20031021Obenchain Workpapers (21MB).pdf

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-03-13
IDAHO POWER COMPANY
P. OBENCHAIN
WORKPAPERS
IDAHO POWER COMPANY
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
TWELVE MONTHS ENDING DECEMBER 31, 2003
WORKPAPERS FOR THE
JURISDICTIONAL SEPARATION STUDY
Table of Contents
Description
Electric Plant in Service
Accumulated Provision for Depreciation and
Amortization of Other Utility Plant
/\dditions and Deductions to Rate Base
Operating Revenues
Operation and Maintenance Expenses
Depreciation and Amortization Expenses
Taxes Other Than Income Taxes
Income Taxes
Labor Allocator
Energy Allocation Factors
Demand Allocation Factors
Rate of Return and IERCO
Page No.
1-34
35-51
52-72
73-105
106-167
168-182
183-199
200-209
210-227
228-288
289-292
293-296
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No
1 Actual
2 Actual
J Actual
4 Actual
5 Actual
6 Actual
7 Actual
IDAHO POWER COMPl\NY
ELECTRIC PLANT IN SERVICE
For The Thirteen Months Ended December 31, 2003
Month
December, 2002 .
January, 2003 .
Pcbruary .
March .
April .
May .
June .
( 1)
Amount
$3,087,419,093
3,094,125,058
3,108,132,719
3,11"3,%1,0JJ
3,122,816,311
3, 134, 4'73. 379
8 Forecast July . 3,140,354,884
9 Forecast August .
10 Forecast September .
11 Forecast October .
12 Forecast November .
13 Forecast December .
14 Average .
3,147,510,909
3,160,280,091
3,171,438,795
J,Hl2,U48,JJ.4
3,212,590,750
$3,136,446,862
•
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Idaho Power Company
Before The Idaho Public Utilities Commission
Additional Ratcba$C and Cxpcn$C Adju$lmcnt$
Account
No. Ratebase Revenue Exeense
Description
Incremental Security Costs Order 28975 182 s 728,766 (1)
Intervenor Funding· DSM/Land and Water Fund of the Rockies 928 $ 4,953
Prairie Acquisition Adjustment 114 $ (454,449)
115 259,413
$ (195,036) (1)
Other Operating Revenue · Cable One 454 $ 346,171
Asset Retirement Obligation :(3)
Electric Plant in Service 101 $ (1,577,314)
Accum Resv for Depree 108 $ 106,204,710
Prepaid Pension 165 $ 17,800,477 (2)
(1) Included in 2003 operating costs.
(2) Included in 2003 operating costs and known and measurable adjustments .
(3) 13 month average
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IDAHO POWER COMPANY
Cost of Metering Allocation
Test Year 2003
Cost of Resale
Metering Allocation Acct. 370
Re�ort E10 "E10" Allocation
Idaho 36.731.736 13,275,012 423,834 37,155,570
Oregon 1,892,384 696,678 22,243 1,914,627
Raft River 44,430 56,567 1,806 46,236
City of Weiser 4,695 52,119 1,664 6,359
City of Seattle 2,785 0 0 2,785
BPAOTEC 180,103 0 0 180, 103
Colton (ABC) 0 27,200 868 868
BPA So. Id. 0 0 0 0
TOTAL 38,856,133 14,107,576 450,415 39,306,548
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Total • Total Company Company Idaho Oregon
1 - Residential Serv. 17,824,642 17, 105,004 719,638
7 - Small General Serv. 4,635,516 4,367,879 267,637
9P - Large General Service 722,630 698,403 L4,Z2f
9S - Large General Service 8,308,381 7,932,059 376,322
9T - Large General Service 21,226 21,226 0
19P - Uniform Rate-Industrial 743,607 692,935 50,672
19S - Uniform Rate-Industrial 3,178 3,178 0
19T - Uniform Rate-Industrial 107,433 29,863 77,570
248 - Irrigation & Pump. 5,877,022 5,521,981 355,041
258 - Irrigation & Pump. 127,910 127,910 0
87 - CSPP Contracts 204,248 182,971 21,277
Sub-Total 38,575,793 36,683,409 1,892,384
Special Contracts 48,327 48,327 0
Total Sales for Resale 232,013 0 0
Total 38,856,133 36,731,736 1,892,384
In Inventory 2, 189,830
Total With Inventory 41,045,963
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" IDAHO POWER COMPANY
COST OF METERING RPORT BY STATE BY RATE CLASS
TWELVE MONTHS ENDING DECEMBER 31, 2002
IPCO METER INFORMATION SYSTEM COST OF Ml: I t:HIN\:i REPORT l'OR TOTAL COMl'ANY
$1.?!i!'l.124 $41.496.380
f.%fll.F
i'f;lY?
.::?,/� Jg f!l�--92' ' +- .3 s-; 5'5 c;
'' (p Cj.?. 9 .3.5 )
1,280 $C,07S,0Hl 'IZ,71"' 430.098 TOTALS
METERS CURRENT TRANSFORMERS VOLTAGE TRANSFORMER TOTAL
RATE DESCRIPTION NUMBER DOLLARS NUMBER DOLLARS NUMBER DOLLARS OOLLARS
1 RESIDENTIAL SERVICE 350,325 $17,155,578 4,515 $667,295 7 $1,770 $17 .824.643
7 SMALL GENERAL SERVICE· ID & OR 35,317 $4,160,759 3,188 $467,966 30 $6,791 $4.635,515
9P LARGE GENERAL SERVICE- ID & OR 119 $322.066 351 $169,881 200 $230,684 $722,630
9S LARGE GENERAL SERVICE- ID & OR 18.255 $5,086,983 21,059 $3,127,574 157 $93,824 $8,308,381
9T LARGE GENERAL SERVICE- ID & OR 3, $4,027 7 $14,198 7 $3,001 $21,226'
10P UNll'OAM AATF-INDUSTRIAL 101 S276.433 297 $186,978 263 $240,134 $703,545
19S UNIFORM RATE-INDUSTRIAL 1 $2,785 3 $090 0 $0 S3.178
19T UNIFORM RATE-INDUSTRIAL 9 $18.910 24 $41,930 24 $46,593 $107.433
24S IRRIGATION 16,519 $4.689.254 8.264 $1,179,457 72 $8,312 $5,877,023
25S IRRIGATION (TOUl 219 $72,833 248 $43,137 9 $11,940 $127,910
87 CSPP CONTRACTS 87 $104,785 168 $50,734 89 $48,729 $204,248
·······••• SUB-TOTAL 420,955 $31,894,412 38,124 $5,949,544 858 $691,777 $38,535,732
SPECIAL CONTRACTS 22 $27,435 61 $27.621 42 $38,029 $93,084
SALE FOR RESALE 40 $70,810 99 $215.400 70 $391,523 $677,733
IN INVl'NTORY 9.081 $1,375.582 4.430 $682,454 310 $131,795 $2,189,830 ........... ,, .. ..
I I (
IPCO METER INFORMATION SYSTEM COST OF METERING REPORT FOR THE STATE OF IDAHO
METERS CURRENT TRANSFORMERS VOLT AGE TRANSFORMER TOTAL
RATC DCOCntl'TIOH NIIMAl'A DOLLARS -·- NUMBER DOLLARS NUMBER DOLLARS DOLLARS 1 RESIDENTIAL SERVICE 336,883 $16,490,926 4,230 :1>1:mi.388 0 :S1,051 :,17,100,004 "i
7 SMALL GENERAL SERVICE·IDAHO 32,940 $3,927,073 2,981 $435,742 22 $5,064 $4,367,879 ']
9P LARGE GENERAL SERVICE·IDAHO 114 $308,141 336 $164,558 188 $225,704 $698,403 ']
9S LARGE GENERAL SERVICE-IDAHO 17.345' $4.850,827 20,121 $2,987,779 153 $93.453 $7,932,059 Y\
9T LARGE GENERAL SERVICE-IDAHO 3 $4,027 7 $14.198 7 $3,001 � w 19P UNIFORM RATE-INDUSTRIAL 96 $262,509 282 $172,361 248 $222,506 ( 195 UNIFORM RATE-INDUSTRIAL 1 S2,785 3 $393 0 $0 $3,178 V\
19T UNIFORM RATE-INDUSTRIAL 7 $13,340 18 $5,930 18 $10,593 $29,863 v\
240 1nn1CATION 15.082 $4,364,263 8,Q76 $1,150,333 62 $7,385 $5,521,981 'I
25S IRRIGATION (TOU) 219 $72,833 248 :b'\3,137 9 ¢11,040 $127,010 '\ i 87 CSPP CONTRACTS 83 $100,904 163 $40,697 84 $41,369 $182.971 I •••••••••• SUB-TOTAL 402,773 $30.397 ,628 36.465 $5,627,518 797 $622,706 S36 f\11lil!i2
\ SPECIAL CONTRACTS 22 $27,435 61 $27.621 42 $38,029 k$93,084 }) \ ••••••••·•TOTALS 402,795 $30,425,063,, 36,526 $5,655.138 839 $660,735 06,740,936 -, s 35: 55'1 ( TT-I 5C--O) _ 40,oc, a <, -r - -tc-e=
IPCO METER INFORMATION SYSTEM COST OF METERING REPORT FOR THE STATE OF OREGON '$';../f, 3o! ,> --- METERS CURREN I I HAN::;FQRMERS VOLTAGC TnANSFOAMEA TOTAi
RATE DESCRIPTION NUMBER DOLLARS NUMBER DOLLARS NUMBER DOLLARS DOLLARS
1 !RESIDENTIAL SERVICE 13,442 $664,652 285 $54,907 1 $80 5719,638
7 iSMALL GENERAL SERVICE-OREGON 2,377 $233,686 207 $32,223 8 $1,727 S267,637
9PlLARGE GENERAL Sl::HVlt.;t:·QREGQN :; $13,02� 1� $5.323 12 $4,979 $24,227 SS LARGE GENERAL SERVICE-OREGON 910 $236,157 938 $139,795 4 $371 $376,3l�
'19P UNIFORM RATE-INDUSTRIAL 5 $13,924 15 $14,617 15 $17,628 (l;46,169 l
19T UNIFORM RATE-INDUSTRIAL 2 $5,570 6 $36,000 6 $36,000 �u
�4$ IRAIGATION 1.,437 $324,990 188 $29,124 10 $927 ..$355,041
87 CSPP CONTRACTS 4 $3,881 5, s 10,037 s $7,!l6Q / S:21.?77
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IDAHO POWER COMPANY
DISTRIBUTION SUBSTATIONS
DY STATE COUNTY & LOCATION
December 31, 2002
LANO & UND RJGIITS STRUCTtfRES & IMPROVEMENTS STATION EQUIPMENT TOT AL INVESTMENT
ACCTJ6tl ACCI 361 A.CCT362
.ATION LOCCODE Pl••• C!AC Pliml C!AC Pl•nt C!AC ...... C!AC NdlbYnC-nl
REGON
Easton Substation :�Jt.$mi,,: 14,603 (23,893) 49,443 (91,357) 64,046 (115,249) (51,203)
ID/\110
Ampot Substation STAMPO 77,727 (8,557) 126,245 (24,231) 203,972 (32,788) 171,184
Armacost Substation l�':;1 4,830 (3.215) 17,034 (4,435) 21,865 (7,650) 14.ZIS
Bcartrack Substation STBRTK 10,429 (7,453) 19.095 (13,646) 29,524 (21,099) 8,41S
Bethal Court Substation STBCRT 204,988 (55,020) 383,686 (147,167) 789,032 (259,869) 1,377,706 (462,056) 915,650
Black Mesa Substation STBMSU 282 13,433 (2.328) 151,771 (25.073) 165,485 (27,401) 138.084
Blacker Substation STBLKR 1,193 (393) 29,757 (14,487) 30,950 (14,880) 16,070
Blacks Creek Substation STBSCR 38,647 (27,903) 95,775 (53,265) 134,422 (81,168) 53,254
Boise Bench Transm. Station STBOBN 1,355 132,436 1,672,329 (l,460) 1,806,121 (1,460) 1,804,661
Boise Dist Substation Storage STBDSS 5,380,709 (11,643) 5,380,709 (11,643) 5,369,066
Border Substation STBRDR 50 82,016 386,467 (71,691) 468,532 (71,691) 396.841
Burley Rural Substation STBYRL 1,856 37,660 (18,204) 348,158 (46,782) 387,674 (64,986) 322.688
Don Substation STDONN 1,536 488,739 (10,307) 5,621,593 (326,275) 6,111,868 (336,582) 5,775,286
Dram Substation STD RAM 2,664,507 (2,741,693) 8,991,326 (8,614,111) 11,655,833 (11,355,804) 300,029
Eastgate Substation STETGT 16,426 83,883 814,304 (4,000) 914,614 (4,000) 910,614
Elkhorn Substation STEKHN 18,428 109,765 (1,633) 383,597 (5,301) 511,790 (6,934) 504,856
Emmett-Boise Cascade # I Subst STBECE 33,397 (25,925) 362,140 (36,575) 395,536 (62,500) 333,036
fatrtlelO suosrauon STFR!'D 391 (391) 3,482 (J,482) J,87J (J,873) 0
Glenns Ferry Substation STGFRY 16,987 107,997 (12,856) 492,484 (167.010) 617,468 (179,866) 437,601
Grove Substation STGRVE 46,950 142,121 6,393,728 (42,095) 6,582,799 (42,095) 6,540,703
Hewlett Packard Substation STHPKD 79,863 (53,200) 902,031 (604,511) 981,893 (657,711) 324,183
l-li.dd.n LOk• Subctotion �TJ.IDLk'_ «n ,.oH (�'�) l<,IQ7 (QQQ) 1-Ci,Qfl' (1,t,7) u.n,�
Hidden Springs Substation STHDSP 39,346 (417) 208,391 (1,923) 323,527 (2,611) 571,263 (4,950) 566,313
Jerome Substation STJRRL 1,012 250,014 1,130,613 (9,503) 1,381,639 (9,503) 1,372,136
Jones Ranch Substation STJSRN 20,697 (1,217) 28,024 (11,046) 48,721 (12.263) 36,458
Karcher Substation STKRCH 3,201 (1,743) 187,943 (102,363) 850,040 (651,421) 1,041,184 (755,527) 285,656
Ketchum Substation STKCHM 415 266,389 1,315,906 (17,301) 1,582,710 (17,301) 1�5,409
Lamb Substation STLAMB 5.220 <12,840 (173) 268,951 (877) 317,01) (l,050) 315,961
Lincoln Substation STLCNS 17,553 (518) 127,166 (3,754) 258,921 (5,728) 403,641 (10,000) 393,641
-nden Substation SlLNDN 9,140 200,67[ 1,853,127 (48,508) 2,062,937 (48,508) 2,014,429
icron Substation STMCRN 287,146 (359,387) 2,193,871 ( 1,622,471) 2,481,017 (1,981,858) 499,159
Mmmtain Home Afu Substation STMHAB 60,727 (10.081) 244,005 (92,817) 304,732 (102,897) 201,834
Nampa Substation STNMPA 3,567 118,851 2,136,907 (51,518) 2,259,325 (51,518) 2,207,807
Norco Substation (Cust, owned) STNRCO 23,783 (1,736) 23,783 (1,736) 22,047
Russet Substation STRSET 9,260 87,051 (14,306) 886,298 (30,714) 982,609 (45,021) 937,588
Sailor Creek Substation STSRCK 5,889 98,128 615,923 (2,500) 719,940 (2,500) 717,440
Scott Valley Substation ST SCOT 7,428 (10,975) 19,420 (15,357) 26,847 (26,332) 515
Simplot Substation STSMPT 1,966 163,677 (107,781) 495,573 (243,893) 661,216 (351,674) 309,542
South PIIR. Subd:S1tion STSOPK ,,RR, 7h,701 IR5.IR1 (11.511) 21�.2M (ll.�13) 2"1,7�1
Squaw Creek Substation STSQCK 4,090 (1,086) 10,269 (2,131) 14,359 (3,217) 11,142
Stoddard Substation STSTRD 678,996 (30,000) 161,733 (55,577) 1,585,148 (500,190) 2,425,878 (585,767) 1,840,111
Sugar Substation STSUGR 132,011 (32,198) 410,809 (159,198) 542,820 (191,396) 351,424
T erry Substation STTERY 39,709 166,356 (76,637) 1,488,568 (629,219) 1,694,633 (705,855) 988,778
Three Creek Substation STTHCK 1,376 (l,085) 138,978 (106,916) 325,569 (246,938) 465,923 (354,940) 110,983
T oponis Substation STTOPN 28,625 57,020 (16,495) 418,543 (149,619) 504,188 (166,114) 338,074
Victory Substation STVTRY 58,302 133,771 1,438,451 (87,709) 1,630,524 (87,709) 1,542,815
Wilder Substation STWLDR 82.006 (82.006) 168,860 (141,636) 250,865 (223,642) 27,224
Wye Substation s·1wYt::t:. ·1,100 \14,b/M IM4.ULL (L,4YI) l,735,807 (2,491) 1,733,316
Zilog Substation STZLOG 1,137 (857) 214,016 (118,645) 1.399,106 (418,910) 1,614,259 (538,412) 1,075,847
TOTAL ALL 1122s1234 !89,641! 7,847�31 !4,187.466) 54,753,112 (151581,!!53} 63,825,677 !19,858,959} 137.643,646
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IDAHO POWER COMPANY
ACCUMULATED PROVISION FOR DEPRECIATION
For The Thirteen Months Ended December 31, 2003
October..................................................... 1,193,688,4.10
November. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1, 200, 091, 813
March....................................................... 1,154,752,250
December.................................................... 1, 199, 531, 838
1. ?.7F.. 7fi"i. <nn
Average $1,201,647,086
( 1)
Month Amount
September................................................... 1,187,705,483
August........................................... . . . . . . . . . . 1,183,872,283
J·uly..... .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,177,301,131
June . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 , 170 , 4 0 8 , 0 6 6
April....................................................... 1,159,124,631
February.................................................... 1,284,008,956
May......................................................... l,1b4,'::J4/,l:5/4
January, 2003 .
