ML17297B014

Forwards Application for Amend to CPPR-141,CPPR-142 & CPPR-143 Permitting Transfer of El Paso Electric Co Ownership Interest to M-S-R Public Power Agency.Supporting Financial Info & Revised Environ Rept Encl.W/O Application

ML17297B014
Person / Time
Site:	Palo Verde
Issue date:	11/06/1981
From:	Van Brunt E ARIZONA PUBLIC SERVICE CO. (FORMERLY ARIZONA NUCLEAR
To:	Office of Nuclear Reactor Regulation
References
ANPP-19367-EEVB, NUDOCS 8111100744
Download: ML17297B014 (18)

Text

REGULATORY INFORMATION DISTRIBUTION 8 YSTE4l (RIDS)

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AC C K8S I 0 VI NBR: 811 FACIL~:STN-50-528 S TN"50 529 STN 50 530 AUTH/,NAMEI VAN SRUVf q El, Ki, RE C IP ~ VA4lEI 1100744 DOC ~ DATKI: 81/11/06 NOTARIZED:" NO Palo Ue'r de; Nucl cari Stat'i one Uni t 1R Arizona Public Palo le'rde>> Nuclear< Stat'ioni Unit 2R Arizona Publii Palo verde'ucleari Station~

Unit 3R Arizona Publi AUTHOR' F F ILI AT>>I ON Arizona Public Service Co ~

RKCXPlENT AFF ILKA>>TIOV Off ice>> of Nuclear Re'actor Regul ati one Director<

OO KEtT" 0 0500%529 05090530

SUBJECT:

Forwards appl i cati on fori amend>> to CPPR" 141E CPPR" 142 CPPR 143 permitting, transfer

< of Elil Paso Electr ic Co oanership interest to M-S-R Public Power Agency.Supoorting financfal info 8 revi sedr envi ron rept encl

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'HOENIX( ARIZONA 65036 November 6,

1981 ANPP-19367-EEVBJr/CAB Director of Nuclear Reactor Regulation U.S. Nuclear Regulatory Commission Washington, D.C.

20555 o

5P cP Sub ject:

Application for Amendment to Construe Permits Nos.

CPPR-141, CPPR-142 and CPP Palo Verde Nuclear Generating Station Units 1, 2 and 3

Docket Nos.

STN 50-528/529/530 File Nos.

81-044-026, 81-056-026

Reference:

Letter dated October 1,

1981, from Reba M. Diggs, Facilities Program Coordinator, License Fee Management

Branch, U. S. Nuclear Regulatory Commission, to Edwin E.

Van Brunt, Jr.,

APS Vice President, Nuclear Projects, Arizona Public Service Company

Dear Sir:

Arizona Public Service Company (APS),

as Project Manager and Operating Agent of the Palo Verde Nuclear Generating Station (PVNGS) Units 1, 2 and 3, is enclosing herewith three originals and nineteen copies of its Application for Amendment to Construc-tion Permits Nos.

CPPR-141, CPPR-142 and CPPR-143, dated Novem-ber 6, 1981.

The enclosed Application seeks the approval of the transfer by El Paso Electric Company to the M-S-R Public Power Agency (M-S-R) of a 3.95% undivided ownership interest as a tenant in common with the other Participants in PVNGS, and the amendment of Construction Permits Nos.

CPPR-141, CPPR-142 and CPPR-143 to reflect such transfer.

In support and as part of the enclosed Application, APS is sub-mitting herewith nineteen (19) copies of the financial qualifica-tions information required by 10 CFR 5 50.33(f).

Also enclosed are twenty-two (22) copies of the environmental information required by 10 CFR Part 51.

The environmental information consists of pre-8iiii00744 8iii06 PDR ADOCK 05000528 A

pDR I

I fI

Director of Nuclear Reactor Regulation November 6,

1981 Page Two liminary revised pages to the Palo Verde Nuclear Generating Station Units 1, 2 and 3 (Docket Nos.

STN 50-528/529/530),

E ironmental Report Operating License Stage.

