20031021Brilz Exhibit 47.pdf

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-03-13
IDAHO POWER COMPANY
EXHIBIT NO. 47
M. BRILZ
Derivation of Schedule 45 Standby Charges
IDAHO POWER COMPANY
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
DERIVATION OF STANDBY CHARGES
December 31, 2003
DERIVATION OF WEIGHTED RESERVE MARGIN
Operating Weighted
Line Maximum Reserve Operating Reserve
No. CaQacity Percentage Reserve Margin
1 Thermal Plant * 1,110.1 7% 78 2.8%
2 Hydro Plant 1,706.7 5% 85 3.0%
3 TOTAL 2,816.8 163 5.8%
• Excludes Danskin and Salmon Diesel
DERIVATION OF_STANDBY�RESERVATION CHARGE Standby
Reservation
Charge
Primary
Standby
Reservation
Charge
Transmission Generation Reserve ComQonent
Schedule 19 Production (Unit Cost * 5.8% WRM)
4 Summer 3.95204 0.23
5 Non-Summer 1.59645 0.09
Transmission Reserve ComQonent
6 Schedule 19 Transmission (Unit Cost* 10% EFOR) 1.35670 0.14
Distribution Reserve ComQonent Total Cost Billing Units
7 Schedule 19 Substation 1,577,379 3,903,470 0.40410 0.40
8 Schedule 19 Primary Lines 3,205,775 3,903,470 0.82126 0.82
9 Schedule 19 Primary Trans 274,457 3,903,470 0.07031 0.07
10 Dist. Subtotal 1.296 1.30
TOTAL STANDBY RESERVATION CHARGE
11 Summer $1.66
12 Non-Summer $1.52
DERIVATION OF STANDBY DEMAND CHARGE
Schedule 45 Total Demand Component
13 Summer 6.60
14 Non-Summer 4.25
15 Ratio of $3.95 to $5.31 0.74388
16 Ratio of $3.25 to $2.95 1.10169
Schedule 45 Primary Standby Demand Charge
17 Summer $4.91
18 Non-Summer $4.68
Less Avoided Losses at Transmission Voltage
19 Summer 0.27
20 Non-Summer 0.26
Schedule 45 Transmission Standby Demand Charge
21 Summer $4.64
22 Non-Summer $4.42
0.23
0.09
0.14
$0.36
$0.23
STANDBY.XLS.10/14/2003.mb
EXHIBIT NO. 47
C::ASF NO IPC:-F:-03-13
M. BRILZ, IPCo
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