December, 2002. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $1, 269, 613, 653
•
Line
No
1 Actual
2 As::tual
3 Actual
4 Ac t ua I
5 Actual
6 Actual
7 Actual
8 Forecast
9 Forecast
10 Forecast
11 Forecast
12 Forecast
13 Forecast
14
IDAHO POWER COMPANY
ACCUMULATED PROVISION FOR AMORTIZATION
OF ELECTRIC UTILITY PLANT
For The Thirteen Months Ended oecernl.Jt:L 31, 2003
November .
Month
March .
( 1)
Amount
34,658,203
3-1,573,895
33,756,859
32,939,823
32,122,787
31,305,751
29,671,679
30,488,715
27,218,346
28,854,643
28,035,380
26,401,326
$30,431,656
$25, 584, 115
2003 .
December .
Augusc .
Average .
September .
October .
May .
July .
Apri] .
June .
January,
December, 2002 .
Line
No
1 Actual
2 Actual
3 :A.ctual
4 Actual.
5 Actual
6 Actual
7 Actual
8 Forecast
9 Forecast
10 Fnrpr;,st:
11 Forecast
12 Forecast
13 Forecast
14
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LINE
NO
Idaho Power Company
Detail of Annualizing Adjustment
Depreciation Expense in Account 403
2003 Expected to 2004 Depreciation using 12/03 Plant Balances
2
4
2003 Depreciation Expense - Expected
2004 Depreciation Expense based on 12/03 Plant
lncreuec to Dcprooio.tion ExpensG using December Plant
Increase to Depreciation Reserve Account 108 (Average)
$ 88,152,411
s 91,072,585
$ ?}"l?0,174 1
$ 1,460,087' 1
1 Detail by FERC categories: A/C 403 A/C 108
5 Total Steam Production $ 547,152 $ 273,576 • 6 Total Hydro Productirm $ 66,091 $ 33,046
7 Total Other Production $ 41,726 $ 20,863
8 Total Transmission Stations $ 241,636 $ 120,818
9 Total Transmission Lines $ 343,923 $ 171,961
10 Total Distribution Stations $ 151,689 $ 75,845
11 Total Distribution Lines $ 711,960 s 355,980
12 Total General $ 815,996 $ 407,998
13 Total Adjustment $ 2,920,174 $ 1.460.087
•
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NO
Idaho Power Company
Detail of Known and Measurable Adjustment
Depreciation Expense in Account 403
Adjust from Old Depreciation Rates to New Depreciation Rates
2
3
4
2004 Depreciation Expense - Expected Old Rates
2004 Depreciation Expense - Expected New Rates
Increase to Depreciation Expense using New Rates
Increase to Depreciation Reserve Account 108 (Average)
$ 91 ,072,585
$ 97,048,855
$ 5,976,270 t
S 2,988, 135 •
5 1 Detail by FERG categories: A/C 403 A/C 108
6 Total Steam Production $ (731 ,839) $ (365,919)
7 Total Hydro Production $ 1,450,788 $ 725,394 • 8 Total Other Production $ (252,608) $ (126,304)
\::! rotai Transmission Stallu11� $ (1 ,209,500) $ (610,751)
10 Total Transmission Lines $ 1,443,320 $ 721,660
11 Total Distribution Stations $ (1,144,416) $ (572,208)
12 Total Distribution Lines $ (5,243, 126) $ (2,621,563)
13 Total General $ 11,693,653 $ 5,846,826
14 Total Adjustment $ 5,976,270 $ 2,988,135
•
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Idaho Power Company
Before The Idaho Public Utilities Commission
Additional Ratebase and Expense Adjustments
Account
Line No. Ratebase Revenue Exeense
No. Description
Incremental Security Costs Order 28975 182 $ 728,766 (1)
2 Intervenor Funding - DSM/Land and Water Fund of the Rockies 928 $ 4,953
3 Prairie Acquisition Adjustment 114 $ (454,449)
4 115 259,413
5 s (195.036) (1)
6 Other Operating Revenue - Cable One 454 $ 346,171
A;:,;:,et netirement Obligation :(3)
7 Electric Plant in Service 101 $ (1,577,314)
8 Accum Resv for Depree 108 $ 106,204,710
10 Prepaid Pension 165 $ 17,R00,477 (2)
(1) Included in 2003 operating costs.
(2) l11t;lu<.Jt,<.J i11 2003 ope,ating coete and known and mcaourablo adjuctmontc.
(3) 13 month average
IDAHO POWER COMPANY - JURISDICTIONAL SEPARATION STUDY
ACTUAL, ESTIMATED AND ADJUSTED DATA
TWELVE MONTHS ENDED DECEMBER 31, 2003
1 Results may be entered directly into data (D) (F) (G) (H)
2 sheet with a "values only" copy/paste. TOTALS ANNL. K.&M. OTHER
3 DESCRIPTION PER BOOKS ADJUST. ADJUST. ADJUST. • 4 •••SUMMARY OF ADJUSTMENTS • • •
5
6 D<?pr,;,ci�tinn Arlj, 1stmi>nts ·
7 Total Steam Production 273,576 (365,919)
8 Total Hydro Production 33,046 725,394
9 Total Other Production 20,863 (126,304)
10 Total Transmission Stations 120,818 (619,751)
11 Total Transmission Lines 171,961 721,660
12 Total Distribution Stations 75,845 (572,208)
13 Total Disu iuuliu11 Lines 355,080 (2,621,663)
14 Total General 407,998 5,846,826
15 Total Adjustment 1.460,087 2.988.135
16
17 Plant Additions:
18 Total Steam Production 103,865 0
19 Total Hydro Production 0 0
20 Total Other Production u u
21 Total Transmission Stations 31,760 170,972
22 Total Transmission Lines 113,589 52,715
23 T otc! Dietribution Gtefienc 0 0
24 Total Distribution Lines 0 0
25 Total General 0 0
26 Total Adjustment 249,214 223,687
27
28 Total of All Adjustments 1,709,301 3,211,822
29 • 30 •••TABLE 2 ·ACCUMULATED PROVISION FOR VtPRtGIA 1/UIV • • •
31
32 PRODUCTION PLANT
33 310-316 / STEAM PRODUCTION 337,245,038 377,441 (365,919) 106,204,710
34 330-336 / HYDRAULIC PRODUCTION 242.185,180 33,046 725,394 0
35 340-346 / OTHER PRODUCTION 3,364,651 20,863 (126,304) 0
36 TOTAL PRODUCTION PLANT 582, 794,869 431,350 233,171 106,204,710
37
38 TRANSMISSION PLANT
39 350 I LAND & LAND RIGHTS 3,046,052 4,074 (20,896) 0
40 352 / STRUCTURES & IMPROVEMENTS 17,083,459 22.847 (117,195) 0
41 353/STATION EQUIPMENT 70,211,579 125,658 (310,688) 0
42 354/TOWERS & FIXTURES 22,825,308 39,305 164,947 0
A..1 :lffi I POI FS R. FIXTt JRFS 37.267.927 64.174 269.317 0
44 356 I OVERHEAD CONDUCTORS & DEVICES 39,535,894 181,669 338,421 0
45 359 I ROADS & TRAILS 233,934 403 1,691 0
46 TOTAL TRANSMISSION PLANT 190,204.153 438,128 325,596 0
•
pao: Adjust_Dep-403 & 108.Depreciation_Reserve.8/1512003.6:44 AM. Page 1 of 2
IDAHO POWER COMPANY - JURISDICTIONAL SEPARATION STUDY
ACTUAL, ESTIMATED AND ADJUSTED DATA
TWELVE MONTHS ENDED DECEMBER 31, 2003
1 Results may be entered directly into data (D) (F) (G) (H)
2 sheet with a "values only" copy/paste. TOTALS ANNL. K.&M. OTHER
3 DESCRIPTION PER BOOKS ADJUST. ADJUST. ADJUST . • 47
48 DISTRIBUTION PLANT
4.Cl �nO / I ANn P., I AN[) RIGHTS 0 0 0 0
50 361 I STRUCTURES & IMPROVEMENTS 5,395,702 11,082 (83,606) 0
51 362 I STATION EQUIPMENT 31,533,125 64,763 (488,602) 0
52 364 / POLES, TOWERS & FIXTURES 74,999,917 81,661 (601,380) 0
53 365 I OVERHEAD CONDUCTORS & DEVICES 31,7 46,305 34,566 (254,555) 0
54 366 I UNDERGROUND CONDUIT 6,469,087 7,044 (51,872) 0
55 367 I UNDERGROUND CONDUCTORS & DEVICES 43,542,692 47,410 (349,143) 0
:36 308 I LINE TRANSFORMERS 133,107,304 144,020 (1,067,308) 0
57 369 / SERVICES 26,240,066 28,571 (210,403) 0
58 370 I METERS 7,557.285 8,228 (60,597) 0
59 371 / INSTALLATIONS ON CUSTOMER PREMISES 922,222 1,004 (7,395) 0
60 373 I STREET LIGHTING SYSTEMS 2,358,335 2.568 (18,910) 0
61 TOT AL DISTRIBUTION PLANT 363,872,041 431,825 (3,193,771) 0
62
63 * * * TABLE 2 · ACCUMULATED PROVISION FOR DEPRECIA TJON * * •
64
65 GENERAL PLANT
00 :JOc> I LAND 6. LAND nlCI ITC 0 0 0 0
67 390 I STRUCTURES & IMPROVEMENTS 13,328,637 83,952 1,203,072 0
68 391 I OFFICE FURNITURE & EQUIPMENT 21,518,833 135,538 1,942,337 0
69 392 ITRANSPORTATION EQUIPMENT 16,371,800 103,119 1,477,755 0
70 393 / STORES EQUIPMENT 326,399 2,056 29,462 0
71 394 I TOOLS, SHOP & GARAGE EQUIPMENT 1,238,927 7,804 111,828 0
72 395 I LABORATORY EQUIPMENT 3,521,866 22,183 317,891 0 e 73 396 I POWER OPEKA 11::U l::UUll-'Ml::N I 3,480,096 21,900 314,627 0
74 397 /COMMUNICATIONS EQUIPMENT 4,370,637 27,529 394,503 0
75 398 I MISCELLANEOUS EQUIPMENT 613,227 3,862 55,351 0
76 TOT AL GENERAL PLANT 64,776,024 407,998 5,846,826 0
77
78 AMORTIZATION OF UTILITY PLANT 0 0 0 0
79
80 TOTAL ACCUM PROVISION DEPRECIATION 1,201,647,086 1,709,301 3,211,822 106,204,710
81
82 AMORTIZATION OF OTHER UTILITY PLANT
83 INTANGIBLE PLANT 30,419,360 0 0 0
84 HYDRAULIC PRODUCTION 12,296 0 0 0
85
An TOTAi AMORT OF OTHFR UTILITY PLANT 30.431.656 0 0 0
87
88 TOT AL ACCUM PROVISION FOR DEPR
89 & AMORTIZATION OF OTHER UTILITY PLANT 1,232,078,7 42 1.709,301 3,211,822 106,204,710
•
pao: Adjust_Dep-403 & 108.Depreciation_Reserve.8115/2003.6:44 AM. Page 2 of 2 !ii
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•
IDAHO POWER COMPANY
CUSTOMER ADVANCES FOR CONSTRUCTION
For The Thirteen Months Ended December 31, 2003
•
Line
No
1 Actual
2 Actual
3 Actual
4 Actual
5 Accual
6 Act.ua l
't Actual
8 Forecast
9 Forecast
10 Forecast
11 Forecast
12 Forecast
13 Forecast
14
December, 2002 .
January, 2003 .
February .
March .
April .
May .
June .
July .
August .
September .
October .
November .
December .
