20031021Said Workpapers.pdf

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-03-13
IDAHO POWER COMPANY
G.SAID
WORKPAPERS
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!PUC OPUC NPSC F'ERC PRAIRIE TOTAL NORMAL I Z E:D NOAUA LI 7 ED NORMALIZED NORMALIZED NORMALIZED · NORMAL I ZED WRATE MONTH MWH MWH MWH "4WH I.CWH I.CWH
n.tC JAN93 141 . 06,. 39.3 0.00e 0.000 0.000 e.00e 141 .062. 393
F'E89J 130.6.36.791 0.000 0.000 0.000 e.000 1.30.6.36.791 MAR9.3 146.419.199 0.000 0.000 0.000 e.0e0 146,419.199 APR9.3 139.773.590 0.000 0.000 0.000 0.000 139,773.590 MA'\'9.3 151,775.994 0.000 0.000 0.000 0.000 151 .775.994 JUN9.3 126.696.955 0.00e 0.000 0.000 0.000 126,696.95� JUL93 111.421.4�6 e.00e 0.000 0.000 e.eee 111,421.436 AUG93 119.992.31€ 0.000 e , eee e.00e 0.e00 119,992.316 SEP93 1 1 9 . 220 . 483 0.000 0.000 0.000 0.000 119.220.40J OCT93 137,675.997 0.000 0.000 0.000 e.000 137.675.997 NOV93 127.871.991 0.000 0.000 0.000 e.000 127 , 87 1 . 99 1 OEC93 1.37,491.197 0.000 0.000 0.000 0.ee0 137.-491 .197
TOTAL �590.038 . .34� 0.000 0.000 0.000 e.000 1,590.038.342
INEL JAN93 1�12!-S.76e 0.000 0.000 0.000 e.000 14 .235. 760 F'EB93 15,461 .270 0.000 ti .eee 0.e0e e.000 15,461 .270 MAR93 11,542.800 0.000 0.000 0.000 e.eee 11 . :142. eee APR93 18.742.870 0.000 0.000 0.000 0.000 18,742.670 MAYOJ 18.083.350 0.000 0.000 0.000 0.000 18,083.350 JUN9.; 13,795.760 (),000 0.000 0.000 e.ee0 1:3, 795. 760 JUL93 1"1.026.:57:2 e.00e 0.000 e .eee o.oo·o. 14 .028 .372 AUG93 9, 102. 610 0.000 0 .000 0.000 e.000 9, 102. 610
SEP93 12. 652. 180 e.000 0.000 0.00e e.000 12. 652. 180 OCT93 1J.161 . 540 e .eee 0. 000 0.000 e.000 13o"161 .540 NOV93 15, 158.830 0.000 0.000 0.000 0.000 15. 158 .830 DEC93 16.JJ2.640 0.000 0.000 0.000 ·e.000 16,JJ2.640
io; "L 172.297.982 0.000 0.000 0.000 0.000 172.297.982 • 8 t,:<' »r I? 10#,; i!,�/l / s: f'V. t? � 6') /fW/7 FMC , ,/ J v .
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Development of Energy Related Allocation Factors - Normalized i. Total Annual Energy
TWELVE MONTHS ENDING DECEMBER 31. 1993
line Delivery Customer losses Power Supply
No. DescriQtion Voltage level MWH 1985-1987 level MWH
I. RETAIL JURISDICTIONS
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State of Idaho
l ransmlssion Level 138 KV 172,298.0 / 179,534.5
Subtransmission Level 46 & 69 KV 88,923.1 I 5.60% __y 93,902.8
Distribution Station 13.2 KV 2,119,148.4.t: � 2,231,463.3
Primary Distribution 12.5-34.5 KV 1,491 ,326.0 7.70% 1,606,158. 1
All Other Service 7,4 76.264. 1 10.80% 8,283,700.7
Total Idaho Retail 11,347,959.7 12,394, 759.4
State of Oregon
Transmission Level 138 KV 56,474.8 4.20% 58,846.7
SulJu c1n:)mi:1:1ion 69 KV 568.8 5.60% 600.7
Primary Distribution 12.5-34.5 KV 94,764.0 7.70% 102,000.S
All Other Service 362,470.2 10.80% 401.616.9
Total Oregon Retail 514,277.8 563, 125.2
State of Nevada.
rrimery Distribution 12.5-34.5 KV. ,.p, 150.7 7.70% 17,394.3
• ••• All Other Service 29;421.6 1'0.80� 32,590.2
Total Nevada Retail 45,572.3 49,993.4
II. WHOLESALE CONTRACTS
Azusa. Banning & Colton 230 KV 42,175.0 3.10% 43,482.4
Mont::m� Power Company 230 KV 437.500.0 3.10% 451 ,062.5
OTECC 69 KV 46,658.0 5.60% 49,270_8
Sierra-Midpoint 345 KV 96,592.2 3.10% 99,586.6
Sierra-Elko 69 KV 0.0 5.60% 0.0
Total Sierra-Elko Contract 96,592.2 99,586.6
Sierra-Long Term 345 KV 421,414.0 3.10% 434,477.8
UAMPS 345 KV 316.736.0 3.10% 326.554.8
Washington City 345 KV 28.307.0 3.10% 29.184.S
Weiser City 12.5KV 47,126.2 5.30% 49,623.9
Total Wholesale Contracts 1,436,508.4 1,483,243.4
Ill. TRANSMISSION CONTRACTS
BPA South Idaho T.S.A.
BPA/OTECC T.S.A.
Seattle City & Light T.S.A.
SYSTEM TOTALS
Total Sales 13,344,318.2 14,491,121.5 •
Run 05 • 5/11 /94
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RESIDUAL OUTPUT UBS. YEAR RUNUFt LN(RUNUFFl NPSC Observat,on Preaicted Y
. SUMMARY OUTPUl
AVERAGE s 48,039,308
Exhibit No. 1
Case No. IPC-E-03-05
G. Said, IPCo
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1
2
3
Q.
A.
What is the projection of PCA expenses for
The projection of PCA expenses for the period
the period April 1, 2003 through March 31, 2004?
4 April 1, 2003 through March 31, 2004 is $111,209,453. This
5 amount is $38,130,325 more than the $73,079,128 normalized
6 level of PCA expenses.
7 Q. What is the basis for the projection of April
8 1, 2003 through March 31, 2004 PCA expenses?
9 A. The Commission, in Order Nu. 24806 issued in
•••
10 Case No. IPC-E-92-25, the proceeding which created the PCA,
11 adopted a natural logarithmic function of projected April
12 through July Brownlee runoff to c.ompute the proj ec t i on of
13 April thr,ough March PCA experis e.s ". 'The ,derivation of the
. . . 14 current equation is contained on-Exhibit No. 1 ("Cur1e11L
15 Regression"). Qualifying facilities ( "QF") purchase expense
16 and normalized Astaris/FMC second block energy revenue are
17 constants, which have hPPn included in the proiection
18 computation. The current equation is:
19
20
21 + $47,574,344
PCA expense= $1,023,185,930
$63,236,861*(1n(runoff))
22 $9,07d,032
23 In this formula, the $47,574,344 is the
24 constant for QF purchase expense, established in Order No.
25 27997. The $9,074,032 is the normalized Astaris/FMC second
SAID, DI 6
Idaho Power Company