The preliminary nvir ed revised pages to the Environmental Report will be incorporate into the next ER-OL Supplement.

The general information required by 10 CFR 5 50.33 is being submitted under separate cover in the form of revised pages to the Palo Verde Nuclear Generating Station (Docket Nos.

STN 50-528/529/530),

General Information, Operating License Application.

With respect.

to antitrust information, M-S-R at this time has no electrical generating capacity.

Furthermore, none of the three members of M-S-R has electrical generating capacity'in excess of 200 MW(e).

Therefore, pursuant to 10 CFR g 50.33a, information regarding antitrust matters is not required for M-S-R or any of its members.

Based on the referenced letter, which concerns the applicable filing fee under 10 CFR 5 170.22 for a similar application, APS is submitting herewith the filing fee associated with a Class III amendment.

Enclosed is an APS check in the total amount of $ 4800 in full payment of such fee.

This amount is based upon a fee of

$ 4000 for amendment of Construction Permit No.

CPPR-141, and a fee of

$ 800 for amendment. of Construction Permits Nos.

CPPR-142 and CPPR-143.

Sincerely, Edwin E.

Van Brunt, Jr.

APS Vice President Nuclear Projects ANPP Project Director EEVB:CAB:jaw Enclosures

PVNGS ER-OL

~ PKLINIMB SYSTEM DEMAND AND RELIABILITY This table and all other tables and figures in this section for PVNGS present the cumulative data as well as individual data for all participants.

Where appropriate

{that is, sales and purchases between participants),

the cumulative data have been adjusted to prevent duplication.

Information in table 1.1-1 shows that the participants had a

combined demand compound growth rate of about 5.6% per annum from 1968 to 1978, and that they anticipate a combined growth rate of 3.8% per annum between 1978 and 1988.

Between 1988 and 1992, it is expected that the combined system demand will be growing at an average rate of more than 1170 megawatts per year.

All participants are summer peaking utilities.

The electric demand and energy growth rate in the areas served by the parti-cipants can be attributed to a rate of population expansion greater than the national average, increased use of air condi-

tioning, and a general trend toward higher per capita use of electricity.

Most of the participants do not have and do not anticipate hav-ing any interruptible load.

SCE includes interruptible loads in its load management reductions, which reduce the peak fore-cast used in SCE planning studies.

Monthly demand and energy requirements for 1981 through 1988 for the combined systems of all participants as well as for an individual participant's

systems, are presented in table 1.1-2.

Figures 1.1-1 through 1.1-7 are projected 1987 to 1988 load duration curves for the participants'ombined system as well as for each participant.

The anticipated 1987 to 1988 load factor for the combined system is 60.3%, with individual load factors ranging from 57.4 to 70-2%.

Analysis of the load dura-tion curves indicates that nuclear energy production can dis-place higher priced coal resources, and that the full potential production of the nuclear units can be used in the combined systems of all participants.

The displacement of coal resources 1.1-3

PVNGS ER<<OL SYSTEM DEMAND AND RELIABILITY will in turn displace the need for the addition of oil-burning

units, such as combined cycle and combustion turbine units.

Thus, the use of domestic coal and nuclear resources will, each in turn, result in the area being less dependent on oil, an expensive and uncertain future energy resource.

All of the participants are members of the WSCC.

Part of their membership obligation is to periodically report certain of the above load-resource data to the WSCC for use in various reports and studies.

These data are compiled and published annually in the WSCC Summary of Estimated Loads and Resources.

The loads and resources for the PVNGS Arizona and New Mexico participants are included in the total for Region III, Arizona-New Mexico Power Area; the PVNGS Southern California participants are included in the totals for Region IV, Southern California-Nevada Power Pool.

Figure 1.1-8 shows the geographic boundaries of these areas.

The total annual peak demand and energy requirements for these two areas, as extracted from WSCC reports, are listed in table 1.1-3.

These data, compiled from the 1972-1987 report period, pertain to all utilities in the geographical area and therefore are larger in magnitude than the data compiled solely for the PVNGS participants.