( 1)
Amount
$10,505,595
10,361,853
10,157,018
10,ll0,65L
10,423,011
10,953,850
10,CJlr.,407
11,034,524
ll,4b/,':1b':J
11, 961, 9L18
11,781,036
11,522,121
11,379,331
Average ·=====$=1=0='=9=6=6='=8=7=0==
•
••
IDAHO POWER COMPANY
CUSTOMER ADVANCES FOR CONSTRUCTION
ACCOUNT #252
FOR THE THIRTEEN MONTHS ENDED DECEMBER 31, 2003
POWER OTHER TOTALS
MONTH SUPPLY (1) (2)
DECEMBER, 2002 0 10,505,595 10,505,595
JANUARY, 2003 0 10,361,863 10,361,863
FEBRUARY 0 10,157,018 10,157,018
MARCH 0 10,110,651 10, 110,651
APRIL 0 10,423,011 10,423,011
MAY 0 10,953,850 10,953,850
JUNE u lU,!:llU,40/ 10,910,407
JULY 0 11,034,524 11,034,524
AUGUST 0 11,467,969 11,467,969
SEPTEMDCR 0 11,061,9'18 11,961,948
OCTOBER 0 11,781,036 11,781,036
NOVEMBER 0 11,522,121 11,522, 121
DECEMBER 0 11,379,331 11,379,331
TOTALS 0 142,569,324 142,569,324
AVG OF 13 MONTHS u lU,!::106,8/1 10,966,871
JURISDICTIONAL (1) 12/31/02 % 12/31/03 13-MONTH
SPLITS AVERAGE
IPUC 10,448,354 99.46% 11,317,329 10,907,116
OPUC 57,241 0.54% 62,002 59,754
PSCN 0 0.00% 0 0
TOTALS 10,505,595 100% 11,379,331 10,966,870
(2) Financial Reports - Balance Sheet, p.2
CUSTADV - 2003
IDAHO POWER COMPANY
2003 RATE CASE ESTIMATE
DEFERRED INCOME TAX BALANCES • BEGINNING CHANGE IN ENDING ADJUSTED
BALANCE BALANCE BALANCE AVERAGE
BALANCE
ACCOUNT 190 - ACCUM DEF INC TAXES
004003-CONSTRUCTION ADV-252 3,758,549 305,808 4,064,357 3,911,453
005010-SFAS 112-POST-EMPLY BEN 182/253 850,104 26,917 877,021 863,562
005033-NONVEBA PEN&BEN-Acct 228 977,195 11,015 988,210 982,702
005044-RESTRICTED STOCK PLAN-COMP 449,871 (158,507) 291,364 370,618
005047-0THER EMPLOYEE'S LT DEFERRED COMP-228 203,726 43,281 247,007 225,367
007007-0THER REGULATORY UABILITIES-254 1,020,870 (477,383) 543,487 782,179
008001-VEBA·POST RET BNFTS-TRUST-ACCT 165 (456,827) (90,591) (547,418) (502,123)
TOTAL 190 6,803,488 (339,460) 6,464,028 6,633,758
ACCOUNT 282 - ACCUM DEF INC TAXES· OTHER PROPERTY
LIBERALIZED DEPA - ELEC PLANT (213,352,493) (4,855, 118) (218,207,611) (215,780,052)
BRIDGER PRTNRSHP CPTLZD ITMS - DEF ONLY (632,057) 102,400 (529,657) (580,857)
FERC JURISDICTION - S. GEORGIA & 144A (7,368,363) (337,604) (7,705,967) (7,537,165)
N VALMY PRTNRSHP CPTLZD ITMS - DEF ONLY (1,039,766) 76,500 (963,266) (1,001,516)
PERCENTAGE REPAIR ALLOWANCE· DEF ONLY (560,785) 169,200 (391,585) (476,185)
TOTAL282 (222,953,464) (4,844,622) (227,798,086) (225,375,n5)
ACCOUNT 283-ACCUM DEF INC TAXES· OTHER
005008-GAIN/LOSS ON REACQUIRED DEBT-DEFERRED (1,091 ,668) 246,099 (845,569) (968,619)
005039-POST RETIREE BENEFIT· FAS106·ACCT 182 (445,204) 212,990 (232,214) (338,709)
005041-SUN VALLEY FAC -- REV AMORT (4,836) 4,820 (16) (2,426)
008020-CONSERVATION PROGRAMS (10,426,491) 1,291,646 (9, 134,845) (9,780,668)
008054-MERIDIAN CONTRACT BUYOUT (169,319) 168,758 (561) (84,940)
008057-REORGANIZATION COSTS-ACCT 182 (887,335) 294,798 (592,537) (739,936)
008071-PHOTOVOL T AIC STARTUP COSTS-ACCT 182 (19,456) 9,308 (10,148) (14,802)
008074-INCREMENTAL SECURITY COSTS DEDUCTED (332,373) (73,243) (405,616) (368,995)
008075-SECURITIZATION COSTS 0 0 0 0
FERG JURISDICTION- 144A 697,937 (80,137) 617,800 657,869 • TOTAL283 (12,678,745) 2,075,039 (10,603,706)- (11,641,226)
TOTAL DEFERRED TAX BALANCES (228,828,721) (3, 109,043) !231,937, 764) !230,383,243)
k:\INC\FIN\2003\RATE CASE\2003 RATE CASE DEF TAX BALANCES-EXHIBIT.xis
8/7 /2003 4:00 PM
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FINANCIAL FORECAST
INPUT PAGE
Month BRIDGER BOARDMAN VALMY BRIDGER BOARDMAN 100% VALMY BRIDGER BOARDMAN VALMY
Jul-02 $ $ $ $ $ $
Aug-02 $ $ $ $ $ $ 10,488 9,810 9,733
Sep-02 $ $ s s :i, $
Oct-02 $ $ $ $ $ $
Nov-02 $ $ $ $ $ $
Dec-02 $ $ $ $ $ $
2002 $ $ $ $ $ $ 9,192 8,653 10,722
Jan-03 $ 278,300 $ 23,900 S 63,700 $ 8,494 $ 4,600 S 57,314
Feb 03 $ 278,300 $ 23,900 s fi'.'l,700 $ 8.494 $ 4.600 S 57.314 tte>iecast•Us.a
Mar-03 $ 278,300 $ 23,900 $ 63,700 s 8,494 $4,600 s 28,740
Apr-03 $ 278,300 $ 23,900 $ 63,700 $ 8,494 $ 4,600 $ 28,740 General Rate Case
May-03 $ 278,300 $ 23,900 $ 63,700 $ 8,494 $ 4,600 $ 28,740
Jun-03 $ 278,300 $ 23,900 $ 63,700 $ 8,494 $ 4,600 $ 28,740
Jul-03 $ 278,300 $ 23,900 $ 63,700 $ 8,494 $ 4,600 $ 28,740
Aug-03 $ 278,300 $ 23,900 $ 63,700 $ 8,494 $ 4,600 $ 28,740
Scp-03 $ 278,300 $ 23,900 $ 63,700 $ 8,494 s 4,600 s 58,203
Oct-03 s 278,300 $ 23,900 $ 63,700 $ 8,494 $ 4,600 $ 58,203 0.570 0.566 0.453
Nov-03 $ 2l!!,;jUU !Ii lJ,�UU :I> t:>3,700 ,1i 0,494 $ 4,000 $ :i0,200
Dec-03 $ 278,300 $ 23,900 $ 63,700 $ 8,494 $ 4,600 $ 58,203
2003 $ 3,339,600 s 286,800 $ 764,400 $ 101 928 $ 55,200 $ 519,880
NOTES: 1) December 2002 Ending Tnventory from Fuel Inventory Report
2) Uses available coal from 2004 contracts and estimated 2004 pricing
3) Uses Heat rates, tons/mwh and btu/lb from July 10, 2003 RMC Forecast
4) Uses 2004 Unit train/Depreciation and Oil, Plant Handling and A&G
•
NOV-03 4,4,672
Dec-03 469,827
•
MONTH
Jan-03
Feb-03
Mar-03
Apr-03
May-03
Jun-03
Jul-03
Aug-03
Sep-03
Oct-03
MWH
469,827
424,360
469,827
,n,;,7,,
367,053
397,836
469,827
469,827
454,672
469,827
IOAHO POWER COMPANY
Coal Purchases and Consumption-Tiber Case
2003
MJLL OIL, A&G, COAL ACCT. 151 ACCT. 501
RATE $/MMBTU HANDLING CONSUMED PURCHASES FUEL EXP
12.24 S 1.1679 S 278,300 s 5,749,709 s 7,104,219 s s.ezs.oos
12.64 S 1.2065 S 278,300 s 5,365,009 $ 5,282,066 $ 5,643,309
12.66 s 1.2081 s 278,300 s 5,947,882 s 5,632,465 $ 6,226,182
17..R I s 1.2223 s 278,300 s 5,459,424 s 5,261,203 s 5,737,724
12.68 s 1.2097 s 278,300 s 4,653,053 $5,515,112 $ 4,931,353
11.80 s 1.1265 s 278,300 s 4,696,345 s 5,558,893 s 4,974,645
11.31 s 1.0792 s 278,300 s 5,313,192 s 4,845,076 s 5,591,492
11.08 s 1.0574 s 278,300 s 5,206,071 s 4,677,706 s 5,484,371
11.00 s 1.0498 s 278,300 s 5,001,846 S 5,167,372 $ 5,280,146
11.00 s 1.0493 s 278,300 s 5,165,901 S 5,286,822 s 5,444,201
11.01 s 1.0504 s 270,300 s s,001,1n S 4,595,099 ,: ,_7l0,7,X
11.21 s 1.0694 s 278,300 s 5,264,987 s 4,859,930 s 5,543,287
s 57,419 s L,J��·"'" s 2,2,1,s30 s 2,446,374
s 49,392 s 2,468,588 $ 2,257,889 s 2,517,980
S 2,881,299
S 2,491,228
s 1,323,147
t 1,K76,R7'; s 2,530,986 s 2,413,519 s 2,534,481 s 2,525,655
S 2,445,319
s 2,532,067
ACCT. 501
FUEL EXP
s 1,981,986 s 1,981,986 s 1,967,699
,: '.l,14,.noo
s 2,243,099 s 2,243,099 s 2,243,099 s 2,243,099 s 2,257,830
s 2,257,830
ACCT. 151
PURCHASES
MILL OJL,A&G, COAL
RATE $/MMBTU HANDLING CONSUMED
15.27 s 1.5720 s 56,434 s 2,824,865
14.60 $ 1.5025 s 54,687 $ 2,436,541
14.12 s 1.4531 s 57,615 s 1,265,532
l:'l.79 s 1.4200 S: 50,606 t 1,1126,'.16!)
13.61 s 1.4009 s 57,672 s 2,473,314
13.48 s 1.3878 s 52,777 s 2,360,742
13.40 s 1.3794 s 56,416 s 2,478,065
13.35 s 1.3738 s 57,054 S 2,468,601
13.35 $ 1.3738 s 55,553 S 2,389,766
13.34 s 1.3733 s 63,892 S 2,468,175
184,987
166,936
89,656
132,396
181,754
175,112
184,934
184,978
179,071
185,009
179,071 13.34 s 1.3733
185,040 13.34 s 1.3733
MWH
Jan-03
Feb-03
Mar-03
Apr-03
May-03
Jun-03
Jul-03
Aug-03
Sep-03
Oct-03
Nov-03
Dec-03
MONTH
OIL,A&G, COAL
HANDLING CONSUMED
S 23,900 s 465,363
s 23,900 S 388,457
s 23,900 s 428,694 s ,lj,'JUO s 390,724
S 23,900 s 315,661
ACCT. 151 ACCT. 501
PURCHASES FUEL EXP
s 509,350 S 489,263
s 408,400 S 412,357
s 468,970 S 452,594
s 448,780 S 420,G24
s 105,550 S 339,561
s 206,500 S 23,900
s 408.400 s 425,575
s 448,780 s 449,201
s 428,590 s 442,654
S 468,970 $ 456,131
s 448,780 S 443,451
s 401,675
s 425,301
s 418,754
S 432,23 I
S 419,551
S 433,807 s 206,500 s 457,707
s 23,900 $
i: ?,,ooo
s 23,900
s 23,900
s 23,900
s 23,900
s 23,900
36,265 11.57 s 1.1811
37,425 11.59 $ 1.1834
MJLL
MWH RATE S/MMBTU
36,985 12.58 s 1.2845
31,966 12.15 s 1.2406
36,067 11.89 s 1.2135
33,763 11.75 s l.19Y6
26,813 11.77 s 1.2019
s
34,384 11.68 $ l.1916
36,583 I 1.63 s 1.1869
36,091 11.60 s 1.1846
37,344 11.57 $1.1817
Jan-03
Feb-03
Mar-03
Apr-03
May-03
Jun-03
Jul-03
Aug-03
Sep-03
Oct-03
Nov-03
Dec-03
MONTH
IDAHO POWER COMPANY
MATERIALS AND SUPPLIES
For The Thirteen Months Ended December 31, 2003
(1) (2) (3)
Line Account Account
......!!9- Month 154 163 Total
1 Actual December, 2002 ........................ $18,938,667 $2,519,780 $21,458,447
2 Actual January, 2003 ......................... $18,578,365 $2,634,479 $21,212,844
Actual renrue r y .............................. ¢18, 591,769 S?.f;G?.047 $21. 276. 816
4 Actual March .......................... , ..... · $19,355,270 $2,552,486 $21,907,756
:; Actuo.l 1' ... pril, ... ,, .. · · .. · · · · · · · s1g_o58.0B8 $2,382,371 $21,440,459
6 Actual May ................................... $18,886,323 $2,234,116 $21,120,439
7 Actual June .................................. $19,020,707 $2,123,428 $21, 144, 135
8 Forecast July .................................. $19,229,490 $2,940,742 $22, 170, 232
9 Forecast August ................................ $19,229,490 $2,940,742 $22, 170, 232
10 Forecast September ............................. $19,229,490 $2,940,742 $22,170,232
11 Forecast October ............................... $19,229,490 $2,940,742 $22,1,0,232
12 Forecast November .................... · .......... $19,229,490 $2,9�0,742 $22,170,232
13 Forecast DecerrJ:>er .............................. $19, 229, 490 $2,940,742 $22,170,232
H Average ............................ $19,061,471 $2,675,628 $21,737,099
•
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65
Name of Respondent Thiswrtls: Date of Report Year of Report
Idaho Power Company (1) An Original (Mo, Da, Yr) 2002 (2) DA Resubmission 04/30/2002 Dec. 31, --
MATERIALS AND SUPPLIES , .. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a):
_ estimates of amounts by function am acceptable. In column (d), designate the department or departments which use the class of material.
• an explanation of important inventory adjustments during U,e year (in a footnote) showing general classes of material and supplies and the
r,, accounts (oparating exper.;�_ .. · ---· ::ig accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense
clearing, if applicable. -- Line Account Balance Balance oepanmemor
No. �innini of Year End of Year Departments which .&./ ! . 2.-oo 'Z... .,IAt>.-( "!. ! 2...uv'::, Use Material (a) {b) I (c) I (d)
1 Fuel Stock (Account 151) 8,726,387 6,942,920 Electric
2 Fuel Stock Expenses Undistributed (Account 152}
3 Residuals and Extracted Products (Account 153) � f}'J � ··-··-- 4 Plant Materials and Operating Supplies (Account 154) ,, 'J,4 i c ·-
5 Assigned to • Construction (Estimated) /
6 Assigned to - Operations and Maintenance
7 Production Plant (Estimated} ctlfrJ""L\\ 9,818,076 9,613,389 °l'6'7'7oif-c/
8 Transmission Plant (Estimated) 2- .s t. i/- &.,o 1 3,200,507 2,756,570 2 3"37.3'9D
9 Di:otribution Plant (Eotimatod) 7 0 7 t. c 7 � 6,77g,Q58 5.697.117 s: 7 , I J _::? </-
10 Assigned to - Other (provide details in footnote) >?!41./t+� 827,163 871,591 s n. «s :
11 TOTAL Account 154 (Enter Total of lines 5 thru 10) 1 <::; 7 2.. (,., y � (,,.,20, 7-05, 724 18,938,667 Electric ! l %8' � 3 2
12 Merchandise {Account lbb) , I
13 Other Materials and Supplies (Account 156)
14 Nuclear Materials Held for Sale (Account 157) (Not
applic to Gas Util)
15 Stores Expense Undistributed (Account 163) 2,573,824 2,519,780 Electric
16 ·,1. --------- -
19
20 TOTAL Materials and Supplies (Per Balance Sheet) 32,005,935 28,401,367
-- ---
3
FERC FORM NO. 1 (ED. 12·96) Page 227
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Idaho Power Company
Refnre The Idaho Public Utilities Commission
Additional Ratebase and Expense Adjustments
Account
Line No. Ratebase Revenue Exeense No. Description
Incremental Security Costs Order 28975 182 $ 728,766 (1)
2 Intervenor Funding· DSM/Land and Water Fund of the Rockies 928 $ 4,953
3 Prairie Acquisition Adjustment 114 $ (454,449)
4 115 259,413
5 $ (H1'i.O�R) (1)
6 Other Operating Revenue - Cable One 454 $ 346,171
Asset Heuremem 0011gauu11 :(3)
7 Electric Plant in Service 101 $ (1,577,314)
8 Accum Resv for Depree 108 $ 106,204,710
10 Prepaid Pension 165 $ 17,800,477 (2)
(1) Included in 2003 operating costs.
(2) Included in 2003 operating costs ana Known anu ureasurabte adju;:,tment:,.
(3) 13 month average
•
•
•
Line
No
1
2
3
4
5
6
7
8
9
10
11
12
13
14
IDAHO POWER COMPANY
PLANT HELD FOR FUTURE USE
For The Thirteen Months Ended December 31, 2002
ACTUAL
Month
December, 2001 .
January, 2002 .
February .
March .
April .
May .
June .
July .
August .
September .
October .
November .
December .
Average .
(1)
Amount
$2,231,595
2,281,595
2,281,595
2,281,595
2,281,595
2,231,595
2,231,595
2,231,595
2,335,078
2,335,078
2.335.078
2,335,078
2,335,078
$2,286,781
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IDAHO POWER COMPANY
IERCo - SUBSIDIARY RATE BASE COMPONENTS
For The Thirteen Months Ended December 31, 2003
( 1 I ( 2) (3) (4)
Advance Notes
Line Coal Payable to
llil Mon.th Investment Rox:alties Subsidiart Total
1 Actual December, 2002 .... $15,107,633 2,547,852 ($2,652,612) $15,002,873
2 Actual January, 2003 ..... 15,401,292 2,532,949 (3,568,647) 14,365,594
3 Actual February ..... 16,068,671 2,514, 721 ( 4, 592, 53 J) 13,990,861
4 Actual March .... 16,242,349 2,497,471 (6,851,155) 11,888,665
5 Actual April ... .......... 18,196,702 2,479,325 (6,916,981) 13,759,046
6- Actual May ............... 19,330,497 2,466,052 (6,356,753) 15,439,797
7 Actual June .............. 21,111,209 2,451,168 (ts, Ul I, bl I) 15,544,760
8 Forecast July .............. 20,323,887 2,435,331 (7,172,239) 1:,, 586, 978
9 Forecast August ............ 21,130,434 2,418,307 (8,283,082) 15,265,71)0
10 Forecast September ......... 21,926,750 2,400,535 (B,772,435) 15,554,850
ll .t4·0LeCC1!::iL 01....LuLcJ.. ......•...• J5,B31,1G7 2,39,1,<;?fl (10,140.)R�l 17.875.714
12 Forecast November .......... 16,340,372 2,365,650 (l,298,704) 17,407.318
i3 Forecast December .......... 17,167,251 2,349,046 (2,001,214) 17,515,033
14 Average ........ $18,782,963 $2,449,463 ($5,909,558) $15,322,868 ti)
71
•
LINE
NO
2
3
Idaho Energy Resources Company
Known and Measurable Adjustment
Income Tax Expense
Adjust to Remove Tax Contingencies
2003 Income Tax Expense - Forecasted
2003 Income Tax Expense - Revised
Adjustment Required to Increase Income Tax Expense
$ (813,715)
$ 4,186,285 1
$ 5,000,000 2
Adjustment Required to Reduce Subsidiary Rate Base:
4 December $
5 January $
6 February $ • 7 Marc;h $
8 April $ (2,000,000)
9 May $ (2,000,000)
10 June $ (2,000,000)
11 July $ (2,000,000)
12 August $ (2,000,000)
13 September $ (2,000,000)
14 October $ (5,000,000)
15 November $ (5,000,000)
16 December $ (5,000,000)
17 13 month Average - Decrease Rate Base $ (2,076,923)
18
19
20
21
1 Forecasted pre-tax income
I P.ss tax-exempt interest income
Taxable
Tax at 35%
12,127,478
(166,665)
11,960,813
4,186,285
•
2 Contingent tax reserves associated with prior years were revalued during 2003
and resulted In a decrease to income tax expense of $2,000,000 in April and
$3,000,000 forecasted to take place in October. For ratemaking purposes,
contingent tax reserve adjustments are not allowed as part of regulated tax
expense.
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•
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Obenchain, Phil
From:
Sent: •To:
Subject:
Pickens, Leonard
Tuesday, August 19, 20031:24 PM
Obenchain, Phil
FW: Water Mgmt Initiative
-----Original Message-----
From: Henderson, Randall Sent: Tuesday, August 19, 2003 1:07 PM
To: Pickens, Leonard
Subject: Water Mgmt Initiative
Water Management Services (Initiatives): Acct 415-416
The Idaho Power Water Management Department provides streamflow guaging services to various federal, state, local,
and environmental concerns. Met with the engineer in charge of streamflow gauging, Pete Vidmar. Reviewed existing
contracts and based revenue projections on these agreements. Pete prepared an expense budget (by DCE) based upon
initiative work expected to be done in remainder of 2003, and provided this mtormanon tor the rerorecast
FERC_Acct Jan-03 Feb-03 Mar-03 Apr-03 .. lliiay-03 Jun-03 Jul-03 Aug-03 : Sep-03 Oct-03
415003 (83,950) (7,200) (11,347) (24,049) (14,603) (14,603) (14,603) (18,353)
416003 16,429 7,597 3,808 8,247 11,700 10,858 11,000 11,000 10,000 11,000
'" 16,429 (7f353): 3)08 1,047 353 (13, 192) (3,603) " (3,603) -({603) (7,353) ••
•
tJ5 (
DERIVATION OF REVENUE ADJUSTMENT
NON-RECURRING CHARGES
e Current Proposed
Charae Tvoe Quantitv Charae Revenues Charae Revenues
Account Initiation Charge
R1, R7, RO 114,582 $15 $1,718,730 $20 $2.291.640
Other 619 $15 $9,285 $40 $24,760
6p.m. - 9p.m.
