OIRECTlevl ~ 5,1(,75 I ~ 5 I ~ '5( g,b 2,5) 5,'b m b) 4~5 4 r)LES

~ Sl 5 '

PFR hfdf!II 5 'f~bo5 6 '1~8 ~ 5 8 ~ 51 ll 5 lf

~ ~ 51 14 ' 1'1~2' >20 ~ 5 TUTAL I 41 Ia3 )9$ 151 149 120 205 lbS 71 98 28 1569 hllv E I '5 S'3 IS1 203 22I 205 221 3ab $ 43 144 La7 bl 2189'724 15 49 )55 31( 512 SHV S26 5(l3 S(0 Iab ff3 bv E IJE 9 39 ) JJV 280 S?2 SJJ4 20V SH7 SIR f42 )55 cl 7 i!b42 E )3 63 ?vg 3 rib SHS Ihb 3vb bvh 416 357 558 I c! I Sbva ESE h c(O 7)b 20h $ 56  ? cr6 2ab 575 276 )42 29 2386 SF .6 56 P.23 303 SOH P.V3 21H 2b9 I27 6$ av f4 1900 SSF 6 57 I cril 275 267 P.b I 10? 229 143 5$ 31 39 1753 S 2 71) ?15 264 Sbl c!6 I 15v 128 be 2$ 7I Sew 5 (eb 261 24(J ?67 P. I v 421 bea 442 Soe 258 $ 444 Sw )55 2$ u c!4cr c19 28$ 65$ 990 949 1318 415 b'b'b 5 wel 4 (I I rlS feu 196 ) O'J 2LH 4)4 656 62$ 574 117 -S$ 12 4 4R )21 fbv )5b 130 )54 2(9 42$ $ 96 327 18 2240 lc JJW I $6 0(J Ivj 111 Ha 84 159 2$ 1 17$ 351 L68 lbvl Nw 2 $0 ) Vg 122 124 lol 95 180 Ivh '1 7H 265 1$ 5 1553 N(c W S 57 ~

IR lb3 13) I 27. H9 10? )HI 126 )30 6S 1325 VAR)heLE (I cl IJ rl e( V 0 0 0 T(ITALS ef 77? 751H 574/ $ 29H 5" I cJ 57) 9 4164 fh/0 59696 PER)(llrS <<f ('ALrlH Rn hl JJJ(J 9

PVNGS ER-OL APPENDIX 2C Ollgf RVATIOMS I

HI IH vISSllvQ'ATA ll>Pb 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

911 911 I

Ll n

O I

910 909 TL'12 910 2 O

I 909 ~)

908 LL 908 907 907 U5-Hl 05-H2==- -:.U5-H3 U5-H4 U5-H5 U5-H6 906 t 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 I I I I I I I I I l I t I I I I I I I l I I I t t2ltllll ttt I I I I I I i II t I II I I I I I I I I I I I I I I I I I It I I I I I I I I I I I t I t I I I I li i I I I I I I I I I I I I I I IIIIIIIIIIIIIIIliillill IIIII Itltll I I I I I I I il I II I I I I I I I iI at'I l I I I I I it I it 905 77 1978 1979 1977 1978 1979 1977 9 8 1979 977 1978 1979 1977 1978 1979 1977 1978 1979 U5-H6 915 915 914 914 913 913 PRC 912 912 APERTURE I

911 911 I CARD 910 910 R

O O

~

)909 909 <)

908 908 907 907 Palo Verde ltjnclear Generating Station 606 U5-H7 U5-H6 :LjU5-H9 = -- -- '

'U5-H10 U5-H11 906 ER-OL HYDROGRAPHS OF OBSERVATION WELLS llltliitltllllltlillititttit IN THE PERCHED-WATER ZONE 905 I lt ill lic ltt I lt I I ltltfllllil 1977 1978 1979 ilill I I I I I i I I II I I II I I I I I i I I t 1977 1978 i; I I 'I I I I i I I I I I 1979

> i I i I i I I 1977

> I "

t I I t I I i I I t I t I I 1978 i I i liI it 1979 I l 111 t I t I I I I I 1977 I'Itliiiftllllltlil ill 1978 1979 977 1978 I it tl I 905 (Sheet 5 of 5) 1979 Figure 2.4-7

'-'/MTS: ..., Kr QTC Qb LEGEND QTs

-;,",,gf'I'i Qs,,.'!  :~'I . I gi...h Ka Ka ic! 69 Qb Qb Ka Kr Ki Ki 0's LITHOLOGY ia Qb Riff;;<<TA,Nlti Peoria NIX Silt, sand and gravel.