Table 1.1-4 is a list of the monthly demand and energy requirements for the areas as extracted from the WSCC report for 1982 through 1987.

The loads and resources of SCPPA members except Los Angeles Department of Water and Power are presented in table 1.1-12.

Comparable data for LADWP is presented in table 1.1-1, sheet 3 of 7.

The loads and resources of M-S-R members are presented in table 1.1-13.

Supplement 4

1.1-4 December 1981

PVNGS ER-OL

~

PIKI.IMII@B SYSTEM DEMAND AND RELIABILITY The need for PVNGS and other additional generating capacity rests on the validity of the forecasts made by the participants for their respective loads through 1990.

To establish this validity the following topics are addressed:

~

Methodology of forecasting

~

Historical accuracy of forecasting

~

Impact of energy conservation measures December 1981 1.1-4A Supplement 4

PVNGS ER-OL SYSTEM DEMAND AND RELIABILITY This page intentionally blank Supplement 3

1.1-4B July 1981

Table 1 ~ 1-12 SCPPA MEMBERS LOADS AND RESOURCES (Sheet 1 1 of 11 )

IMPERIAL IRIGATION DISTRICT ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)

Page 2 of 2

Actual 1980 1981 Pro ected 1982 1983 1984 1985 1986 1987 1988 1989 1990 Hydro:

Drop No. 4 Drop No. 4 Drop No.

3 Drop No. 3 Drop No.

2 Drop No.

2 Pilot Knob Unit 1....

Unit 2....

Unit 1....

Unit 2....

Unit 1....

Unit 2....

Unit 1....

7.5 7.5 7.5 7.5 3.75 3.75 3.75 3.75 3 ~ 75 3.75 3.75 3.75 9.0 9.0

7. 5 7.5 3. 75 3. 75

3. 75 3.75 9.0

7. 5 7.5 3. 75 3. 75 3.75 3.75 9.0 7.5 7.5 3. 75 3.75 3.15 3. 75

9. 0 7.5 7.5 3.75 3.75 3.75 3. 75 9.0 7.5 7.5 3.75 3.75 3.15 3.75 9.0 1.5 7.5

3. 75 3.75 3. 75 3.75 9.0

7. 5 7.5 3. 75 3.75 3.75 3.75 9.0 7.5 7.5 3.75 3.75 3.75 3.75 9 ~ 0 7.5 7.5

3. 75 3.75 3.75 3.75 9.0 Subtotal..

Geothermal t Additions I1 )....

Nuclear:

Palo Verde 1.

~..

Palo Verde 2....

Palo Verde 3....

39 39 39 39 3.5 39 3.5 3.5 39 3.5 3.5 39 3.5 3.5 3.5 39 3.5 3.5 3.5 39 12

3. 5

3. 5

3. 5 39 15 3 ~ 5 3.5 3.5 39 18

3. 5 3.5 3.5 Subtotal...

Other:

wAP-Parker-Davis..

SCE'-Axis Plant....

Purchases.........

33 25 40 33 25 40 33 25 40 33 25 40 33 25 40 33 25 100 33 25 100 33 25 100 33 25 250 33 25 250 33 25 261 Subtotal 98 98 98 98 98 158 158 158 308 308 319 Total...

Nargin for Reserves/Losses..

Percent Nargin...

452 84 23 477 86 22 477 56 13 53 1 84 19 534 70 15 597 1 15 24 604 102 20 607 85 16 760 217 763 198 35 717 190 32 t p t n tn b

• t by n tti in ti i

r r tb r tt int br i t:

n b r nn tb rn r. br itr r nii nn.

Table 1.1-13 M-S-R MEMBER IOADS AND RESOURCES (Sheet.

1 of 3)

MODESTO IRRIGATION DISTRICT ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)

Actual Pro'ected Energy Requirements (Gwh) ~

~ ~ ~

1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1268 1358 1400 1446 1492 1539 1595 1652 1712 1773 1837 Peak Load (MW)..........