R1, R7, R9 540 $45 $24,300 $45 $24,300
Other 3 $45 $135 $65 $195
After9PM
R1, R7,R9 30 $80 $3.120 $80 $'.'l,1?0
Other 0 $80 $0 $100 $0
Reconnect Charge
R1, R7, R9 16,491 $15 $247,365 $20 $329,820
Other 150 $15 $2,250 $40 $6,000
6p.m.-9p.m.
Rl, R7,R9 1,964 $45 $88,380 $46 $88,380
Other 4 $45 $180 $65 $260
After 9PM
Hl, H/, H� 239 $60 $19, 120 $80 $10,120
Other 1 $80 $80 $100 $100
Irrigation Connect- Reg (<10 days) 560 $30 $16,800 $40 $22,400
e Irrigation After Hours Connect Charge 15 $60 $900 $65 $975
Irrigation Disconnect Charge (<10 days) 20 $30 $600 $0 $0
lrriqation Disconnect Charge arr 3 $60 $180 $0 $0
Field Collection Charge
R1, R7, R9 15,242 $15 S228.630 $20 $304,840
Other 19 $15 $285 $40 $760
SUBTOTAL 150,491 $2,360,340 $3,116,670
Irrigation (R24 & R25)
Connects 3,429 $40 $137,160
Service Transfer 1,242 $20 $24,840
Less Above (G7G) $-10 -$23,000
Dusk/Dawn (R15)
Connects 295 $40 $11,800
Service Transfer 905 $0 $0
Less Above (134) $40 -$5,360
Other Non-metered (R40, 41, 42)
connects 140 $40 $5,600
Service Transfer 59 $0 $0
Less Above (2) $40 -$80
GRAND TOTAL 155,850 $2,360,340 SJ,267,630
NET 5907,290 e
?(6
SERVICE INITIATION I RECONNECTION I FIELD COLLECTION
543 $ 22,470.00
1,968 S 84,360.00
115,201 $ 1,675,833.83
$ #
15,261 $ 220,080.00
15 $ 510.00
3 $ 180.00
560 $ 16,260.00
20 $ 450.00
39 $ 2,800.00
240 $ 15,180.00
16,641 $ 243,922.50
SA TYPE ADJ CODE QTY TOTALS.
EA-IR AHCONN 2 $ 90.00
Ec-LG AHCONN 6 $ 270.00
EC-SG AHCONN 8 $ 270.00
ER-OL AHCONN 1 $ 45.00
ER-RS AHCONN 526 $ 21,795.00
EC-LG AHRCON 3 $ 60.00
EC-SG AHRCON 25 $ 1,125.00
ER-OL AHRCON 4 $ 180.00
ER-RS AHRCON 1936 $ 82,995.00
EA·IR CONN 000 $ 7,414.00
EC-LG CONN 1735 $ 24,690.00
EC-OL CONN 1 $ 15.00
EC-SG CONN 4998 $ 70,677.81
EC·UM CONN 1 $ 15.00
EL-UM CONN 1 $ 15.00
ER·OL CONN 10 s 120.00
ER-RS CONN 107849 s 1,572,887.02
EAIR l=DCOLL 10 c;: 1?0 nn
EC-LG FDCOLL 746 $ 10,740.00
EC-OL FD COLL 3 $ 45.00
EC-SG FDCOLL 943 $ 13,740.00
tR-nl i=nr.rn I 6 s as.ez ER-RS FDCOLL 13553 $ 195,391.18
EA-IR IAHCON 15 $ 510.00
EA·IR IAHDCN 3 $ 180.00
EA·IR ICON 553 $ 16,110.00
EC·SG ICON 7 $ 150.00
EA·IR IDCON 20 $ 450.00
ER-RS LHCONN 39 $ 2,800.00
EC-S<;l_ LHRCON 3 $ 80.00 ER-OL LHRCON 1 s OU.UV
ER-RS LHRCON 236 $ 15,020.00
EA-IR RE CON 42 $ 510.00
EC-LG RE CON 98 $ 1,440.00
EC-OL RE CON 5 $ 75.00
EC-SG RE CON 396 $ 5,820.00
ER-OL RE CON 103 $ 1,215.00
ER-RS RE CON 15997 $ 234,862.50
•
150,491 $ 2,282,046.33
•
Service lnrtiation Charge (Pyell).jcb t(/
• Account 451101 for Year-End 2002
•
Idaho
Oregon
Idaho
Oregon
Company Use
OS Metr Rd
Co-Gen
Total Idaho
Company Use
Total Oregon
Total Retail
Total Company
Misc
Misc
100
101+103
PA
107
PB
109P
109S
115
119P
1248
1258
140
166
187
000
001
0078
009SB
015
02488
50,209.08
960.37
51,169.45
60.00
3,061,366.83
1,653.50
126,258.31
45.00
441.50
43,536.00
1,806.82
35.00
41, 111.50
685.00
79.50
970.00
-15.00
3,278,033.96 +
30.00
22,736.00
1,037.00
900.00
1,071.50
1.745.00
27,519.50 -r
3,305,553.46
3,356, 722.91
_,,,,o - 3 3zt3. :J.'13 �o, 2v < - 1 /
•
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•
•
Obenchain, Phil
From:
Sent: •o:
ubject:
Phil:
Brilz, Maggie
Monday, August 18, 2003 3:47 PM
Obenchain, Phil
Standby Revenue
The jurisdictional split for 456 Standby Revenue for 2002 is:
Idaho $86,957
Oregon $60,377
Maggie Brilz
Pricing and Regulatory Services
Idaho Power Company
[phone]
[phone] {tax)
[e-mail]
1?JJ
I / . / ',L//,.,.,., ... �1'-'-"' ... � i·
,-- /­ _L--
NET POWER SUPPL y COSTS (W�hout PPL ano Tiber)
89,914 Total
2003 Normalized Thermal Out�ut (MWh) MW avg
Jim Bridger 5,169,303 59C
Valmy 1,431,709 163
Doordmon �00.961 d7
Danskm 905 0
7 011 779
2003 Normalized Cost ($000) $/mwh
Jim Bridger 65,402 $12.65
Valmy 23,183 $16.19
Boardman 5,600 $13.66
Danskin 52 $58.00
94,238
200'3 Norm=ili7Pri ThPrm�I Outnut 111.,1u11h1 MWavQ Jun Bridger 5,156,486 589
Val my 1,355,573 155 Boardman 414,326 47 Dans kin 871 0
6 927 257
2003 Normalized Cost ($000) $/mwh
Jim Bridger 65,240 $12.65 e. Val my 21,950 $16.19
Boardman 5,662 $13.66
Danskin 45 551.56
92,897
2003 Norrnalued Thermal Outout fMWh) MWayq Jim Bridger 5,103,908 563
Valmy 1,305,329 149 Boardman �W.'+SO 47
Dan skin 973 0
6 819 706
2003 Normalized Cost f$000) Slmwh
Jim Bridger 64,575 $12.65
Va1my 21,137 $16.10
Boardman 5,595 $13.66
Dans kin 44 $44.83
91,351
2000 Nv1 rneolii.:cd Th�rmol O\.ltp...,t (MWh) MW,uo
Jim Bridger 5,012,507 572
Val my 1,242,022 142
Boardman 387,682 44
Danskin 657 0
6643068
2003 Normalized Cost !$0001 S/mwh Jim Bridge, 63,419 $12.65 Val my 20,111 $16.19 Boardman 5,300 $13.66 Danskm 26 $38.87
88,856
2003 Normalized Thermal Outout (MWhl MW avg Jim Bridger 4,743,954 542 Valmy 1,079,915 123 Boardman 344,685 39 Danskin 382 0
6168 936
2003 Normalized Cost ($000) $/mwh
Jim Bridger 60,021 $12.65 Val my 11,407 $10.19
Boardman 4,710 $13.66 Dans kin 12 $3178
82,229
2003 Normalized Thermal Outout IMWh\ MW avg Jim Bridger 5,037,232 575
Val my 1,262,910 146
Ooorclmor, 303,'.250 •• Oanskin 758 0
Total 6 714149
2003 Normalized Cost fSOOO\ $/mwh
Jim Bridger 63,731 $12.65
V:ilmy 20,773 Si6.19
Boardman 5,374 $13.66
Danskm 36 $47.18
$29.44
$24.42
PPL O
Wheeling�
Avg NPSC 46,513
AVERAGE
Thermal Generation (MWh) (Br, Bo, VJ 6,168,554
Hydro Generation (MWh) 11,569,526
Combustion Turbine (MWh) 382
Total Market Purchases (MWh) 16,144
Total Market Sales (MWh) (4,492,889)
Total Thermal Unit Fuel Costs ($000)' 82,229
Tnt�I M:uket Purchases ($000) 266 $16.48 Total Market Sales ($000) (79.278) $17.65
Net Power Sucolv Costs ($000) 3218
• Bridger, Boardman, Valmy, Climsidn
Thermal Generation (MWh) (Br, Bo, VJ 6, 713,392
Hydro Generation (MWh) 6,836,038
Combustion Turbine (MWh) 7:'.;0
Total Market Purchases (MWh) 299,089
Total Market Sales (MWh) 0 (2,567,559)
Total Thermal Unit Fuel Costs ($000)° 89,91£
Total Market Purchases ($000) 10,677 S35.70 Total MarKet sares ()UWJ ( .s.r;_: t1 J,r;g) (!;C,64G) E:22.06
Net Power Suoclv Costs (SOOOl 43 945
• Bridger, Bo•ranan, Valmy, Oanslcn
�enarlo4
Thermal Generation (MWh) (Br, Bo, VJ 6,642,411
Hydro Generation (MWh) 10,128,423
Combustion Turbine (MWh) 657
Tobi Market Purchases (MWh) 64,901
Total Market Sales (MWh) (3,554,674)
Total Thermal Unit Fuel Costs ($000)" 88,856
Total Market Purchases ($000) 1,585 $24.42
Total Market Sales ($000) (74,998) $21.10
Net Power Supply Costs ($000) 15 443
- c,1ui,a, n.:..,,;1o,.n, Y•lrny, o. ... io ..
Scenario 2
• Bridger, Boardman. Valmy, Oanslon
Scenario 1
Scenario 5
Scenario 3
�T�h-e_nm_a�l�G�e-n_e_ra-t,-on�(M_W..,..,..h�)-(�B-r.�B-o-.�VJ,-+�����6�.8�1�8�.7�3�3�·-�
'-'yd•o Cono,ot;,.,n (MWh) 8,866,392 I Combustion Turbine (MWh) 973
Total Market Purchases (MWh) 183,235 ,
Total Market Sales (MWh) (2.587,616)
Total Thermal Unit Fuel Costs ($000)' 91 ,351
Total Market Purchases ($000) 5,395
Total Market Sales (SOOO) (63.191)
Net Power Suoolv Costs ($000) 33 555
Thermal Generation (MWh) (Br, Bo, VJ 6,926,386
Hydro Generation (MWh) 7,628,272
Combustion Turbine (MWh) 871
Total Market Purchases (MWh) 371,690
Total Market Sales (MWh) (1 ,645,501)
Total Thermal Unit Fuel Costs ($000)' 92,897
T otat Market Purchases ($000) 12,621 S33.96
Total Market Sales ($000) (47,694) 528.96
Net Power Suoolv Costs ($000) 57 824
· �·· o •• � ... v.1,ny,o,,.......,..
Thermal Generation (MWh) (Br, Bo, VJ 7,010,874
Hydro Generation (MWh) 5,967,579
Combustion Turbine (MWh) 900
Total Market Purchases (MWh) 859,474
Total Market Sales (MWh) (557,113)
Total Thermal Unit Fuel Costs ($000)' 94,238
Total Market Purchases ($000) 33.519 $39.00
Total Market Sales ($000) (16,072) $32.44
Net Power Suoolv Costs ($000) 109 686
• Bridger, Boardman, VaWTly. Oanskin
I
•
•
ID_Macro_Revised August 7 WfTHOUTTiber PPL 0813Portfolio Average Aggregate ;oJ
,F
Obenchain, Phil
From:
Sent: •ifo:
Subject:
Phil:
Brilz. Maggie
Friday, August 08, 2003 8:52 AM
Obenchain, Phil
Facilities Revenue Adjustment
(!)
The revenue adjustment to Facilities Charges (Acct. 454) for Idaho is ($72,504). This adjustment reflects the
transfer of four Schedule 19 Transmission Service Level customers to Primary Service Level and the elimination of
facilities charges on substation investment. Please let me know if you have any questions.
Maggie Bnlz
Pricing and Regulatory Services
Idaho Power Company
[phone]
[phone] (fax)
mbrilz@irl-:ihnnower.com
•
•
--- G
2003 Normeliad Cest csrvvn
7003 Norme li,ed Thermal Outnut IMWh'
Jim Brioper �.731
Valmy 26,m
Boardman 5,4SII
Danskin 56
I sc,n2r1c 1
Thermal Generation (MWh) (Br, Bo, VJ i ,355,421
Hydro Generation (MWh) 5,967.646
Combustion Turbine (MWh) 932
Total Market Purcha.u (MWh) 658,400
Total Mort.et Sale> (MWh) (780,752)
Total Thermal Unl Fuel Costs (SOOO)• 97,Mi
Total Merkel Purchases ($000) 26,73€ S<I0.61
Total Markel Sales (5000) (2t,30B) 531.13
Net Power Suot>fv Ccsts {Hlnrn 9P.945
• 'lrido-. F.�ffllln. VafflV. OanNWI
Jln 1 61 i\Jgcr
Valmy
Boardman
Danskin
6,166,�
1,788,5313
410,486
932
7 356 3511
� 588 204 47
0
!mlm! $12.75
$14.70
$13.25
$511.7(!
117,517
Sctnarlo 2
Thermal Generatior, (MWh) (Br, Bo, VJ 7,:0!>0,660
Hydro Generation (MWh) 7,629,737
Combustion iurbine (MWh) 1,017
Total Market Purchases (MWh) :156,526
l ct.al Market S..lu (MWh) (2. 036 ,286)
Total Thermal Unit Fuel Cost. (SOOO)' 97.AM
1 ct.al Market Fu,�h.,�u IS 000) P,09:; �35.45 1 olal Market Sales ($000) (!;.7,601) ,::Ut'9.�
Net Power Suoolv Costs. (S.O(M.'.)l <8.85�
• &ridQef, &oar<lmlin, V•"'f, Dint»,
?003 Normeli.ed Thermal Outnut tMWh\
Jim Bridger 5, 149,62.ol
Valmy 1,786,505
Boardman 414,531
Danskin 1,017
1351 sn
;)003 Norm;; Ii; Pd Cost csrvvn
Jim Bridger 65,645
Valmy 26,262 Bo�rdman 5.G1
Dans kin 52
97,-451
1i!!!l!!I! 512.75
$14.70 i,;,.z:,
$51.57
!!U!:ab $12.75
514.70
$13.25
$33.03
SlmWh
$12.75 $14.70 n;,z,
S:39.!iS
flmwh
$12.75 $14.70
$13.25 $44.16
114,727
6 752735
Jim Bridger 59,678
Valmy 25,2�
Boardman 4,679
Danskio 20
7003 Normali,ed Co•t riuuu,
Jim Bridger 4,681,528
Valmy 1,717,351
Boardman 353,283
Oanakin 591
7003 Notrnatlr ed Thermal Outnut IMWI,\
Jim Bridger 63,533
Valmy 26,010
Boardman 5,162
Danskin 21
7003 NormElized Cogt Ts()I)())
7003 Normsh,ed Cost 1)nnm
Jim Bridge, 64,873
Valmy 215, 177
Boardmen s.,•1
Dan•kin 41
ec,t.e1
"-'-'""-":;,..;;;;:.,;;;;->==--I MW'.;',
200 47 0
t=7c'0�03'=--N�o"-rm"'•::.:l;:.i;"'-ed;:;,,,;,1:::.h•::.;r'-'mo=l .::O.::u1"'tn:.:uc..t.,_ 1,M:::.Wh='"-'--l � Jim Bridget 4,983,984 !i88
Valmy 1,769,346 202
Boardman 389 ,687 44
Dansktn 5S7 O
71.olS�
SCPnario e
5cenc1r1o •
Thermal Generation lMWh) (Br, Bo, V) 6,752,142
Hydro Generation (MWh) 11,569,325
Combustion 1 urbine (MWh) 591
Total Markel Purchases (MWh) A,314
Total Mari<el Sales lMVVn) (£,1 IIA,717)
Total Thermal Untt Fuel Cost. ($000)" 89,62::
1 otel Markel Purchase. (SOOO) rt $17.87
T olal Mork•t Sales (I 000) (89,698) $17.44
Net Power Suoolv Cost, 1$000) 1
• tinagt1, t,oa11:1n .. 11, v • .,,.,, O•..Nri
Therms! Generet,on JMWh) (Br, Bo, V) 7, 1<3,017
Hydrc, Generation (MWh) 10,128,410
Combustion Turbine (MWh) 537
T olal Merkel Purchase• (MWh) 32,761
Total Morkol Sale• (MWh) (4,103,071)
1 otal Thermal Untt Fuel Cost. 1$000)• 94,72;
l otal Markel Petchesee 11000) 886 $27.03
1 otal Markel Sates (5 000) (6:i,100) ,:io.7-4
Net Power Suoolv Coe te fl 000) ,0500
• f>riogar, E,oardl'Mn, V•fflf, D•nu:lrl
Sc•narlo 3
Thermal Generation (MWh) (Br, Bo, VJ 7,160,'1io4:;
Hydro Generot,on (MWh) 6.867,933
Combustion 1 urbine (MWh) 937
Total Merkel Purchases (MWh) 108,872
Total Merkel :>oles lMWh) (3,05i.530)
1otal1'hermal Unh Fuel Costs (1000)• 96,53,
Total Market Purchase• ltOOO) 3.39E $31.21
Total Merkel SalH (5 000) C7M12) t23.99
Ne1 Power Sunnlv Coste (� 000) 76.61f
· D•t..1r,,t. .... -.,,•J,.�.n.,� '
·- Thermal Generatior, iMWh) (Br, Bo, V) 7,1i6,33E
Hydro Gener.loon {MWh) 6,836,610
Combustion 1 urbine (MWh) are
1 otel Msrket Purcbas.es (MWh) 212,174
iulel Merr1"':t E..elcic: {MWh) @ (3,024,271) Total Thermal Untt Fuel costs ($000)" 95,17(·
lot.al Mart.et Purchases ($000) , . B,03E $37.86
1otal Markel Seres {}000) ( C·') 000;t66,02A) � $21.83
Net Power Suoolv Cost, ISOOOl 37 184
• Bnogt,, fioar<fmln. Vatny, Dansllil
''· Wheeting �
Avp NPSC 44,608
Total 95,170
1lllmb $12.75
$1.ol.70
$13.25 $,47.41
MW avg
157' 202
45
0
:.,012,11,4
1,768,'85
395,736
803
Jtm enoger
Valmy
Boardman
Oanskin
Jim Bridper 63,892
Valmy 25,9117
Boardman 5,242
Dano kin 38
7003 Normeliied Thermal Outcut IMWh\
4.400 PPL
AVERAGE
\
ID_ Macro_ Revised Aupust 7 Tiber PPL 0812Portfolio Averape Agg,epat,
Line
No.
