20060515Comments.pdf

DONALD L. HOWELL, II
DEPUTY ATTORNEY GENERAL
IDAHO PUBLIC UTILITIES COMMISSION
PO BOX 83720
BOISE, IDAHO 83720-0074
[phone]
IDAHO BAR NO. 3366
I.! n
. .... "
. !' c
Street Address for Express Mail:
472 W. WASHINGTON
BOISE, IDAHO 83702-5983
Attorney for the Commission Staff
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION OF
IDAHO POWER COMPANY FOR AUTHORITY)
TO IMPLEMENT POWER COST ADJUST-
MENT (PCA) RATES FOR ELECTRIC
SERVICE FROM MAY 31, 2006 THROUGH
MAY 31, 2007
CASE NO. IPC-06- 7
COMMENTS OF THE
COMMISSION STAFF
The Staff of the Idaho Public Utilities Commission, by and through its Attorney of
record, Donald L. Howell, II, Deputy Attorney General, submits the following comments in
response to Order No. 30022, the Notice of Application and Notice of Modified Procedure issued
on April 18, 2006.
BACKGROUND
On April 12, 2006, Idaho Power Company filed its annual power cost adjustment
(PCA) Application. Since 1993 the PCA mechanism has permitted Idaho Power to adjust its
rates upward or downward to reflect the Company s annual "power supply costs." Because of its
predominant reliance on hydroelectric generation, Idaho Power s actual cost of providing
electricity (its power supply cost) varies from year-to-year depending on changes in Snake River
STAFF COMMENTS MAY 12 2006
streamflow and the market price of power. The annual PCA surcharge or credit is combined
with the Company s "base rates ! to produce a customer s overall energy rate.
In this Application Idaho Power proposes a PCA rate adjustment that reduces annual
revenue $46.8 million below what would be collected under base rates. The Company represents
this as a $123.5 million decrease in revenues from existing PCA rates, or an average reduction in
the PCA rates of 19.34%. Exhibit 8. Attachment A to these comments is a graphic that shows
the history of Idaho Power s residential energy rates and identifies the PCA component.
STAFF AUDIT AND ANALYSIS
The PCA has three components: 1) a projection component; 2) a true-up component that
corrects for the previous years projection error; and 3) a true-up ofthe previous year s true-up
that is a final correction. Set out below are the Staff s comments on the three PCA components.
A. The PCA Projection
The National Weather Service Northwest River Forecast Center in Portland, Oregon
forecasts the April through July Brownlee Reservoir inflow this year to be 8.38 million acre-feet
(mat). This is one hundred and thirty-three percent (133%) of the average inflow. A regression
equation developed from the results of a power supply model run is used to project "Net Power
Supply Costs.See Order No. 24806. Using the forecasted 8.38 maf and the regression
equation, Staff calculates Net Power Supply Costs for April 2006 through March 2007, to be
579 741. As authorized by Commission Order, Staff increased the calculated Net Power
Supply Costs by expected PURP A qualifying facility purchases of $54 632 157 and reduced the
amount by the expected net benefit of cloud seeding $895 462 ($1 004 538-900 000) to
generate an expected PCA expense of$63 316 436. See Staff Attachment B.. This is $37.
million below normal on a total company basis. Staff found that its calculation agreed with
Idaho Power s calculation. The calculation of the projection rate component is shown on lines 1
through 6 of Attachment C, where the projection rate component is calculated to be
0.2507 ~/kWh. Staffs calculation of the projection rate component agrees with Idaho Power
calculation.
I Base rates are to be established by the Commission in Idaho Power s pending general rate case (Case No.
IPC-O5-28). All parties in the pending general rate case have urged the Commission to approve a
settlement Stipulation to increase base rates by an average of3.2%.
STAFF COMMENTS MAY 12, 2006
B. The PCA True-up
Exhibit No.3 to Idaho Power witness Schwendiman s testimony illustrates the
calculation of the true-up deferral amount. Attachment D is Staffs calculation of true-up
deferral amounts. Staff found no differences in methodology or amounts from those presented
by the Company.