351.7 344 398 414 431 447 465 483 503 523 544 Resources:

(MW)

Existing Hydro

~ ~ ~ ~ ~ ~ ~ ~

~

Gas Turbine...

Proposed Small hydro(

Geothermal....

Harry Allen...

ANPP

~ ~ ~ ~ ~ ~ ~ ~ ~

~

Purchases........

54.4 39.0 258.3 54.2 53.4 236.4 49.5 98.0 0.5 272 '

49. 5 98.0 6.0 41.7 248.1 49.5 98.0 49.5 98.0 83.4 218.2 83.4 224.6 19.4 30.8 49.5 98.0 32.8 82.5 30.0 125.0 152.0 49.5 98.0 32.8 82.5 60.0 125.0 151.0 49.5 98.0 32.8 82.5 90.0 125.0 149.0 49.5 98.0 32.8 82.5 120.0 125.0 148.0 49.5 98.0 32.8 82.5 120.0 125.0 144.0 To'ta 1 o ~

~

~

~

~

~

~

~

~ ~

~

~

~

Margin for Reserve/

Losses................

Percent Margin..........

351.7 344.0 420.2 443.3 468.5 486.3 569.8 598.8 626.8 655.8 651.8 0

22.2 29.3 37.5 39.3 104.8 115.8 123.8 132.8 107 '

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 th)0 0

Table 1.1-13 M-S-R MEMBER LOADS AND RESOURCES (Sheet'.

2 of 3)

CITY OF SANTA CLARA ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)

Actual Pro 'ected Energy Requirements

{Gwh) 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1609 1754 1858 1959 2052 2142 2234 2326 2415 2516 2612 Peak Load {MW)........

Resources

{MW)

Thermal Geothermal, NCPA..

Gas Turbine - Cogen Small Hydro Black Butte.......

Stony Gorge.......

Large Hydro Calaveras.........

Purchases...........

265.6 265.6 5.8 60.4 5.8 60.4 5.8 60.4 45.8 60.4 45.8 6.8 3.9 60.4 45.8 6.8 3.9 78.4 45.8 6.8 3.9 78.4 45.8 6.8 3.9 78.4 45.8 6.8 3.9 78.4 45.8 6.8 3.9 291.2 261.0 278.0 266.6 62.0 224.8

62. 0 255.6 62.0 253.6 62.0 268.6 62.0 345.1 62.0 345.1 297 314 331 347 262 37S 394 409 426 442 Total...............

Margin for Reserve/

Losses.

265.6 297.0 327.2 344.2 372.8 403.7 434.5 450.5 465.5 542.0 542.0 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 '

14.9 14.3 13.8 27.2 22.6

Table 1.1-13 M-S-R MEMBER LOADS AND RESOURCES (Sheet 3 of 3)

CITY OF REDDING, ELECTRIC UTILITY SYSTEM (CALENDAR YEAR)

Actual Pro'ected Energy Requirements (Gwh)o

~

~

~

Peak Load (MW).........

~

1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 444.6 481.4 511.2 536.8 562.4 587.9 609.2 630.5

.651.8 673.1 690.2 105 113 120 126 132 138 143 148 153 158 162 Resources:

(MW)

Thermal ANPP ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~

Harry Allen....

Geothermal.....

Small Hydro Whiskeytom....

Saeltzer.......

Lake Redding...

Lake Red Bluff.

North Fork.....

cottonwood.....

Large Hydro Calaveras......

Purchases........

105 113 120 4.0 117 115.4 8.3 16.6 16.6 4.0 0.9 18.8 115.4 25.0 5.0 16.5 4.0 0.9 14.0 14.0 18.8 115.4 25.0 10.0 16.5 4.0 0.9 14.0 14.0 6.0 18.8 115.4 25.0 15.0 16.5 4.0 0.9 14.0 14.0 6.0 18.8 115 '

25.0 20.0 16.5 4.0 0.9 14.0 14.0 6.0 18.8 115.4 25.0 20.0 16.5 4.0 0.9 14.0 14.0 6.0 9.0 18.8 115.4 Tote 1 o ~ ~ ~ ~ ~

~

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~

~

~

~ ~

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Margin for Reserve/

Losses

~ ~

~

~

~ ~

~

~ ~

~

~

~

~ ~

~

~

Percent Margin..........