2
3
4
5
6
7
8
10
•
Idaho Power Company
Befor" Th" Idaho Public Utilities Commission
Additional Ratebase and Expense Adjustments
Account
No. Ratebase Revenue Expense
Descriptlcn
Incremental Security Costs Order 28975 182 $ 728,766 (1)
Intervenor Funding - DSM/Land and Water Fund of the Rockies 928 $ 4,953
Prairie Acquisition Adjustment 114 $ (454,449)
115 259,413
$ (1Q5,036) (1)
Other Operating Revenue · Cable One 454 $ 346,171@
Asset Heuremem 0011ga11on :(3)
Electric Plant in Service 101 $ (1,577,314)
Accum Resv for Depree 108 $ 106,204,710
Prepaid Pension 165 $ 17,800,477 (2)
(1) Included in 2003 operating costs.
(2) Included in 2003 operating costs ano Known anu mt:ici:Surc:11.Jlt< c:1Uju:,t111ent:;.
(3) 13 month average
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/II
IDAHO POWER COMPANY
OPERATION AND MAINTENANCE EXPENSES
For The Twelve Months Ended December 31, 2003
.LINE
NO
FERC
ACCOUNT
l�UlVJB:t!;R DESCRIPTION
Y-T-D
Actual
JunQ
Forecast
July Through
[)i::;.f'."Amh�r 'l'n'l'I\T,
2,187,417
0
4,99),765
1,267,277
2,958,065
607,157
548.895
0
1,130,737
666,090
1,808,726
255,420
1,638,522
0
3,860,027
bU.L, .Ll:n
1.149,339
351,737
Operand supv engineering
Fuel
Steam expenses
Electric expenses
Misc steam power expenses
Rents
501
S02
505
506
507
°p;wer productio� expenses:
St:am power generation -
Operation -
soo 1
2
3
4
5
6
·rot al operation 7,600,813 4,409,868 12,010,681
8
9
10
11
12
510
511
512
513
514
Main supv and engineering
Main of structures
Main of boiler plant
Main of electric �lant
Main of misc steam plant
666,655
193,246
8,012,538
l,n8,'.:>8U
3,114,E32
1,133,948
102,514
4,688,306
1, I I I, 15.L
4,875,711
1,800,603
295,759
12,700,845
3,69j,731
7,990,543
Total maintenance 13,905,851 12,577,fill 26,4133,481
Total steam power generation
4,267,390
3,950,383
5,479,474
1,058,196
1. 759. 801
391,972
38,494,162
2,344,497
1,716,226
2,936,918
470,852
R99,4'i,
204,903
16,987,499
J.,922,893
2,234,157
2,542,557
587,345
860,3ll.8
187,069
21,506,663
Rents
Oper supv and engineering
Water for power
Hydraulic expenses
Electric expenses
Ml:sc l1ydro pwr gen exp
537
538
539
540
Hydraulic power generation -
Operation -
535
536
15
16
17
18
i s
20
14 •
21 Total operation 8,334,368 8,572,848 16,907,217
Maintenance -
541 Main supv and engineering
542 Main of structures
22
23
24
25
�6
543
544
545
Main of res,dams,waterwys
Main of electric plant
Mctlu u[ llli5c hydro plant
555,105
4'l.'/ ,'l.SI
427,733
1,482,202
1,087,507
621,696
64'1,224
458,572
1,100,830
1,?11,ll.fiO
1,176,801
1,071,461
886,306
2,583,033
2.298.967
27 Total maintenance 3,979,785 4,036,781 8,016,567
28 Total hydraulic power generation 12,314,154 12,609,630 24,923,783
Other power generation -
Operation -
546 Oper supv and engineering 29
•
30
31
32
33
547
548
549
549
Fuel
Generation expenses
Misc other pwr gen exp
Misc other pwr gen exp
215,688
0
67,415
98,764
0
167,054
0
128,392
254,853
15,103
382,741
0
195,806
353,617
15,103
34 Total operation 381,867 565,402 947,268
JI�
• IDAHO POWER COMPANY
OPERATION AND MAINTENANCE EXPENSES
For The Twelve Months Ended December 31, 2003
LINE
NO
FERC
ACCOUNT
NUMBER DESCRIPTION
Y-T-D
Actual
June
Forecast
July Through
December TOTAL
Other power generation - (continued)
Maintenance -
1 551 Main supv and engineering 0 752 752
2 552 Main of structures 108,581 82,474 191,054
3 553 Main of gen and elec plt 39,483 169,926 209,409 � 554 Main misc oth pwr gen plt 149,477 249,228 398,705
5 Total maintenance 297,541 502,379 799,920
6 Total other power generation 679,408 1,067,781 1,747,189
Other power supply expenses -
7 555 Purchased power 0 0 0
8 556 System cont and load disp 13,373 7,961 21,334
9 55'7 Other expenses 717,229 1,413,959 2,131,188
10 'l'otal other power supply expenses 730,603 1,421,920 2,152,523 • 11 Total power production expenses 35,230,827 32,086,829 67,317,657
•
;;J
IDAHO POWER COMPANY
OPERATION AND MAINTENANCE EXPENSES
For The Twelve Months Ended December 31, 2003
Y-T-D Forecast • LlNE
NO
FERC
ACCOUlilT
}HJMBER DESCRIPTION
1>.rr11a 1
June
July Throuqh
December TO'l'AL
1,878,325
2,714,370
1,762,104
654,644
0
2,987,576
476,947
1,592,298
886,771
1,341,182
989,783
]28,117
0
1,470,276
336,209
982,739
991,555
1,373,187
772,321
326,528
0
1,517,300
140,739
609,559
Station expenses
Overhead line expenses
Underground line expenses
Trans of elec by others
Misc trans expenses
Rents
Oper supv and engineering
Load dispatching 561
562
563
564
565
56G
567
Transmission expenses:
Operation -
560 1
2
3
4
5
6
7
8
q Total operation 5,731,190 6,335,076 12,066,266
Maintenance -
10
11
12
13
14
568
569
570
571
573
Main supv and engineering
Main of structures
Main of station equip
Main of overhead lines
Main of misc trans plant
357,428
337
1,375,137
958,764
57.733
407, 113
(1, 809 >
526,837
1,555,386
3,031
774,542
( 1, 552)
1,901,974
2,514,150
60,764
15 Total maintenance 2,759,400 2,490,478 5,249,878
Total transmission expenses 8,490,590 8,825,554 17,316,144
3,523,703
2,356,235
1,273,803
3,607,428
2,652,995
156,324
6,632,290
506,128
4,735,766
139,665
1,953,311
1,271,663
821.981
2,019,674
1,479,798
71,451
3,591,100
267,685
2,255,500
130, 440
1,570,393
1,084,573
451, 822
1,587,755
1,173,197
84,873
3,041,190
238,443
2,480,266
9,217
Ot.:ition c>epences
Overhead line expenses
Underground line expenses
St light and sgnl sys exp
Meter expenses
Customer install expenses
Misc distribution exp
Rents
Oper supv and engineering
Load dispatching
582
581
583
584
585
586
587
588
589
Distribution expenses:
Operation -
580 17
18
19
20
21
?.2
23
24
25
26
27 Total operation 11,721,727 13,862,611 25,584,339
Maintenance -
28
?q
30
31
32
33
34
•
35
36
590
591
592
593
594
595
596
597
598
Main supv and engineering
Main of structures
Main of station equip
Main of overhead lines
Main of underground lines
Main ot line transformers
Main of st lght-sgnl sys
Main of meters
Main of misc dist plant
17,255
0
1,283,771
5,710,292
578,362
G4G,02G
164,502
760,988
129,712
37,641
0
1,369,276
6,307,562
736,651
765,155
197,943
773,808
86,450
54,896
0
2,653,046
12,017,854
1,315,013
1,111,180
362,444
1,534,797
216,161
37 Total maintenance 9,290,907 10,274,486 19,565,393
38 Total distribution expenses 21,012,634 24,137,097 4S,14�,/31
/It/
• IDAHO POWER COMPANY
OPERATION AND Mll.INTENANCE EXPENSES
For The Twelve Mont.hs Ended December 31, 2003
6 Total customer accounts expenses
Customer accounts expenses:
Operation -
1 901 Supervision
2 902 Meter reading expenses
3 903 Cust recrds - collect exp
4 904 Uncollectible accounts
5 905 Misc customer accts exp
LINE
NO
FERC
ACCOUNT
NUMBER DESCRIPTION
Y-T-D Forecast
Actual July Through
June December TOTAL
185,939 205,778 391,71•)
2,289,427 2,419,067 4,709,291
3,827,689 3,447,062 7,274,751
1,592,466 2,973,845 4,566,311
545 1,274 1,819
7,896,066 9,047,825 16,943,891
Total maintenance
Total operation
Maintenance -
935 Main of general plant
219,498 158,334 377,332
3, 466, '.392 4,J09,04J 7,?75,636
156 19 175
275,989 311,029 587,017
0 0 0
3,962,235 4,778,426 8, HO, 660
14,844,624 14,989,109 29,833,732
7,444,132 8,827,610 16, 271. ,42
(12,991,888) (13, 261. 046 l (26,2'.-,2,934)
3.213.653 2,367,090 5,580,743
1,871,050 2,041,629 3,912,680
1,864,497 1,406,845 3,271,342
12,688,937 13,068,466 25,757,402
1,475 1,332 2,807
1,978,588 1,912,284 3,890,872
0 0 0
137,G40 314,468 152,109
669,764 585,254 J.,255,018
5,459 17,671 23,130
31,727,931 32,270,711 63,998,642
1,140,672 877,440 2,Ulti,112
1,140,672 877,440 2,018,112
32,868,603 33,148,151 66,016,754
Ad.min and gen salaries
Office supplies and exp
Admin exp transf - er
Outoidc cervices eroployE>d
Property insurance
Injuries and damages
Emp pensions and benefits
Franchise requirements
Reg cormnission expenses
Duplicate charges - er
General advertising exp
Misc general expenses
Rents
Total administrative and
general expenses
Total customer service and
informational expenses
921
922
92)
924
925
926
927
928
929
930.1
930.2
931
Administrative and general expenses:
Operation -
920
Customer service and informational expenses:
Operation -
907 Supervision
908 Customer assistance exp
909 Info and instruct adv exp
910 Misc cust svc and inf exp
912 Demo and selling exp
27
26
28
13
14
15
16
17
18
19
20
21
22
23
24
25
7
8
9
10
11
30
Total electric operation
and maintenance expenses 109,460,955 112,023,883 221,484,838
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• DRAFT
POWER SUPPLY EXHIBIT
Case With Normalizing
Case With Normalizing Adjustments and Known & Measurable Adjustments Difference
Direct Impacts
Puq;h,l§ed Power - Contract
CSPP
Energy (mwh) 783,635 812,779 29,144
Expense ($ x 1 DOD) 1/ $45,167.0 $46,413.D $1,246.0
PPL-Montana
Energy (mwh) 0 99,360 99,360
Expense ($ x 1000) $0.0 $4,400.0 $4,400.0
Fuel Costs
Bridger
Cost (millslkWh)$/mmBtu) 12.65 12.75 0.10
Energy (mwh) 5,038, 109 5,013,126 (24,983)
Cxpen;,c ($ x 1000) i63,7��.6 '>6�.004.0 ',1fi? 4
Boardman
Cost (millslkWh)$/mmBtu) 13.66 13.25 (0.41)
Energy (mwh) 393,464 395,936 2,472
Expense (S x 1000) $5,376.4 $5,244.7 ($131.7)
Val my
Cost (millslkWh)$/mmBtu) 16.19 14.70 (1.49)
Energy (mwh) 1,283,205 1,768,646 485,441
Expense (S x 1000) $20,778.3 525,999.8 $5,221.5 - Indirect Impacts
Purchased Power - Market
Energy (mwh) 297,564 210,815 (86,749)
Expense ($ x 1000) $10,607.6 $7,976.9 ($2,630.7)
Surplus Sales
Enerov (mwh) 2,567,823 3,024,696 456,873 Revenue ($ x 1000) $54, 164.5 $63,094.8 $8,930.3
� Energy (mwh) 761 805 44 Expense ($ x 1 ODO) $3,254.2 $3,256.5 $2.3
Net Power Supply Expense($ x 1000) $49,594.6 $47,688.1 ($1,906.5)
1/ Not included in Ne,t Power Supply E"pense
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PS Exhibit Adjustments 092303
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• Idaho Power Company
Summary of Adjustments to 2003
Operating Expenses During 2004
DRAFT COPY - ALL AMOUNTS ARE PRELIMINARY
Line Source
No. Page Amount
Annualizing Adjustments
"1 A Operating Payroll $ 2,913,244
2 c Property 8t Liability Insurance (927') 384,503
Total Annualizing Adjustments 3,297,826 @
Known & Measurable Adjustments
3 A Incentive 5,114,821
4 B Operating Pension Expense Adjustment 2,170,163
5 B 2002 Prescription Expenses Booked in 2003 (280, 107)
6 c 2004 Salary Structure Adjustment 2,241,595
7 c American Falls Interest 297,436
8 c Property & Liability Insurance 364,014
9 Total Known & Measurable Adjustments 9,907,923 @
10 Total Adjustments to Operating Expense $ 13,205,750
7/29/20031;30 PM
• Idaho Power Company
Detail of Adjustments to 2003
Operating Expenses During 2004
A
.e
Line Source
No. Page Amount
1) Operating Payroll (Various accts)
December estimated two pay periods $ 8,356,933
2 Times 13 (26 pay periods per year; 108,640,131
3 Less 2003 Estimated Total Year 104,404,373
4 Gross Adjustment 4.235.758
5 Operating percent 68.78%
6 Adjustment to Operatinp Expense $ 2,913,244
2) Incentive Expense (Various accts)
7 2003 Estimated Adjusted Straight-time Payroll $ 108,640, 131
8 2 Less Estimated Officer Payroll 2,400,454
9 Total Payroll Exel Officers 106,239,677
10 3 Normalized Incentive Rate 7.00%
11 Normalized Incentive 7,436,777
12 Less 2003 Estimated Incentive
13 Increase 7,436,777
14 Times operating percent 68.78%
15 Adjustment to Operating Expense $ 5,114,821
/35
• B
Idaho Power Company
Detail of Adjustments to 2003
Operating Expenses During 2004
Lina Source
No. Page_ Amount ·----
3) Operating Pension Expense Adjustment (920)
4 Service Cost $ 10,173,344
2 4 Less 2003 Accrual 7,018,000
3 Difterence 3.155,344
4 Operating Percent 68.78%
5 Adjustment to Operating Expense $ 2, 170, 163
6
7
5 4) 2002 Prescription Expenses Booked in 2003 (Various accts) $
Times Operating Percent
407,266
68.78%
6 Adjustrnent to Operating Expcnoc $ 280,'107
• c
Idaho Power Company
Detail of Adjustments to 2003
Operating Expenses During 2004
Line Source
No. _Page_ Amount
5) 2004 Operating Payroll SSA (Various accts)
A 200::i Annualized Gross Payroll $ 108,040, 131
2 Estimated SSA 3.00%
3 Gross Adjustment 3,259,204
4 A Operating percent 68.78%
5 Adjustment to Operating Expcncc $ 2,241,595
5) Americ an r elle lntere ot (536)
6 6 2004 Estimated $ 801,941
7 6 2003 Actual/Estimated 504,504
8 Adjustment to Operating Expense $ 297,436
7) Liability & Property Insurance (924 & 925)
9 7 New monthly premium $ 561,647
10 Annualized (Times 12) 6,739,760
11 7 2003 Actual/Estimated 6,33_:i_.__487
12 Annualizing Adjustment $ 405,273
7 Portion to Subsidiaries (5.1053%) 20,690
Idaho Power Portion $ 384,583
2004 Premium Increase
13 7 New monthly premium (with increase) s !:)�3.til 3
14 Times 12 7,123,358
15 7 Less 2003 Annualized Estimated Cost 6,739,760
16 2004 Adjustment 383,598
17 7 Portion lu Subsidiaries 19,584
18 Idaho Power Portion $ 364,014
Idaho Power Company
Estimate of 2003 Gross Payroll
Jan-03
Feb-03
Mar-03
Apr-03
May-03
Jun-03
Jul-03
Aug-03
Sep-03
Oct-03
No·i-03
Dec-03
SUDtotal
Total Loaded labor all accounts
Labor i-icl ben trsf credit
111 - STRAiGHT TIME PAYROLL
123 ·· INCENTIVE ACCRUAL
Total labor excl Incentive
s/t % of total
All accounts dee 111 excl 242 dee 2003
gross up for 242 time
December all accounts gross payroll
Gross Adjustment
Operating portion
Operating portion
2003 Total Labor
Budget all accts
15,677,558
11,432,553
10,837,474
11, 126,297
10,801,801
11,365,301
11,418,156
16,275,185
11,410,747
11, 138,259
11,463,374
11,569,306
144,537,011
Actual 2002
150,510,721
139,307,941
86,267,55'/
2,567,526
136,740,415
63.09%
Dec 2003
7,298,908
114.50%
�
Total 2002
144,537,011
150,510,721
139,307,941
86,267,557
2,567.526
136,740,415
63.09%
Total 2003
91,186,317
114.50% �3)
Dec Annualized
108,640, 131
4,235,758
60.63%
2,568,140
LABOR ENTRY SYSTEM SIT PAYROLL EXCL 242
Operating Portion
Operating Percent
VACATION & HOLIDAYS TAKEN
LABOR ENTRY SYSTEM SIT PAYROLL INCL 242
Percent Operating/Gross Payroll 2002 Actual:
Operating Payroll
2002 Total Payroll
Operating Payroll Percent of Total
84,824,253
58,3_;3...9"� (68.78%)
12,295,832
97,120,086
61,152,115
100,864,610
RO.Rel%
J:f
• Officer pay May 2003 YTD
DCE Acct Amount Oubtotale Percent
111 242020 267.55
111 242030 38,295.89
111 242032 4,215.39
111 2'12050 91,799.93 134,578.76 13.25%
111 417420 226,859.95
111 4174?? 7.177.49
111 417423 15,418.84
111 417427 12,733.09
111 417430 4,601.62
� 11 417446 2,562.49
111 426400 6,693.00 276,046.48 27.18%
111 920000 604,951.29 604,951.29 59.57%
Total May YTD 1,015,576.53 100.00%
Annualized
/11 X 26 \..-2,400,453.62 . ..._) --- .. -�-- ------ .. - -··· .