'gr ' ~sch

'r QTC QTs Basalt InCludes tuff and gravel.

Qb Lgf 94'hoenix rp ~QTS Sand, gravel and conglomerate.

vfh. Glendale as QTs gf I QTC

[QTb Basalt flow.

O Palo Verde Site o Diffsventiatml tanglomerate.

Lgf ~QT bf Sawn fill deposit.

Qb

/ /

+Tvfn Volcanic tan deposit QTs

'"an,+ Ki 0's ~Mv M/OCene Ufldlffefent/Oted volcafvcs K s O cn Ka . Mv. QTbf gf I O Undif ferentioted volcanics.

~T.v Tvfn " ','Mv vfn rt M, Andesite.

QTs K lect +/(

Ki .~gT Rll 4 sO Lgr t

Granite and related crystalline rocks.

O Qb Qs I

RIYAL)':~ ~TG.'ssI Andesite includes tuff ond agglomerate.

Qb 0 QTs u Dikes and plugs.

Tv tn 0 aTs ~v f, Rhyolite.

~QO Qb QTbf Schist includes diorite, rhyolite and greenstone.

QTC R~l QTC Qs ~9r:. Grarute and related crystalline rocks.

.:: 0's ".::.. ~, ":,:.':'.:'.::'S',,:'.:',:,':,'::,,,:':::::::'..':.:::,:::.'::;::..: Qs

.<<::::::....,:.'::::::::::::,..':,.'::.::.:,:::">>:...'.":,:': QTC GIanltIC gneisc

',Ty rt Qs" I 'r/- ',EtUCK gr Afeo sheen efl regional geologic map.

sch

/

gf SYMBOLS

/

Ki QTC Tv Fault: Dotted where concealed.

gr index Map of Anzona Dashed where interred.

QTs QTb gf QTs K QTC Geologic contact: Dashed where opprowmate.

a ca as A NORTH I

Qb gf I rl SCALE (Miles) Section Location

~ << ', I I

/

/ 0 Qb

/ gf sch Ds: I I

Reference/ Arizona Bureau of Mines mcdiriwl by Fuoro Inc.

ats gf

/

'f Palo Verde Nuclear Generating Station ER-OL QTs 'lg',

'I gr',

gr PRG t!EGIONAL GEOLOGIC HAP as'.'.::; ',Qt ',' Tv / ARICOPA - MTS: i . /gf APERTURE Figure 2.5-1

Geologic Section Across Palo Verde Site A'AST I300 1300 S ite Property I 00 II 00 Upper Sand and Gravel Indura ted Boring Boring Boring Boring Boring Fanglomerate PV- IB PV- PV-23 P V-24 PV- 25 I

900 n Silt R- IO HORIZON ~I

.'AGNETO Upper Silt aa Upper Basalt - Andestte;". rn Palo Ver e a 700 u

~ r ~~~i-'W;;.".;;; ~ .',";:

• Slit xrltn Sand and G~~~e 'oner

.; 2 t ,;::;:;;.:,';::,":; .'.:,:: .:,'::,".::;' Basalt-Andesltec; xt

'..::.t '.'.I . x-.'x ..'-'..r::;. x','v.. x. '.: r~'....'.'."., Indurated.Fantltomerattx..'r::

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;+~~ +'

A R

Mk~~,h; N

a k-"::eu 1) h

-'&INP 'P"<<~I TVzT) R N PRC I )I T. T, CPN N 0 I

)Ij)u APERTURE T

e

) CARD I

I'4

"', NBA'1,'6 0~8858YATI0 g, AIR@

.'" i 54>'

N T)L Reel/T

,'p 'i R,

uTN

'P LEGENO 0 POTENTIAL ACCESS POINTS f'R IR TR/Tuft

-- sK y.T j h,7$ Tt...a

~kg) I 1 , I r) / I pII

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NORTH 2

i

'I I

I h.