As shown on Attachment D, line 62 in the "Totals" column, the true-up amount with
interest is a minus $39 513 704. In rounded numbers it is composed as follows:
ITEM
Revenues from Last Year s Projection
90 % of Last Year s Above Normal Power Supply Costs
Last Year s Above Normal PURPA Facilities Costs
Miscellaneous Adjustments (Lines 45 , 46, 47, 48)
Interest ($57 730)
MILLIONS
$(48.
$ 21.0
$ (0.
$(11.2)
$ 0.
---------
Total True-up Expense $(39.
To verify revenues and costs associated with Idaho Power s true-up deferrals, Staff
conducted an audit of all actual revenues and expenses that occurred during the PCA year.
These revenues and costs included the cloud seeding program, fuel expenses for coal, fuel
expenses for gas, and power purchases and sales. Staff also examined Settlement Agreement
Credits for Order No. 29600, IDACORP Energy credits, and the Risk Management operating
plans. The following items were significant:
a. Cloud Seeding Program. Idaho Power spent $1 108 094 in total on the cloud seeding
program costs during the prior PCA year. This expense item is subject to the 90/10 sharing.
b. Fuel Expense - Coal.A large portion of Idaho Powers electricity comes from thermal
power produced from its coal plants. The three coal plants in operation for Idaho Power are
Bridger, Valmy, and Boardman. For the audit period of April 2004 to March 2005, the total coal
expense for all plants in operation was $100 632 189. This is $5 482 789 higher than the base.
This expense item differential is subject to the 90/10 sharing.
c. Fuel Expense - Gas. Idaho Power owns two gas-fired combustion turbine generating
plants. The Danskin and Bennett Mountain Power Plants are both located near Mountain Home
and account for 100% of gas usage. The total variable gas and gas transportation expense
STAFF COMMENTS MAY 12, 2006
amounted to $3 987 581 for the PCA period. This expense item is $730 981 over the base and
the difference is subject to the 90/10 sharing.
d. Power Purchases and Sales. During the PCA year ending March 31 , 2006, the
Company sold surplus power totaling $211 248 247 , while total power purchases (excluding
PURPA contracts) were $188 243 754. When applying the 90% sharing percentages to the net
sales of $23 004,493 , customers will receive a benefit of $20 704 044 over the next 12 months.
Staff reviewed the power purchases and sales in conjunction with the Company s Risk
Management Operating Plans. Our analysis did not find any transaction that was not reasonable
or did not follow the Risk Management Committee s recommendations. These transactions were
made with an assortment of credit-worthy partners on a timely basis, and there were no
transactions conducted with an Idaho Power affiliate.
e. IdaCorp Energy Credit.In Order No. 29446, Case No. IPC-01-16 (PHASE II), the
Commission accepted the terms of a stipulation between Commission Staff, Idaho Power, and
various customer groups, including the Industrial Customers of Idaho Power, J.R. Simplot
Company, Idaho Retailers Association, and Micron Technology. The stipulation credited Idaho
customers approximately $10 million from May 2003 through December 2005. The credit was a
separate line item in the PCA calculation with 100% of the benefit going to Idaho customers.
The monthly amount of $166 667 is included in this year s PCA filing for 9 months, ending in
December 2005. The total amount of the credit included in this year s PCA filing is $1 500 000.
f. Settlement Agreement (Order No. 29600). In a Stipulation involving Idaho Power and
the Commission Staff, both parties agreed on a single comprehensive settlement amount to
resolve several outstanding issues. Case No. IPC-04-9. The parties proposed that the expense
adjustment rate for growth (EARG) component in the PCA would continue at the existing value
16.84 mills per kWh, until the next general revenue requirement case in which the Company
resets the base rates for PCA computation purposes. Idaho Power also agreed to provide a $19.
million revenue credit to Idaho Power Customers in the Company s PCA. This revenue credit
would be a separate $804 167 monthly line item for the months June 2004 through May 2006 in
the PCA true-up calculation and includes interest from June 1 , 2004 at the PCA carrying charge
rate of one percent (1 %). The Commission approved the Stipulation in Order No. 29600 issued
in September 2004. Staff verified that all settlement components of the Stipulation were
incorporated in this PCA Application. The Company has included the proper credit for
customers in the amount of$9 650 000 through March 2006.