•
/31
Forrey, Dave
•From: Sent: To:
Subject:
Brilz, Maggie
Monday, July 07, 2003 11 :22 AM
Forrey, Dave
FW· Normalized Incentive
Maggie Brilz
Pricing and Regulatory Services
Idaho Power Company
[phone]
[phone] (tax)
mbri![e-mail]
Oriqincl Mcccage-----
From: Williams, Jan
Sent: Tuesday, April 29, 2003 5:41 PM
To: Brilz, Maggie
Subject; Normoli;,cd Incoritivo
The methodology we used to determine a "normalized" incentive was to calculate the percent difference in empioyee pay between the 50th %ile and the 60th %ile, using the most current salary surveys.
The difterence was 7.85%, which is consistent with other recent measures: -. It's not coincidence that we used 7% as the
incentive target payout for the employee incentive plan for 2003. The . 7% t�'rget measures the performance necessary for e Ami,loyP.P.s 10 receive 60th %ile total cash compensation. -..._//
I hope this explanation is sufficient for your purposes. If you need anything more, don't hesitate to ask.
Jan
/ft
Exhibit 23
Retirement Plan for Employees of Idaho Power Company
(263,000)
729,091
360,911
827,002
Jtl; I I
23,445,535
282,420,076
0
6,590,260
294,933,783
6,590,260
1 \:J,463,189
$9,530,065
048 279 �--)
36
(I} Milliman USA
5. Net Periodic Pension Cost
[(1 c) + (2c) - (3d) + (4d)]
4. Net Amortization Payments
a. Unrecognized Net Transition Obligation I (Asset)
b. Unrecognized Prior Service Cn!';t
c. Unrecognized Net (Gain) I Loss
d. Total amortization payments [(a)+ (b) + (c)]
ipef007� rlnr
620119 IPC lOIBCF/fll.Slltjl<
3. Expected Return on plan assets
a. Market-Related Value of plan assets as of January 1, 2003
b. Expected contributions, weighted for timing
c. Expected distributions. weighted for tirninq
d. Expected Return on plan assets at 8.50%
[(a)+ (b) - (c) x 8.50%]
Net Periodic Pension Cost
Pension Expense
2. Interest Cost
a. Projected Benefit Obligation as of January 1, 2003
b FxrP.cted distributions. weiqhted for timing
c. Interest Cost at 6.75% [{(a) - (b)} x 6.75%]
1 . Service Cost
a. Normal Cost as of January 1 , 2003
b. Interest at G.75%
c. Service Cost [(a)+ (b)]
The NP.t Periodic Pension Cost for the fiscal year ending December 31, 2003 is determined
below. The primary actuarial assumptions used were established on the December 31,
2002 measurement date and included a discount rate of 6.75%, an expected long-term rate
of return on assets of 8.50%, and a rate of compensation increases of 4.50%. This expense
amount is subject to change if a significant plan-related event (such as a plan merger, spin­
oit, settlement, curtailment, or amendment) should occur before the end of the fiscal year.
Farrey, Dave
•-=rom:
'ent:
To:
Subject:
Forrey, Dave
Wednesday, July 02, 2003 9:03 AM
Forrey, Dave
FW: Rog,mce Blue Shield RX unhillPrl amount
The new account sot up for this is payable is 232913. Larry we will make the entry in the April close.
Darrell, The total amount of RX expenses that have not been billed by Regence Blue Shield is $647,633.67. The
yearly break do.wrLis_____ /_,_. _-::. :.i,,l':. • 20021$485,266.00 J :;,;.,::-! · _ ': · , _.,!i ,-- '--- , ,,,:)'/, • 2003 - 162,367.67 °v. Y1 · t-�i::i =r c. . 1-:
Tho cc charges should be bookPrl In accm mt �2fi 120.
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e Combined Property (924) and Liability (925) Insurance
Annualizing Adjustment
2003 New Monthly Payment $ 561,647
X 12 months = 2003 Annualized Cost $ 6,739,760
Less 2003 Estimated Cost $ (6,334,487)
Adjustment to 2003 Estimate $ 405,273
Annualized 2003 Estimate $ 6,739,760
Known & Measurable Adjustment
2004 New Monthly Payment - 10% premium mcroaso $ 593,613
X 12 months = 2004 Estimated Cos! $ 7,123,358
Looo :2008 /\nnualizod E:::stimat,;;,d Co.c:t s (6.739.760)
Adjustment to 2003 Annualized Estimate $ 383,598
Total Adjustments $ 788,871 /�) fl.? - Percent to Subsidiaries 5.11%
Balance to Idaho Power $ 748,597
Note:
Service Level Agreement:
Total 2003 Revised Budget
Subsidiary Reimbursements on SLA's
Percent ot Total 2003 Budget
6,365,987
325,000
5.11%
Insurance O&M Charges
Estimated
Type of Insurance Account 2003
Estimafed
2004 Difference
Propertylnsruance 924 $ 3,912,680 $ 3,782,060 $ (130,620) -3.3%
Liability Insurance 925 $ 2,421,807 $ 3,341,298 $ 919,491) 38.0%
Total lnsuance Charges $ 6,334,487 $ 7,123,358 $ 788,871 12.5%
Note: Estimated total for 2003 is same as line 3 of Summary Sheet
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•
•
Idaho Power Company
Before The Idaho Publlc Utilities Commission
Additional Ratebase and Expense Adjustments
Account
Line No. Rate base Revenue Exeense
No. Description
Incremental Security Costs Order 28975 182 $ 728,766 (1)
2 Intervenor Funding - DSM/Land and Water Fund of the Rockies 928 $ 4,953@
3 Prairie Acquisition Adjustment 114 $ (454,449)
4 115 259,413
5 $ (195,036) (1)
6 Other Operating Revenue - Cable One 454 $ 346,171
A��ot l=lolirtam"nl ()hlio:atinn ·('.1)
7 Electric Plant in Service 101 $ (1,577,314)
8 Accum Resv for Depree 108 $ 106,204,710
10 Prepaid Pension 165 $ 17,800,477 (2)
(1) Included in 2003 operating costs.
(:2) lnoludod in :2003 operating cocte arrd known and m":;,c;;11r:ahlA :arlj, 1,::tmAnt,::
(3) 13 month average
•
•
Line
No
1
2
3
Line
No
4 Actual
5 Actual
6 Actual
7 Actual
8 Actual
9 Actual
10 Forecast
11 Forecast
12 Forecast
13 Forecast
14 Forecast
15 Forecast
16
IDAHO POWER COMPANY
DEDUCTIONS FROM OPERATION AND MAINTENANCE EXPENSES
For The Twelve Months Ended December 31, 2003
TOTAL DEDUCTIONS FROM OPERATION AND MAINTENANCE EXPENSE:
General advertising expense .
Memberships and contributions .
Total deductions .
CENEP.1'.L .'\DVEP.TISII\TG! EXPEI\T£:R (llC'r:'nTThl'T' q,n 1)
Mon ch
January, 2003 .
February .
March .
April ······.················
May .
June .
July .
August .
September .
October .
November .
December .
Total .
(1)
Amount
$452,109
28,384
$480,493
(1)
Amount
sz . 234
18,2H
9, 33.;1.
9,105
22, 607
76, 147
59,542
2 9, 3 87
56,615
60,535
49,842
58,546
$452.109
•
Idaho Power Company
Customer Accounting Expenses-Account #902
For The Twelve Months Ended December 31, 2002
st:ate ot ld:;iho
Customer Recorders
Average Cost Cost Cost w/Phones Total
Description Customers to Read � Mo Allocation :Ji432/Year Costs
RESIDENTIAL (1) 326,788.3 0.84 274,502 3,134,207 0 3,134,207
SMALL COMMERCIAL (7)
Secondary - Recorders Read Via Phone Lines 0.0 162.92 0 0 0 0
Secondary - Other 31,388.3 0.91 28,563 326,130 Q 326 130
Total 31,388.3 28,563 326,130 0 326,130
COMMERCIAL SERVICE (9)
Transmission - Recorders Read Via Phone Lines 3.0 162.92 489 5,581 1,296 6,877
F1i111c11y • Recorder:-, nead Via rhonc Lincc 112.0 162.92 rn.?47 ::>OR.341 48.384 256.725 Secondary - Recorders Read Via Phone Lines 11.0 162.92 1,792 20,462 4,752 25,214
Secondary - Other 16.908.3 0.86 14 541 166,028 Q 166 028
Total 17,034.3 16,822 192,071 54,432 246,503
UNIFORM CONTRACTS (19)
Transmission - Recorders Read Via Phone Lines 6.0 162.92 978 11,161 2,592 13,753
Primary - Recorders Read Via Phone Lines 96.0 162.92 15,640 178,578 41,472 220,050
Secondary - Recorders Read Via Phone Lines .LQ 162.92 163 1 860 432 2 292
Total 103.0 16,781 191,599 44,496 230,095
IRRIGATION· ON (24)
Secondary - Recorders Read Via PhOne Lines 0.0 162.92 0 0 0 0 Secondary - umer 1:3.307.3 1.10 14.638 167,133 Q 167 133
Total 13,307.3 14,638 167,133 0 167,133
Unmetered General Service (40) 1,172.6 0.00 0 0 0 0
Municipal Street Lighting ( 41) 120.0 0.00 0 0 0 0
Trattic Control Lighting (42) 56.3 0.00 Q Q Q Q
Total 1,348.9 0 0 0 0
SPECIAL CONTRAr.TS
INEL 1.0 162.92 163 1,860 432 2,2\:12
Micron 1.0 162.92 163 1,860 432 2,292
Simplot {R29) .LQ 162.92 163 1 860 432 2,292
Total 3.0 489 5,581 1,296 6,877
Total Idaho Retail Sales 389,973.1 351,795 4,016,721 100,224 4,116,945
ACCT902 (Dollars).jcb
Idaho Power Company
Customer Accounting Expenses-Account #902
For The Twelve Months Ended December 31, 2002
etate or oreyu11
Customer Recorders
Average Cost cost Cost w/Phones Total
DescriQt1on Customers to Read Cc:P Mo Allocation �32/Year Costs
RESIDENTIAL (1) 12.975.8 1.09 14.144 161,488 0 161,488
SMALL COMMERCIAL (7) 2,212.5 1.08 2,390 27,283 0 27,283
COMMERCIAL SERVICE (9)
Transmission - Recorders Read Via Phone Lines 0.0 162.92 0 0 0 0
Primary - Recorders Read Via Phone Lines 5.0 162.92 815 9,301 2,160 11,461
Secondary - Recorders Read Via Phone Lines 1.0 162.92 163 1,860 432 2,292
Secondary - Other 897.3 1.09 978 11 167 Q 11 167
Total 903.3 1, 141 10,0£7 �,50� 16,61G
UNIFORM CONTRACTS (19)
Transmission - Recorders Read Via Phone Lines 2.0 162.92 326 3,720 864 4,584
Frllllc:!IY - F\ei.;u1Llt,1:, F\t,a(l Via P1-,011e Line" 6.0 16:2.02 078 11, 1R1 ?.',�? 13.753 Secondary - Recorders Read Via Phone Lines 0.0 162.92 Q Q Q Q
Total 8.0 0.00 1,303 14,881 3,456 18,337
IRRIGATION· ON (24)
Transmission· Recorders Read Via Phone Lines 0.0 162.92 0 0 0 0
Secondary - Recorders Read Via Phone Lines 0.0 162.92 0 0 0 0
Secondary • Other 1.209.7 1.08 1 306 14,917 Q 14 917
Total 1,209.7 1,306 14,917 0 14,917
Unmetered General Service (40) 7.1 0.00 0 0 0 0
Municipal Street Lighting (41) 13.0 0.00 0 0 0 0
Trattic Control Lighting (42) 8.0 0.00 Q Q Q Q Total 28.1 0 0 0 0
Total Oregon Retail Sales 17,337.3 20,284 231,596 6,048 237,644
ACCT902 (Dollarsl.jcb /5/
• Idaho Power Company
Customer Accounting Expenses-Account #902
For The Twelve Months Ended December 31, 2002
Total Compony
Description
RESIDENTIAL (1)
SMALL COMMERCIAL (7)
Recorders Read Via Phone Lines
Other
Total
COMMERCIAL SERVICE (9)
Recorders Read Via Phone Lines umer
Total
UNIFORM CONTRACTS (19)
Fle corcie rc ncad Via Phone Lincc
IRRIGATION· ON (24)
Recorders Read Via Phone Lines
Other
Total
Unmetered General Service (40)
Municipal Street Lighting (41) Traffic Control Lighting (42)
Total
SPECIAL CONTRACTS
INEEL
Micron
Simplot (R29)
Total
Total Retail Sales
SALES FOR RESALE-FIRM (")
TOTAL COMPANY
Average
Customers
339,764.1
0.0
33 600.8
33,600.8
132.0
17.60:i.O
17.937.6
111.0
0.0
14 516.9
14,516.9
1,179.7
133.0 64.3
1,377.0
1.0
1.0
.1.Q 3.0
407,310.4 ' l!J)_
407,316.4
Recorders
Cost Cost w/Phones Total
r@ Mo Allocation �432/Year Costs
288,646 3,295,696 0 3,295,696
0 0 0 0
30 953 353 413 Q. 353 413
30,953 353.413 0 353,413
21,505 245,545 57,024 302,569
1�1!;1S 177,105 Q 177 Hl6
17,963 205,097 57,024 262, 121
18,0lclL!. ?nR.'1H1 '17Wi? 2!'i4433
0 0 0 0
15 944 182 050 Q. 182 050
15,944 182,050 0 182,050
0 0 0 0
0 0 0 0
ll. Q Q Q
0 0 0 0
163 1,860 432 2,292
163 1,860 432 2,292
163 1 860 432 2 292
489 5,581 1,296 6,877
372,079 4,248,317 106,272 4,354,589
978 11, 161 1 296 12.457{1''1"')
373,056 4,259,478 107,568 4,367,046
p (} 6;.}05' .r».