105 113 120 126 136.0 155.7 213.6 224.6 229.6 234.6 243.6 4.0 17.7 70.6 76.6 76.6 76.6 81.6 3.0 12.8 49.4 51.8 50.1 48.5 50.4 U

0 0

PVNGS ER-OL

~ pi~II IIp:";(ppy CONSEQUENCES OF DELAY The participants generally rely on a high percentage of resources that are remote from their load areas, with power carried to the load areas over EET transmission systems.

There is a limi'ted number of interconnections between the partici-pants'ervice areas and surrounding systems.

Even assuming that the large amounts of power that may be needed are avail-able for purchase, the limited number of interconnections and high use of the EHV tranmission system will make it difficult for those large amounts of power to be transmitted to the participants'ervice areas.

Delays in the construction of PVNGS generating facilities will have the following adverse effects on systems planning and operation.

A.

Longer Lead Times - Consistent delays in construction lengthen the lead time required for generation plan-ning.

This reduces the flexibilityand adaptability of incorporating new technology or changes in load fore-casts into the planning process.

B.

Decreased System Reliability - Delays will result in lower reserve margins that decrease system reliability and thereby cause more frequent service interruptions.

C.

Additional Costs - The delay of a generating facility may require the temporary substitution of a more costly alternative with the possibility of a greater environ-mental impact.

Delays also result in additional costs for interest during construction of the planned facility.

The impact of delay on production costs is shown in table 1.3-8.

The assumptions regarding heat rate, fuel

cost, 0&M costs, and discount rates are presented in table 1.3-9.

The energy mix of SCPPA members and M-S-R members that have their own generation is shown in tables 1.3-10 and 1.3-11, respectively.

December 1981 1.3-3 Supplement 4

Table 1.3-1 1981 RESERVE MARGIN DUE TO DEMY OF PVNGS (MW) (Sheet 1 of, 10)

No Delay 1 Year Delay 2 Year Delay 3 Year Delay Indefinite Delay Arizona Public Service 697 697 697 697 697 1464 1464 1464 1464 1464 El Paso Electric 153 153 153 153 153 Public Service of New Mexico 238 238 238 238 238 Salt River Project 1037 1037 1037 1037 1037 0

Southern California Edison 2197 2197 2197 2197 2197 Participants Total 5786 5786 5786 5786 5786 0

u

Table 1.3-9 AVERAGE SYSTEM DATA SOUTHERN CALIFORNIA EDISON (Sheet 6 of 6)

Year Heat Rate (BTU/KWH)

Fuel Cost

($/MWH) 0&M Cost

($/MWH) 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 9880 9850 9860 10080 10170 10290 10430 10520 10560 10520 42.40 49.70 49.20 53.60 58.60 60.90 63.80 65.50 69.10 73.60 3.50 4.40 4.40 4.90 5.30 6.10 6.90 8.10 8.80 9.60 n0 f.

SCE discount rate is 15%

PVNGS ER-OL CONSEQUENCES OF DELAY Table 1.3-10 SCPPA MEMBERS ENERGY MIX MEMBER WPo

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B lendale....................

G Pasadena..........-......-.-

Imperial Irrigation District HYDRO GAS DIESEL COAL 14$

27/

28$

31$

3X 72K 25K 10$

78$

12$

0 17/

72/

1l%,'

52/

34%%uo 14$

0 a.

Excludes members without their own generation.

MEMBER Table 1.3-11 M-S-R MEMBERS ENERGY MIX HYDRO GAS Modesto Irrigation District.......

50.4%%u'ity of Santa Clara...............

0 49.6%

aoo%%u a.

Excludes members without their own generation.

Supplement 4

1.3-74 December 1981