STAFF COMMENTS MAY 12 2006
g.
Bennett Mountain Credit.In Order No. 29790, Case No. IPC-05-, the
Commission approved recovery of Bennett Mountain power plant costs and required that the
related reduction in power supply expense be included in the Company s 2006-2007 PCA. The
Company has included the proper monthly amount to reflect the reduction in power supply costs
resulting from the Bennett Mountain power plant. The credit began in June 2005 and is reflected
in the Company s filing for 10 months. This credit totals $39 858 and is not subject to the 90/10
sharing.
C. The PCA True-up of the True-up
The true-up amount set for recovery in last year s PCA case (IPC-05-15) was
$49,472 607 and the rate calculated to recover that amount was 0.3973 ~/kWh. At the
Company s request, the overall PCA rate was not increased last year. This resulted in an
effective PCA true-up rate of 0.1751 ~/kWh which was expected to under recover the true-up
amount by approximately $28.3 million. Including interest considerations, the approved rate
under recovered the true-up amount by $24 513 298. As shown on Attachment C, line 13 , this
amount is used to calculate the true-up of the true-up PCA rate component of 0.1931 ~/kWh.
This is the same rate the Company calculated.
PCA RATES
The Staffs calculated PCA rate reduction of -3689 ~/kWh is the sum ofthe three
components listed above (-0.2507 + -3113 + 0.1931 = -3689). This rate is shown on
Attachment C, line 16. These are the same rates included in the Company s filing.
Attachment E shows the average reduction from base rates by class and Attachment F
shows the average reduction from existing rates by class. In both of these attachments the
percentage decrease to larger customers is substantially more than the average decrease. When
large power supply costs increase rates, larger customers receive larger than average PCA
increases. This results because large customers have lower rates than smaller customers and an
equal cents per kWh increase makes a larger percentage difference to them than it does to
smaller customers whose base rates are higher.
STAFF COMMENTS MAY 12 2006
CONSUMER ISSUES
Idaho Power filed its PCA Application on April 12, 2006. Customers were notified of
the Application by bill stuffers and a press release. The bill stuffers were mailed with customers
monthly billings beginning on April 26th and ending May 24
Both the customer notice and press release comply with the notice requirements of
IDAPA 31.21.02.102. Customers were given until May 1th to file comments regarding the
proposed decrease in rates.
As of the preparation of these Comments, the Commission had received no comments
from customers.
PCA RECOMMENDATIONS
Staff s review identified no adjustments to the Company s calculations. Staff
recommends that the Commission approve the PCA rates as filed by the Company. Staff
recommends that these PCA rates become effective June 1 2006.
Respectfully submitted this
-/,k
day of May 2006.
Deputy Attorney General
Technical Staff:Keith Hessing
Donn English
Kathy Stockton
Marilyn Parker
Beverly Barker
i :umisc/commen tslipceO6. 7 dhkhklsdempbab
STAFF COMMENTS MAY 12, 2006
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2006-2007 PCA - Fourteenth Annual
IPC-06-
Staff Case
(a)(b)(c)(d)(e)(f)
(g)
Line Descri tion Units Base Forecast Difference Rate
Projection 2006-2007:
PCA Expense
($)
100 916,459 63,316,436 (37 600,023)
Normalized System Firm Sales (MWH)13,497 550 13,497 550
Energy Rate (i/kWh)74767 0.46910 27857
Sharing Percentage
(%)
90%
Energy Rate Difference (ilkWh)25071232 (0.2507)
ill (MWh)($/MWh)WkWh)
True-Up of 2005-2006:(39,513 704)695 163 112500722 (0.3113)
True-Up of the True-Up:513 298 695,163 930916366 1931
PCA Rates:
PCA Rate Adj. From Base (ilkWh)(0.3689)
PCA Rate Currently in Effect (~/kWh)6039
Difference - Last Year to This Year (i/kWh)(0.9728)
Expected PCA Revenues:Rate Energy Revenue
/MWh (MWh)ill
Forecast Revenue (2.507)695 163 (31 826 774)
True Up Revenue (3.113)695 163 (39 513 695)
True Up of True Up Revenue 931 695,163 513 090
Total (3.689)(46 827 378)
Note: Negative rates and amounts indicate benefits to ratepayers.