FA /f !i9 ( //-'- ,..; I .!3A �w·) ( J (') Weiser has one recorder; Ratt River has two recorders
All others (Azusa, Oregon Trail, UAMPS, Washington City)
are either "Scheduled" or "Contract Demand" Customers
ACCT902 (Dollars).jcb /5J
I ACCOUNTS READ VIA PHONE LINE
FOR THE YEAR ENDED DECEMBER 31, 2002
State Rate No. of Meters Monthly Annual
Schedule Charges Charges
Idaho
109S 11 $396 $4,752
109P 112 $4,032 $48,384
109T 3 $108 $1,296
119S $36 $432
1191"' 93 $3.348 $40,176
119T 7 $252 $3,024
125SB $36 $432
187 8 $288 $3,456
ISBNA , $36 $432
ISBPL 1 $36 $432
ISBT1 1 $36 $432
239 $8,604 $103,248
Oregon
009S , $36 $432
009P 5 $180 $2,160
019P 5 $180 $2,160
019T 2 $72 $864
087 $36 $432
OSBN $36 $432
15 $540 $6,480
Total 254 $9,144 $109,728
••
Average Telephone Charges for Meters With Recorders =
11 '/3i. .u,.J. v O
$36.00 Each per Month
$109,728.00 Annual Total
I IDAHO POWER COMPANY
METERING INFORMATION
TWELVE MONTHS ENDING DECEMBER 31, 2002
READING AND PROCESSING OF PULSE RECORDING DEVICES
The following reproccnts th" mon1hty labor cost averaoe horn company wide efforts in maintaining pulse recording meters/devices in 2002
Company Wide LCBS Accounts (Excluding Sale for Resale and Coqeneration)
Load Profile Recording Devices
••• Total Company 288
AnnualLaborCostperAccount $1,955
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•
•
Idaho Power Company
Customer Accounting Expenses - Account #903
For the Twelve Months Ended December 31, 2002
State of Idaho
Average Cost
Description Customers Allocation
RESIDENTIAL (1) 326,788.3 5,506,831
SMALL COMMERCIAL (7) 31,388.3 528,936
COMMERCIAL SERVICE (9)
Transmission 3.0 180
Primary 112.0 6,720
Secondary 16,919.3 285,113
Total 17,034.3 292,013
UNIFORM CONTRACTS (19)
Transmission 6.0 360
Primary 96.0 5,760
Secondary .L.Q 60
Total 103.0 6,180
IRRIGATION - ON (24)
Transmission 0.0 0
Secondary 13,307.3 224,246
Total 13,307.3 224,246
Unmetered General Service (40) 1,172.6 19,760
Municipal Street Lighting (41) 120.0 2,022
Traffic Control Lighting (42) 56.3 949
Total 1,348.9 22,731
SPECIAL CONTRACTS
INEEL 1.0 60
Micron 1.0 60
Simplot (R29) .L.Q 60
Total 3.0 180
Total Idaho 389,973.1 6,581,117
ACCT903. 7/15/2003.mb /%
• Idaho Power Company
Customer Accounting Expenses - Account #903
For the Twelve Months Ended December 31, 2002
State of Oregon
•
Description
RESIDENTIAL (1)
SMALL COMMERCIAL (7)
COMMERCIAL SERVICE (9)
Transmission
Primary
Secondary
Total
UNIFORM CONTRACTS (19)
Transrniscinn
Primary
Secondary
Total
IRRIGATION - ON (24)
Transmission
Secondary
Total
Unmetered General Service (40)
Municipal Street Lighting (41)
Traffic Control Lighting (42)
Total
Total Oregon
ACCT903.7/15/2003.mb
Average
Customers
12,975.8
2,212.5
0.0
5.0
898.0
008.0
2.0
6.0
0.0
8.0
0.0
1 :::>09.7
1,209.7
7.1
13.0
8.0
28.1
17,337.1
Cost
Allocation
218,660
37,284
0
300
15,133
15,433
120
360
Q
480
0
20.385
20,385
120
219
135
474
292,716
•
•
Idaho Power Company
Customer Accounting Expenses - Account #903
For the Twelve Months Ended December 31, 2002
Total Company
Average Cost
Description Customers Allocation
Hestdennat 339,704.1 5,725,401
Small Commercial (7) 33,600.8 566,220
Commercial Service (9) 17,937.3 307,446
Uniform Contracts (19) 111.0 6,660
Irrigation - On (24) 14,517.0 244,631
Unmetered General Service (40) 1,179.7 19,880
Municipal Street Lighting (41) 133.0 2,241
I ramc control Lighting (42) 64.3 1,08'1
Total 1,377.0 23,205
SPECIAL CONTRACTS
Astaris 0.0 0
!NEEL 1.0 60
Micron 1.0 60
Simplot (R29) .LQ 60
Total 3.0 180
Total Company 407,310.2 6,873,833
ACCT903.7/15/2003.mb
•
To:
Re:
Maggie Brilz
Large Power Billing
Date: Julyl4, 2003
From: Todd Schultz
Maggie rhe following information describes the annual cost associated with billing
industrial customers. These are the costs associated with time spent within the CAMC on
billing 255 "large power" customers. The costs are:
•
Customer Service Representative II
(CSR II grade 17 step 13, 35% of their annual time spent)
If you need additional information please let me know .
$15,186.08
•
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• Idaho Power Company
Allocation of Account #908 - Miscellaneous
For the Twelve Months Ended December 31, 2003
Annualizing Adjustment: Expiration of DSM Amortization in Oregon
Program Allocations: Idaho Oregon Total
Jurisdictional Allocations
DSM Amortization: 3,266,412 0 3,266,412
Other Miscellaneous (1): 4,272,950 189,974 4,462,924
Total Misc I DA908 7,539,362 189,974 7,729,336
•
(1) 2002 Averaae Number of Customers
Rate Idaho Oreaon Total
1 326,788 12,976 339,764
7 31,388 2,213 33,601
9 17,034 903 17,937
15 0 0 0
19 103 8 111
24 13,307 1,210 14,517
40 1,173 7 1, 180
41 120 13 133
42 56 8 64
Subtotal 389,969 17,338 407,307
Astaris 0 0 0
Micron 1 0 1
Simplot 1 0 1
INEEL 1 0 1
Subtotal 3 0 3
Total 389,972 17,338 407,310
91212003/DA908.xlsljcb
/fl
• Idaho Power Company
Allocation of Account #908 - Miscellaneous
For the Twelve Months Ended December 31, 2003
Program Allocations:
Jurisdictional Allocations
DSM Amortization:
Other Miscell:;:mP.ous (1):
Total Misc I DA908
3,266,412
4.272.950
7,539,362
Oregon
.. --·-- ..,
/ � ( 0 I
4&;-3:00--
189,974
236,274
3,312,712
4,462,924
�$)
(1)
�M/./ f).5,/\7 /11><-;?t:U:./7.?#;z::;t,-­
� �"'?-->-- /A,- �.r h_�
�er/1/Q'/1-L/2r/v'O- �� -7 £:'
2002 Averaae Number of Customers
Rate Idaho Oreaon Total
1 :\?f\.788 12.976 339,764
7 31,388 2,213 33,601
9 17,034 903 17,937
15 0 0 0
19 103 8 111
24 13,307 1,210 14,517
40 1, 173 7 1,180
41 120 13 133
42 56 8 64
Subtotal 389,969 17,338 407,307
Astaris 0 0 0
Micron 1 0 1
Simplot 1 0 1
INEEL 1 0 1
Subtotal 3 0 3
Total 389.972 17,338 407,310
8118120031DA9081jcb
j/J
I
•
• 8/18/20031DA908{jcb
Idaho Power Company
Allocation of Account #908 - Miscellaneous
For the Twelve Months Ended December 31, 2003
Program Allocations: Idaho Oregon Total
Jurisdictional Allocations
DSM Amortization: 3,266,412 46,300 3,312,712
Other Miscellaneous (1): 4,272,950 189,974 4,462,924
Total Misc I DA908 7,539,362 236,274 7,775,636
) 2002 Averaae Number of Customers
Rate Idaho Orea on Total
1 326,788 12,976 339,764
7 31,388 2,213 33,601
9 17,034 903 17,937
15 0 0 0
19 103 8 111
24 13,307 1,210 14,517
40 1,173 7 1,180
41 120 13 133
42 56 8 64
Subtotal 389,969 17,338 407,307
Astaris 0 0 0
Micron 1 0 1
Simplot 1 0 1
INEEL 1 0 1
Subtotal 3 0 3
Total �3�9,972 17,338 407,310 �--
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• Idaho Power Company
Detail of Annualizing Adjustmont
Depreciation Expense in Account 403
2003 Expected to 2004 Depreciation using 12/03 Plant Balances
\.. -
2003 Depreciation Expense - Expected
2004 Depreciation Expense based on 12/03 Plant
Increase to Depreciation Expense using December Plant
Increase to Depreciation Reserve Account 108 (Average)
$ 88,152,411
$ 91,072,585
$ 2,920, 174 1
$ 1,460,087 1
1 Detail by FERC categories: A/C 403 A/C 108
Total Steam Production $ 547,152 $ 273,576 • Total Hydro Production $ 66,091 $ 33,046
Total Other Production $ 41,726 $ 20,863
Total Transmission Stations $ 241,636 $ 120,818
Total Transmission Lines $ 343,923 $ 171,961
Total Distribution Stations $ 151,689 $ 75,845
Total Distribution Lines $ 711,960 $ 355,980
Total General $ 815,996 $ 407,998
Total Adjustment $ 2,920,174" s 1,400,mrr
•
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• Idaho Power Company
Detail of Known and Measurable Adjustment
Depreciation Expense in Account 403
Adjust from Old Depreciation Rates to New Depreciation Rates
2004 Depreciation Expense - Expected Old Rates
2004 Depreciation Expense - Expected New Rates
Increase to Depreciation Expense using New Rates
Increase to Depreciation Reserve Account 108 (Average)
$ 91,072,585
$ 97,048,855
$ 5,976,270 1
$ 2,988,135 1
1 Detail by FERC categories: AJC 403 AJC 108
Total Steam Production $ (731,839) $ (365,919)
Total Hydro Production $ 1,450,788 $ 725,394 • Total Other Production $ (262,608) s (126,30'1)
Total Transmission Stations $ (1,239,503) $ (619,751)
Total Transmission Lines $ 1,443,320 $ 721,660
Total Distribution Stations $ (1,144,416) $ (572,208)
Total Distribution Lines $ (5,243, 126) $ (2,621,563)
Total General $ 11,693,653 $ 5,846,826
Total Adjustment $ 5.976.270 ,' $ 2.988.135
•
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!EC,
IDAHO POWER COMPANY - JURISDICTIONAL SEPARATION STUDY
ACTUAL, ESTIMATED AND ADJUSTED DATA
TWELVE MONTHS ENDED DECEMBER 31, 2003
1 Results may be entered directly into data (0) (FJ (G)
2 sheet with a "values only" copy/paste. TOTALS ANNL. K.&M.
3 DESCRIPTION PER BOOKS ADJUST. ADJUST. • 4 * * * SUMMARY OF ADJUSTMENTS * * *
5
6 Depreciation Adjustments.
7 Total Steam Production 547,152 (73"1,839)
8 Total Hydro Production 66,091 1,450.788
9 Total Other Production 41,726 (252,608)
10 Total Transmission Stations 241,636 (1,2:l�.503)
11 Total Transmission Lines 343,923 1,443,320
12 Total Distribution Stations 151,689 (1,144.416)
13 Total Distribution Lines 711,960 (5,243, 126)
14 Total General 815.996 11,693,653
15 Total Adjustment 2,920,173 5,976,269
16
17 Plant Additions:
18 Total Steam Production 207,729 0
19 Total Hydro Production 0 0
20 Total Other Production 0 0
21 Total Transmission Stations 63,520 341,945
22 Total Transmission Lines 227,178 105,431
23 Total Distribution Stations 0 0
24 Total Distribution Lines 0 0
25 Total General 0 0
26 Total Adjustment 498,427 447,376
27
28 Total of All Adjustments 3,418,600 6,423,645
29
30 * ** T.A9LE 6-DEPREC/ATION & JJMORT/lJJTION FXPFN.<;F •• •
31
32 DEPRECIATION EXPENSE
33 310-316 / STEAM PRODUCTION 23,518.215 754.881 (731,839)
34 330-336 / HYDRAULIC PRODUCTION 12,126,522 66,091 1,450,788
35 340-346 / OTHER PRODUCTION 1,677,605 41,726 (252,608)
36 TOTAL PRODUCTION PLANT 37.322.342 862,698 466,341
37
38 TRANSMISSION PLANT
39 350 I LAND & LAND RIGHTS 236,369 9,365 (48.041)
40 352 / STRUCTURES & IMPROVEMENTS 926,157 36,696 (188,237)
41 353/STATION EQUIPMENT 4,936,020 259,095 (661.280)
42 354/ TOWERS & FIXTURES 1,098,227 74,035 310,697
43 355 / POLES & FIXTURES 2,074,354 139,838 586,851
44 356 / OVERHEAD CONDUCTORS & DEVICES 1iU4,J1/ J56,90:l 649,835
45 359 / ROADS & TRAILS 4,839 326 1,369
46 TOTAL TRANSMISSION PLANT 11,200,283 876,257 651,193
pao: Adjust_Dep-403 & 108.Depreciation_Expense.8/15/2003.6:44 AM Page 1 of 2
• 48 DISTRIBUTION PLANT
49 360 I LAND & LAND RIGHTS
50 361 / STRUCTURES & IMPROVEMENTS
51 362/STATION EQUIPMENT
52 364 / POLES. TOWERS & FIXTURES
53 365 / OVERHEAD CONDUCTORS & DEVICES
54 366 / UNDERGROUND CONDUIT
55 367 I UNDERGROUND CONDUCTORS & DEVICES
56 368 / LINE TRANSFORMERS
57 369 I SERVICES
58 370 I METERS
59 371 / INSTALLATIONS ON CUSTOMER PREMISES
60 373 / STREET LIGHTING SYSTEMS
61 TOTAL DISTRIBUTION PLANT
62 *••TABLE 6-DEPRECIATION & AMORTIZATION EXPENSE•••
63
64 #
65 389 I LAND & LAND RIGHTS
66 390 I STRUCTURES & IMPROVEMENTS
67 391 I OFFICE FURNITURE & EQUIPMENT
68 392 / TRANSPORTATION EQUIPMENT
69 393 / STORES EQUIPMENT
70 394 / I OOLS, SHOP & GARAGE EQUIPMENT
71 3951 LABORATORY EQUIPMENT
72 396 / POWER OPERA TED EQUIPMENT
73 307 /COMMUNICATIO�IS i=OUIPMl=MT
7 4 398 / MISCELLANEOUS EQUIPMENT
75 TOT AL GENERAL PLANT
76 #
77 # TOTAL DEPRECIATION EXPENSE
pao: Adjust_Dep-403 & 108.Depreciation_Expense.8/15/2003.6:44 AM.
652,562
0
4:lL,ti1o
3,005,202
5,899,878
2,273, 124
666,993
4,376,201
10, 147,291
2,263,060
1,146,305
173,257
184,745
30,568,670
0
1,333,097
5,915,998
4,327
40,038
167,526
432,835
8,569
1039205
119,522
9,061,116
88,152,411
0
19,089
132,600
154,823
59,651
17,503
114,839
266,282
59.387
30,081
4,547
4,848
863,649
60,026
266,382
195
1,803
7,543
19,489
386
46,793
5.382
407,998
815,996
3,418,600
(G)
K.&M.
ADJUST.
0
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(1,140,171)
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(221,527)
(33,482)
(35,703)
(6,387,542)
860,201
3,817,390
2,792
25,835
108,099
279.293
5,529
670,563
77.124
5,846,827
11,693,653
6.423,645
Page 2 of 2
IDAHO POWER COMPANY - JURISDICTIONAL SEPARATION STUDY
ACTUAL, ESTIMATED AND ADJUSTED DATA
TWELVE MONTHS ENDED DECEMBER 31, 2003 1 Results may be entered directly into data (0) (F)
2 sheet with a "values only" copy/paste. TOTALS ANNL.