/

RNP,

"-$ 5 0 5 10 15 20 Ml Pi 'e,t 4P:.'RANSMISSION SCALE q") ':J e L Palo Verde IVuclear Generating Station ER-OL Phe 2 IT LINE ROUTE PROJECT 3 Se Figure 3.9-2 CHANGE March 1981 Supplement 2

PRC APERTURE CARD I hhld

/ 4 4

1/au 1

/,/

d I

I 4 TOLLEBON I AVOIIIDALE I-=

I 4

Id t lh W R R D

+ ,PehP

/

tc lll dm BUCKEYE CANAL TURINlIOUT PIPELINE 114 1'

.I>>

'n~..j h/

PIPE LINE 86",/ '. "',, '.. '.J 8 Ill AV E. SE WAG E TREATMENT PLANT V /4 L Y ,, ~~.- .P----" C BUG CKEYE GILA RIVER j I BASE LINE BASE LIN 4 BASE L IN I L E L R.R... , d SALT RIVER U.S. 80 Z.

LUKE AU BUCKEYE C PIE I

/1, PUMP STATION j '

'Rd PALO VERDE NUCLEAR GENERATING GTaTIDN

'I '~@~i',(Qj~9,~~i~~grQ( .

~J P

L ht*

GILARI

/ D D

r i Ch C AC I. / Palo Verde Nuclear Generating Station ER-OL Vtiwi j PVNGS PIPELINE r; MILES WATER CONVEYANCE WOW 3 4 5 0 2 Figure 3.9-5

'Q ~r ~W ) Cjrg SCALE March 1981 Su PP lement CHANGE

~CLN~~I.M"45- ( Q

PVNGS ER-OL EVALUATION OF COMPLIANCE WITH PRC APPENDIX I OF 10CFR50 AND 40CFR190 APERTURE Table 58-1 MAXIMUM INDIVIDUAL DOSES FROM CARD RADIOIODINES AND PARTICULATES (mrem/yr)

Location A Location B Dose from Unit 1 Release Dose from Unit 2 Release Dose from Unit 3 Release Dose from Unzt 1 Rele.ase Dose from Unit 2 Release Dose from Unit 3 Release Total Total Total Total Total Total Pathway Body Bone Thyroid Body Bone Thyroid Body Bone Thyroid Body Bone Thyroid Body Bone Thyroid Body Bone Thyroid Adult Ground Plane 3.28(-3) 3.28(-3) 3.28(-3) 2.65(-3) 2.65(-3) 2.65(-3) 2.32(-3) 2.32(-3) 2.32(-3) 6.82(-4) 6.82(-4) 6.82(-4) 7 79(-4) 7.79(-4) 7.79(-4) 9 01(-4) 9.01(-4) 9.01(-4)

Vegetable Ingestion 8.46(-1) 1.17 1.02 7.48(-1) 1.03 8.90(-1) 7.27(-1) 1.00 8.52(-1) 6.14(-1) 8.96(-1) 6.544(-I) 6.67(-1) 9.76(-1) 7.13(-1) 7 32(-1) 1.07 7.85(-1)

Inhalation ~1.57(-1 ~4.14 -4 ~2.82(-1 ~1.39 -1 ~3.62 -4 2~48 -1 ~1.34 -1 ~3.49 -4 ~2.40 -1 ~1.19 -1 ~2.98 -4 2.1'7(-1) ~1.30 -1 3~26 -4 ~2.29 -1 ~1. 42 -1 ) 59 -4 ) 51 -1

~3. ~2.