U:lkhessinllPCE0607lCompany CaselTRUE UPS & RATES 5/5/2006
Attachment C
Case No. IPC-06-
Staff Comments
05/12/06
DESCRIPTION
3 PCA Revenue
4 Normalized Idaho Jurisd, Sales
5 Forecast Rate
6 Revenue
8 Load Change Adjustment
9 Actual System Firm Load - Adjusted
10 Normalized Firm Load
11 Load Chan
12 Expense Adjustment ((1j)16.84)
14 Non-QF PCA
15 ACTUAL:
16 BPA Water Option Agreement
17 Cloud Seeding Program
18 Fuel Expense - Coal
19 Fuel Expense - Danskin
20 Fuel Expense - Bennett Mountain
21 Non-Firm Purchases
22 Surplus Sales
23 Ex ense Ad usiment (iPJ16,24 Sub-Total
26 BASE:
27 Fuel Expense - Coal
28 Fuel Expense - Danskin
29 Fuel Expense - Bennett Mountain
30 Non-Firm Purchases
31 Surplus Sales
32 Sur lus Sales Adder33 Sub-Total
35 Change From Base
36 Deferral (Shared and Allocated)
38 QF Deferral
39 Actual (includes Net Metering)
40 Base
42 Change From Base
43 Deferral (Allocated)
45 Intervenor Funding
46 Credit From IDACORP Energy
47 Settlement Agreement (ON 29600)
48 Bennett Mtn. Credit (ON 29790)
49 Total Deferral (-6+36+43+45+46+47+48:
51 Principal Balances
52 Beginning Balance
53 Amount Deferred
54 Ending Balance
56 Interest Balances
57 Accrual thru Prior Month
58 Interest (1j) 2% per Year
59 Prior Month's Interest Ad
60 Total Current Month Interest
61 Interest Accrued to Date
62 Balance (True-Up & Interest)
64 True-Up of the True-
65 True-Up Revenues66 True Up Rates67 Actual Idaho Sales68 Total
70 Beginning Baiance
71 Adjustments per ON 2979372 Fuel Expense Adjustment73 Intervenor Funding
74 Irri ation Lost Revenues ON 2966975 Sub-Total
76 Interest (1j) 2% per Year
77 Revenue Applied to Interest
78 Revenue Applied to Balance
79 True-Up of the True-Up Balance
MWh
mlKWh
TRUE-UP CALCULATIONS FOR 2005 - 2006
FOR
IDAHO POWER COMPANY PCA
CASE NO. IPC-06-
Staff Case
Units
2005
APR
862 931
2.499
156,465
MWh
MWh
MWh
002 528
974 066
28,462
(479 300)
788
527 289
333 725
098 341
(5,434 762)
479 300
103 080
108,200
264 800
000
187 500)
786 500)
889 580
528 585
131 025
815 766
(684 741)
(644 341)
(166 667)
(804,167)
756 946
756 946
756 946
757 003
2005
MAY
881 064
2.499
201 779
020 216
142 316
122 100
056 164
256 201
516,168
114 958
169 001
500 338
(18 370 968)
056 164
(758 138)
800 600
278 500
664 100
566 900)
176 300
934,438)
638 276)
605 364
160 399
(555 035)
(522 288)
(166 667)
(804 167)
333 176)
756,946
333 176
576 230)
262
231
287
569 943)
2005
JUN
002 040
4.288
296 748
272 295
258 858
437
(226 279)
878 317
114 108
654 700
234 832
(14 206 066)
226 279
6,449 612
344 900
275 700
931,000
(4,558 900)
992,700
1,456 912
233 859
359 151
508 847
(149 696)
(140 864)
(166 667)
(804 167)
986)
178 571 )
576 230)
178 571
754 801)
287
(2,627)
627)
660
751 141)
2005
JUL
185 074
288
081 597
641 692
1,491 793
149 899
524 299)
168 717
191 888
1,480 609
198 870
(11 376 337)
524 299
139 448
714 800
279 600
335 100
385,400)
944,100
195 348
9,481 340
810 850
702 897
107,953
101,584
(166 667)
(804 167)
986)
526 508
754 801 )
526 508
(2,228 293)
660
591)
595)
935
234 228)
2005
AUG
303,702
288
590,274
538 801
1,424 633
114 168
(1,922 589)
963 765
274
450 682
146 513
360 602)
922 589
22,368 042
721,300
280,000
842,900
371 000)
8,473 200
894,842
767 542
6,490 347
6,422 258
089
071
(166 667)
(804,167)
(3,986)
266 520
228 293)
266 520
038 227
935)
714)
145
569)
504
028 722
2005
SEPT
164 116
288
991 729
190 787
179 173
614
(195 580)
093 240
(639 672)
(875 540)
710,413
(12,538 689)
195 580
554 171
8,446 500
264 800
480 800
702,300)
3,489 800
064 371
135 916
038,841
081 395
(42 554)
(40 043)
(166 667)
(804 167)
986)
(870 676)
038 227
870 676
167,551
(9,504)
064
105
959
545
163 005
~/kWh
kWh
3707 0,3707 0,4024 0.4024 0.4024 0.4024
840 704 656 939 127 871 1 054,848 703 1 325 929 728 1 309 551 663 1 137 579,165
164 039 3 002 187 2 701 380 2 176 780 2,406 699 2 173,844
921 564
(250 506)
671 058
118
118
102 921
568,138
Note: Negative amounts indicate benefit to ratepayers
U:\kh"';o'pcB0607\Comp~y C".ITRUE UPS & RATES 51812006 KDH
568 138
(45 675)
13,482 882
47,005 345
342
342
923 845
081,500
081 500
081,500
73,469
73,469
627,910
41 ,453 589
41,453 589
41,453 589
089
089
107 691
345 898
345 898
345 898
576
576
341 123
004,775
004,775
004,775
675
61,675
112,169
34,892 606
2005
OCT
925 105
4.288
966 850
051 573
055 943
370
591
374 911
285 872
783
7,477 280
(13 902 800)
591
315 636
727,700
272,300
700
982 500)
053 200
737 564)
471 543)
068 572
792,830
(724 258)
(681,526)
(166 667)
(804 167)
986)
094 739)
167 551
094 739
927 189)
(4,545)
613
603
943
928 131)
0.4024
975,839 218
723,273
892 606
892,606
154
154
665,118
227,488
Attachment D
Case No. IPC-06-
Staff Comments
05/12/06 Page 10f2
DESCRIPTION
3 PCA Revenue
4 Normalized Idaho Jurisd, Sales
5 Forecast Rate
6 Revenue
8 Load Change Adjustment
9 Actual System Firm Load - Adjusted
10 Normalized Firm Load
11 Load Chan
12 Expense Adjustment (IID16,84)
14 Non-QF PCA
15 ACTUAL:
16 BPA Water Option Agreement
17 Cloud Seeding Program
18 Fuel Expense - Coal
19 Fuel Expense - Danskin
20 Fuel Expense - Bennett Mountain
21 Non-Firm Purchases
22 Surplus Sales
23 Ex ense Ad ustment 16,
24 Sub-Total
26 BASE:
27 Fuel Expense - Coal
28 Fuel Expense - Danskin
29 Fuel Expense - Bennett Mountain
30 Non-Firm Purchases
31 Surplus Sales
32 Sur lus Sales Adder
33 Sub-Total
35 Change From Base
36 Deferral (Shared and Allocated)
38 QF Deferral
39 Actuai (includes Net Metering)
40 Base
42 Change From Base
43 Deferral (Allocated)
45 Intervenor Funding
46 Credit From iDACORP Energy
47 Settlement Agreement (ON 29600)
48 Bennett Mtn. Credit (ON 29790)
49 Total Deferral (-6+36+43+45+46+47+48)
51 Principal Balances
52 Beginning Balance
53 Amount Deferred
54 Ending Balance
56 Interest Balances
57 Accrual thru Prior Month
58 Interest lID 2% per Year
59 Prior Month's interest Ad
60 Total Current Month Interest
61 Interest Accrued to Date
62 Balance (True-Up & Interest)
64 True-Up of the True-
65 True-Up Revenues66 True Up Rates67 Actual Idaho Sales68 Total
70 Beginning Balance