Total 1.01 1.17 1.31 8.90(-1) 1.03 1.14 8.63(-1) 1.00 1.09 7.34(-1) 8.97(-1) 8.65(-1) 7.98(-1) 9.77(-1) 9.43(-1) 8.75(-1) 1.07 1.04 Teenager Ground Plane 3.28(-3) 3.28(-3) 3.28(-3) 2.65(-3) 2.65(-3) 2.65(-3) 2.32(-3) 2.32(-3) 2.32(-3) 6.82(-4) 6.82(-4) 6.82(-4) 7.79(-4) 7.79(-4) 7.79(-4) 9.01(-4) 9.01(-4) 9.01(-4)

Vegetable Ingestion 1.06 1.90 1.21 9.42(-1) 1.67 1.06 9.16(-1) 1.62 1.02(-1) 7 73(-1) 1.45 8 06(-1) 8.41(-1) 1.58 8.78(-1) 9.22(-1) 1.73 9.66(-1)

Inhalation ~1.58(-1 ~5.62 -4 ~3.14(-1 ~1.39(-1 4~92 -4 ~2.75 -1 1~35 -1 4~74 -4 ~2.67 -1 ~1. 2 0 -1 ~4. 0 5 -4 ) ~2. 33 -1 ~1.31 -1) ~4.43 -4) ~2.54 -1 ~1.43 -1) 4~88 -4) ~2.79 -1 Total 1.22 1.90 1.53 1.08 1.67 1.34 1.05 1.62 1.29 8.94(-1) 1.45 1.04 9.73(-1) 1.58 1.13 1.07 1.73 1.25 Child Ground Plane 3.28(-3) 3.28(-3) 3.28(-3) 2.65(-3) 2.65(-3) 2.65(-3) 2.32(-3) 2.32(-3) 2.32(-3) 6-82(-4) 6 82(-4) 6 '2(-4) 7.79(-4) 7.79(-4) 7.79(-4) 9.01(-4) 9.01(-4) 9.01(-4)

Vegetable Ingestion 1.93 4.57 2.15 1.71 4.03 1.89 1.66 3.91 1.82 1.40 3.50 1.45 1.53 3.81 1.58 1.67 4.18 1.74 Inhalation ~1.40(-1 ~7.34 -4 ~3.16(-1 ~1.23 -1 6 43(-1) 2 78(-1) 1.20(-1) ~6.19 -4 ~2.69 -1) ~1.06 -1 ~5.29 -4 ~2.34 -1) ~1.15 -1 ~5.79 -4) ~2.56 -1 ~1.27 -1 ~6.38 -4 2~81 -1 Total 2.07 4.57 2.47 1.84 4.03 2.17 1.78 3.91 2.09 1.51 3.50 1.69 1.65 3.81 1.84 1 80 4 18 2 02 Infant Ground Plane 3.28(-3) 3.28(-3) 3.28(-3) 2.65(-3) 2.65(-3) 2.65(-3) 2.32(-3) 2.32(-3) 2-32(-3) 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)

Vegetable Ingestion (c) (c) (c) (c) (c) (c) (c) (c) (c) (c) (c) (s) (c) (c) (c) (c) (c) (c)

Inhalation 8~06 -2 ~5.37 -4 ~42 -1 ~7.09(-2 4~70 -4 ~2.12(-1 ~6.89 -2 ~4.53 -4 ~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 Total 8.39(-2) 3.82(-3) 2.45(-1) 7.36(-2) 3.12(-3) 2.15(-1) 7.12(-2) 2.77(-3) 2.07(-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.

c.

Location B Pathway not is 5500 meters applicable.

south-southwest of Unit 1, 5100 meters SSW of Unit 2 and 4700 meters SSW of Unit 3.

X%~'lmXc x%K- 1c July 1981 5B-5/5B-6 Blank Supplement 3

HVAC LINES FANS DAMPERS SUPPLEMENTAR Y INSTRUMENT EOUIPMENT R FIXTURES EOUIPMENT PROCESS PIPING LINE VALVES VALVESTATUSSYMSOLS MISCELLANEOUS[CONT) ~ IPING IDENTIFICATION DESIGNATIONS 0

2 5 -*-

DRAINS COILS AIR CLEANING DEVICES FIRE PROTECTION EOUIPMENT VALVE IDENTIFICATION t

Y MISCELLANEOUS 0

P T Qi PROJECT CLASSIFICATION 7

HUMIDIFIERS LJ 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