71 Adjustments per ON 2979372 Fuel Expense Adjustment73 Intervenor Funding
74 Irri ation Lost Revenues ON 29669
75 Sub-Total
76 Interest lID 2% per Year
77 Revenue Applied to Interest
78 Revenue Applied to Balance
79 True-Up of the True-Up Balance
TRUE-UP CALCULATIONS FOR 2005 - 2006
FOR
IDAHO POWER COMPANY PCA
CASE NO. IPC-06-
Staff Case
Units
MWh
mlKWh
MWh
MWh
MWh
2005
NOV
885 609
288
797,491
137 344
079 817
527
(968 755)
798 142
377 898
759
196 111
728 267)
968 755
675 887
8,445 200
264 700
610 900
(1,414 700)
906 100
769 787
192 633
095 280
204 739
(109,459)
(103 001)
(166 667)
(804 167)
986)
682 679)
927 189)
682 679
609 867)
(943)
212)
212)
155
619 022)
2005
DEC
965 920
288
141 865
354 735
220,489
134 246
260 703)
414 022
902,700
314 726
523 632
754 148
(15 037 170)
260 703
611 354
727 000
272 800
884 100
357 300)
526 600
084 754
315 978
315 598
193 531
122 067
114 865
(166 666)
(804 167)
986)
314,159
609 867)
314 159
704 291
155)
(11 016)
(11,036)
191
684 100
2006
JAN
043 993
288
4,476 642
244 146
207 127
019
(623 400)
140 182
9,468 720
885
790
190 694
(33,421 590)
623,400
175 719)
460 000
272 500
397 900
811 600)
318 800
(5,494 519)
653 308)
792 655
164 012
628 643
591 553
(804 167)
986)
346 550)
704 291
346 550
642 258)
(20 191)
174
175
016
656 274)
2006
FEB
968 236
288
151 796
124 755
032 883
91,872
547 124)
137 597
178 162
089
480
292 649
(32,412 950)
547 124
(12 263 097)
371,000
257 500
700
681 800)
35,400
(12 298 497)
(10,415 597)
707,472
073 610
633,862
596,464
(804,167)
(3,986)
(14,779 081)
642,258)
779 081
(20,421,340)
(14 016)
(9,404)
403)
23,419
(20,444 758)
rf,/kWh
kWh
0.4024 0.4024 0.4024 0.4024
890,496,444 1 005,408 010 1 078 920 738 1 016 643 093
568 690 1 889 864 1 988 372 1 739 243
227,488
227,488
379
379
513 310
714 178
Note: Negative amounts indicate benefit to ratepayers
U,~h",i""",(!607\Comp"'y C",\TRUE UPS & RATES 51812006 KDH
714 178
714 178
857
857
837 007
877 170
29,877 170
877,170
49,795
795
938 577
27,938 593
938 593
938 593
564
564
692 679
245 915
2006
MAR
909 048
288
897 998
139 815
040,475
340
(1,672 886)
102 305
762 059
016
205 921
12,443 565
(37,458 046)
672 886
(17 588 065)
282 200
273,400
700
074 900)
(441,600)
(17 146,465)
(14 521 342)
2,497 723
292 773
204 950
192 858
(804,167)
986)
(19,034 634)
(20,421 340)
034 634
(39,455 973)
(23 419)
(34 036)
276
(34 312)
730
(39,513 704)
TOTALS
12,096 838
751 234
718,687
107 573
611 114
(10 291 160)
108 094
100 632 189
992 041
995 540
188 243 754
(211,248 247)
10,291 160
432,211
149,400
256 600
12,376 900
(63 094 800)
688 100
744,111
20,955 787
45,912,878
46,413,057
(500 179)
(470 669)
(1,500 000)
650,000)
(39,858)
(39,455 973)
39,455,973
(57,488)
242
(57,730)
(39,513 704)
0.4024
954 795,701 12 529 844,990
776,360 26 310 731
245 915
245 915
743
743
732 617
513 298
416 271,416
(250 506)
(45 675)
13,482 882
429,458 117
715 764
594 967
513 298
Attachment D
Case No. IPC-06-
Staff Comments
05/12/06 Page 2 of2
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17
4
)
53
,
97
6
,
4
5
3
62
4
27
.
04
%
24
/
2
5
15
,
08
5
1,
5
7
4
,
10
0
,
11
7
79
,
06
7
,
33
8
(1
5
,
33
3
,
30
9
)
63
,
7
3
4
,
02
9
04
9
19
.
39
%
31
0
16
,
20
2
,
70
7
97
1
,
2
3
5
(1
5
7
,
62
0
)
81
3
,
61
5
02
1
16
.
23
%
12
9
18
,
7
0
4
,
63
6
00
5
,
92
6
(1
8
1
,
9
5
9
)
82
3
,
96
7
9.
7
5
1
07
%
84
2
,
17
3
30
8
99
2
(7
6
,
28
9
)
23
2
,
70
3
96
7
24
.
69
%
42
9
,
4
1
0
11
,
6
2
9
,
03
1
,
7
1
9
60
5
,
54
0
,
82
7
(1
1
3
,
17
4
,
7
0
7
)

4
9
2
,
36
6
,
12
0
23
4
18
.
69
%
67
3
,
7

6
0
,
25
0
21
,
4
2
5
,
92
6
(6
,
55
4
,
34
0
)
14
,
87
1
,
58
6
20
7
30
.
59
%
18
7
,
63
2
,
19
9
63
3
,
04
1
(1
,
82
5
,
28
6
)
80
7
,
7
5
5
02
9
32
.
4
0
%
20
4
,
7
3
8
,
94
3
23
7
,
19
5
(1
,
9
9
1
,
7
0
0
)
24
5
,
4
9
5
07
4
31
.
93
%
06
6
,
13
1

,
39
2
33
,
29
6
,
16
2
(1
0
,
37
1
,
3
2
6
)

2
2
,
92
4
,
83
6
15
0
31
.

1
5
%
42
9
,
4
1
3
12
,
69
5
,
16
3
,
11
1
63
8
,
83
6
,
98
9
(1
2
3
,
54
6
,
03
3
)

5
1
5
,
29
0
,
95
6
05
9
19
.
34
%
Ba
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w
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b
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O
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2
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.

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a
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M
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3
1

,
2
0
0
6
.
CERTIFICATE OF SERVICE
HEREBY CERTIFY THAT I HAVE THIS 12TH DAY OF MAY 2006
SERVED THE FOREGOING COMMENTS OF THE COMMISSION STAFF, IN
CASE NO. IPC-06-, BY MAILING A COpy THEREOF, POSTAGE PREPAID, TO
THE FOLLOWING:
BARTON L KLINE
MONICA MOEN
IDAHO POWER COMPANY
PO BOX 70
BOISE ID 83707-0070
GREGORY W SAID
DIRECTOR, REVENUE REQUIREMENT
IDAHO POWER COMPANY
PO BOX 70
BOISE ID 83707-0070
SECRETAR ,
CERTIFICATE OF SERVICE