3 DESCRIPTION PER BOOKS ADJUST.
47
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• IDAHO POWER COMPANY
Ad Valorem Tax Allocation
TOTAL SYSTEM
Calendar Year 2003 / RATE CASE
STEAM ELECTRIC PLANTS:
Jim Bridger
Val my
Boardman
Total Steam
$896,081
937, 198
425,945
$2,259,223
OTHER:
Production 3,917,997
Transmission 3,041,917
Distribution 6,242,686
General Plant 1,417,275
Total Other 14,619,876
TOTAL SYSTEM AD VALOREM TAXES $16,879,100
K·\OTI\MSC\03\Ad Valorem Tax Allocation Rate Case
12-Jun-03
• Page2
IDAHO POWER COMPANY
Ad Valorem Tax Allocation
Calendar Year 2003 / RATE CASE
Idaho
Steam Electric Plants In Idaho:
Nnm�
Total Steam
Other:
Production
Transmission
Distribution
General Plant
Total Other
TOTAL IDAHO AD VALOREM TAXES
K:\OTI\MSC\03\Ad Valorem Tax Allocation Rate Case
12-Jun-03
$0
3, 119,475
2,639,293
5,693,845
1,409,572
$0
12,862, 186
$12,802, 186
• Page 3
IDAHO POWER COMPANY
Ad Valorem Tax Allocation
Calendar Year 2003 I RA TE CASE
Montana
•
Steam Electric Plants in Montana:
None
Total Steam Electric Plants
Other:
Production
Transmission
Distribution
General Plant
Total Other
Total Montana Ad Valorem Taxes
K:IOTI\MSC\03\Ad Valorem Tax Allocation Rate Case
12-Jun-03
$0
0
80,000
0
0
$0
80,000
$60,000
Page4
Idaho Power Company
Ad Valorem Tax Allocation
Calendar Year 2003 / RATE CASE
Nevada
Steam Electric Plants in Nevada:
Val my
Total Steam
Other:
Production
Transmission
Distribution
General Plant
Total Other
TOTAL NEVADA AD VALOREM TAXES
K:\OTIIMSC\03\Ad Valorem Tax Allocation Rate Case
12-Jun-03
0
17,408
3,999
0
$937, 198
21,407
$958,605
/8.
• Page 5
Idaho Power Company
Ad Valorem Tax Allocation
Calendar Year 2003 / RATE CASE
Oregon
•
Steam Electric Plants in Oregon:
Boardman
Total Steam
Other:
Production
Transmission
Distribution
General Plant
Total Other
TOTAL OREGON AD VALOREM TAXES
K:IOTI\MSC\03\Ad Valorem Tax Allocation Rate Case
12-Jun-03
$425,945
798,522
251,297
!:>44,842
7,703
$425,945
1,602,364
$2,028,310
/f1
• Page 6
Idaho Power Company
Ad Valorem Tax Allocation
Calendar Year 2003 / RATE CASE
Wyoming
•
Steam Electric Plants in Wyoming:
Jim Bridger
Total Steam
Other:
Production
Transmission
Distribution
General Plant
Total Other
TOTAL WYOMING AD VALOREM TAXES
K:IOTIIMSC\03\Ad Valorem Tax Allocation Rate Case
12-Jun-03
$896,081
$896,081
0
53,919
0
0
53,919
$950,000
;er
Basye, Katrina
�
.Ject:
Phil,
Obenchain, Phil
Tomlinson, Darrell; MacMahon, Bruce
Ad Valorem Tax Allocation for the Rate Case
The attachment contains the tax allocation you need. Please use the worksheet titled "Rate Case Final Doc". The
remainder of the worksheets are for support only.
Also you will note that for Nevada there is recorded a distribution tax. In Nevada the 00 investment year which
IPCO had distribution investment applys to the 02/03 tax year.
A hard copy is in the mail too.
Please call me if you have any questions.
Katrina
Ad Valorem Tax
Allocation Rate ...
•
ff(
J :\OTIIKWHiIDA\2003\[CLSALL03ratecase.xls]Class Allocation & Irrig Exmpt
14-ful-03
IDAHO POWER COMPANY
NORMALIZED
CLASS ALLOCATION OF KWH TAXES
2003 Rate case
KWH TAX SUMMARY
358,325
579,854
2,674,139
358,325
358,325
IRRIGA
REBATE
ADJUST
1---____::=.;__ __
-+------,,-+-----o-�,;.:+----�1-------+---1-4_0,_8_0:::-11ru:nmm1ml::r\::::]t::
41,269
IDAHO JURISDICTIONAL KWH TAX
IDAHO JURISDICTIONAL IRRIGATION REFUND
IDAHO JURISDICTIONAL INDUSTRIAL EXEMPTION
NET IDAHO JURISDICTIONAL KWH TAX
TOTAL % of %
RATE NORMALIZED NORMALIZED x
SCHEDULE KWH KWH KWH IAX
1&A 4,141,393,426 34.24% 915,501
7&8 265,335,667 2.19% 58,655
9 & LP 3,014,426,986 24.92% 666,372
LW/10 0 0.00% 0
15 & OL 5,872,586 0.05% 1,298
16 0 0.00% 0
17 0 0.00% 0
18 0 0.00% 0
19 1,978,824,237 16.36% 437,441
OP/23 0 0.00% 0
LU/22 0 0.00% 0
24, I, & 25 1,620,930,931 13.40% 358,325
26 636,967,670 5.27% 140,809
27 0 0.00% 0
28 0 0.00% 0
29 186,684,665 1.54% 41,269
30 203,084,146 1.68% 44,894
32 33,297 0.00% 7
40/UM 16,054,942 0.13% 3,549
41 17,845,445 0.15% 3,945
42 9,384,218 0.08% 2,074
46 0 0.00% 0
72 0 0.00% 0
91 0 0.00% 0
92 0 0.00% 0
99 0 0.00% 0
TOTAL 12,096,838,216 100.00% 2,674,139 -
1---____:�--+-----:-+----':-'-:--:-::-'-+------=-+--���-t---3-2s-.-79-7��+ii���
1------;---______.,...._....,....,;----r--------;----
' : mrrm,imii�rn
I�
•
, .. , " ... /
July 22, 2003
k:/oti/msc/2003/165236 Rate Case
IDAHO POWER COMPANY
TAXES OTHER THAN INCOME TAXES
FOR THE YEAR ENDED DECEMBER 31, 2003
165236an.xlw /f;
Line Jan· June July • December 2003
No DESCnlr>TION Actual Ei;timate AMOUNT
State, county and local taxes:
Real and personal property:
4 Idaho 6,400,000.00 6,400,000.00 12,800,000.00
5 Oregon 977,891.47 1,050,418.00 2,028,309.47
6 Montana 40,000.00 40,000.00 80,000.00
7 Wyoming 4 75.()()() on 475.000.00 950.000.00
8 Nevada 468,604.92 490,000.00 958,604.92
9 Shoshone-Bannock 31,093.00 31,093.00 62,186.00
10 Total real and personal property 16,879,100.39
11 Kilowatt-hour tax - Idaho 2,094,285.00
I iP.An<::A<:::
12 Wyoming - 2,964.62 2,964.62
13 Nevada 0 0 -
14 Shoshone-Bannock 150.00 - 150.00
lb 1 otai ucenses :>,114.C2
Regulatory commission:
16 Idaho 935,098.84 935,098.84 1,870, 197.68
17 Oregon 47,089.00 47,089.00 94,178.00
18 Nevada - 100.00 100.00
19 Total regulatory commission 1,964,475.68
Franchise:
20 Oregon (actual Jan - April) 234,544.09 227.100.00 461,644.09
21 Nevada (sold distribution) 0 0
22 Total franchise 461,644.09
23 TOTAL TAXES OTHER THAN INCOME TAXES 21,402,619.78
� J:IOTIIKWHIIDA\2003\[CLSALLD3ratecase.xls]Class Allocation & lrrig Exmpt
- 14-Jul-03
IDAHO POWER COMPANY
NORMALIZED KWH TAX
2003 Rate Case
Normalized annual Idaho hydro KWH ( 1) 5,692,200,000 KWH
% Of Total KWH Bartered, Sold or Exchanged (2) 93.9580% TAXES
Adjusted Idaho Hydro KWH 5,348,278,073 2,674,139
Normalized KWH sold to Idaho Customers (3) 12,096,838,216
% ofTotal Adjusted Idaho Hydro to ID Customers 44.2122%
LESS EXEMPTIONS:
Normalized Irrigation Exemption (4) 1,620,930,931 358,325
Normalized Industrial Use Exemption (5) 2,623,051,560 579,854
TOTAL EXEMPTIONS minus% of total adj. ID hydro ID customers 1,876,357,945
Net taxable Normalized KWH 3,471,920, 128
NORMALIZED TAX DUE, 1/2 MIL Pen TAXAOLE KWH 1,736,060 1,736,060
Portion refunded to irrigation customers 358,325 358,325
TOTAL TAX AND REFUND 2,094,285 2,094,285
IDAHO POWER COMPANY
TAXES OTHER THAN INCOME TAXES
FOR THE YEAR ENDED DECEMBER 31, 2003
Line Jan -June July· December 2003 2002
No DESCRIPTION Actual Estimate AMOUNT AMOUNT
State, county and local toxco:
Real and personal property:
4 Idaho 6,400,000.00 6,400,000.00 12,800,000.00 12,166,517.82
5 Oregon 977,891.47 1,050,418.00 2,028,309.47 2,017.478.37
6 Montana 40,000.00 40,000.00 80,000.00 85,799.22
7 Wyoming 475,000.00 475,000.00 950,000.00 922,617.08
8 Nevada 468,604.92 490,000.00 958,604.92 964,014.18
9 Shoshone-Bannock 31,093.00 31,093.00 62,186.00 76,200.00
10 Total real and personal property 16,879, 100.39 16,232,627
11 Kilowatt-hour tax - Idaho Will be provided when acutal KWH is know through June 1,407,845.75
licenses:
12 Wyoming 2,964.62 2,964.62 2,964.62
13 Nevada 0 0 100.00
14 Shoshone-Bannock 150.00 150.00 150.00
15 Total licenses 3,114.62 3, 106.28
Regulatory commission:
16 Idaho 935,098 84 935,09884 1,870,197.68 1,714,255.78
17 Oregon 47,089.00 47,089.00 94,178.00 93,470.00
18 Nevada 100.00 1nn nn 1 """-.12 19 Total regulatory commission 1,964,475.68 1,809,261.90
Franchise:
20 Oregon (actual Jan - April) 234,544.09 227,100.00 461,644.09 452,903.71
21 Nevada (sold distribution) 0 0 -588.00
22 Total franchise 461,644.09 452,315.71
May 14, 2003
.msc/2003/165236 Rate Case
165236an.xlw
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!f6
Title:
Date:
Prepared by:
Delivered to:
Property Tax Expense
5/16/2003
Katrina Basye
Catie Miller
Description or Purpose:
To prepare January - June 2003 actual and estimate July - Dec 2003 property tax
expense. Reference lines 4-10.
Oregon & Nevada - The first six months are actual and the last six months are
estimated. These states are split year states 03/04 etc.
Idaho, Wyoming & Montana - the entire year is estimated as the bill is not received
until the end of November.
Shoshone-Bannock tax is actual for the entire year as April 15 is the due date.
Forecast Methodology Used:
Real and personal property taxes:
Appraisal Forecast Methodology: Historical data and actual data (to extent it is
known such as capitalization rate) is the forecast methodology.
Levy Forecast Methodology: Historical levy data (state not district) and local
government budget policy (if well defined) is used to estimated levies.
Assumptions used for Forecasting:
Real and personal property taxes:
Appraisal Assumptions: In forecasting the appraisal actual data is used to the
extent it is known and each states historical appraisal methodologies and trends
are used in forecasting the final appraisal.
Tax levy Assumptions: A state levy was assumed rather than individual taxing
districts to estimate taxes.
Allocation Method:
Not applicable
Assumptions used for Allocation:
Not applicahla
•
;a,r ///
\_- tc:\OTl\l'IU'\MSC\Ol\llATI!STAX
13-Feb-03
Page 1
IDAHO POWER COMPANY
Ad Valorem Tax Allocation
TOTAL SYSTEM
Calendar Year 2002
STEAM ELECTRIC PLANTS:
Jim Bridger
Valmy
Boardman
Total Steam
OTHER:
Production
Transmission
Dl�::. ::.mtion
General Plant
Total Other
TOTAL SYSTEM AD VALOREM TAXES
K:\011\PRP\MSC\OJ\RA Tl!ST AX
$670,252
948,334
398,569
3,776,002
2,913,602
5,976,399
1,349,467
$2,217,155
14,015,470
$16,232,625
IDAHO POWER COMPANY
TAXES OTHER THAN INCOME TAXES
FOR THE YEAR ENDED DECEMBER 31, 2002
ACTUAL
••··· Line
No DESCRIPTION AMOUNT
Federal taxes:
1 Unemployment 102,660.00 2 Social Security 8,284,494.20 3 Total federal taxes 8,387, 154.20
State, county and local taxes:
Real and personal property: 4 Idaho 12, 166,517.82 5 Oregon 2,017,478.37 6 Montana 85,799.22 7 Wyoming 922,617.08 8 Nevada 964,014.16 9 Shoshone-Bannock 76,200.00 10 Total real and personal property 16,232,626.67
, 1 Kilowatt-hour tax - Idaho 1,407,845.75
Licenses:
12 Wyoming 2,856.28 13 Nevada 100.00 14 Shoshone-Bannock 150.00 15 Total licenses 3,106.28 '
Regulatory commission:
16 Idaho 1,714,255.78 17 Oregon 93,470.00 18 Nevada 1,536.12 19 Total regulatory commission 1,809,261.90
Franchise:
20 Oregon 452,903.71 21 Nevada -!'iRB.00 22 Total franchise 452,315.71
23 Unemployment - total state 198,918.30
24 Total state, county and local taxes 20, 104,074.61
25 Total other taxes 28,491,228.81 26 Less: State & Fed P/R Loading Reversal (8,538,494. 17) 27 Net other taxes 19,952, 734.64
IC:IO'Il\MSC\2002\l65236rut:.hv
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IDAHO POWER COMPANY
2003 RATE CASE ESTIMATE
DEVELOPMENT OF STATE NET-TO-GROSS FACTORS
LINE - DESCRIPTION IDAHO OREGON OTHER COMPOSITE
1 - TAXABLE INCOME 100.000% 100.000% 100.000% 100.000%
2 - STATE COMPOSITE RATE (ACCRUED) 5.900% 0.300% 0.100% 6.300%
3-FEDERAL TAXABLE INCOME 94.100% 99.700% 99.900% 93.700%
4- FEDERAL INCOME TAX RATE - 35% 32.935% 34.895% 34.965% 32.795%
(LINE 3 @ 35%)
5 - NET OPERATING INCOME 61.165% 64.805% 64.935% 60.905%
6 - Nl::T-TO-GROSS !=ACTOR (1/1 INI= ") 1.642
k:\INC\FIN\RATE CASE\2003 RATE CASE NET TO GROSS FACTOR-EXHIBIT.xis
8(7/2003 4:01 PM
•
Line
No
2
.3
IDAHO POWER COMPANY
INTEREST CHARGES
For The Twelve Months Ended December 31, 2003
FORECAST
Description
Interest charges:
First mortoaoe bonds .
Other long-term debt .
::;norc-cerrn uelJL. .
(1)
Amount;
$46,147,000
9,799,723
951,312
4 Other interest charges ·���3_,_,_4_4_9_,_3_2_1�
•
•
5
6
7
Cost of Debt .
Cost of Preferred Stock .
5.991%
6.534%
;.a
Total interest charges ··====$=6=0='=3=4=7==,3::::::::::5=6=
• IDAHO POWER COMPANY
Interest Synchronization Adjustment
For the Twelve Months Ended December 31, 2003
LINE NO. DESCRIPTION Total
Total Company Rate Base 1,673,283,777
Adjustments to Rate Base:
2 Construction Work-in-Progress 103,822,493
3 Adjusted Rate Base 1, 777, 106,270
4 company we,gnrea cost or Debt 0.104%
5 Pro Forma Long Term Debt 55,694,511
Interest Expense
6 Other Interest Expense 4,400,633 • 7 Total Adjusted Interest Expense 60,095, 144
8 Actual Interest Expense 60,347,356
9 Interest Expense Adjustment -252,212
•
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IDAHO POWER COMPA-'JY
WAGES AND SALARIES (OTHER)
For The Twelve Months Ended December 31, 2003
FERC Y-T-D Forecast
LINE ACCOUNT J\CLUdl July Through
NO NUMBER DESCRIPTION June December TOTAL
Power production expenses:
Steam power generation -
Operation -
1 500 Oper and supv engineering 78,305 84,765 163,070
:J 501 Fuol 0
3 502 Steam expenses 0
4 505 Electric expenses 0
5 506 Misc steam power expenses 8,489 9,894 18,382
6 507 Rents 0
7 Total operation 86,793 94,659 181,452
Maintenance -
8 510 Main supv and engineering 0
9 511 Main of structures 0
10 513 MSlin of boilor pl;:int: 0
11 513 Main of electric plant 0
12 514 Main of misc steam plant 0
13 Total maintenance 0 0 0
14 Total steam power generation 86,793 94,659 181,452
Hydraulic power generation -
Operation -
15 535 Oper supv and engineering 1,392,464 1,466,197 2,858,660
16 536 Water for power 74,418 49,663 124,080
17 537 Hydraulic expenses 748,583 883,181 1,631,764
18 �.HJ �lectric expenses 42S,:il2 344,406 769,918
19 539 Misc hydro pwr gen exp 521,907 605,163 1,127,070
20 540 Rents 0 0
21 Total operation 3,162,883 3,348,609 6,511,493
Maintenance -
:J:J 511 Main supu Mnf'1 PnainPP.ring 466.820 478,787 945,607
23 542 Main of structures 307,517 396,868 704,386
24 543 Main of res,dams,waterwys 197,828 285,876 483,704
25 544 Main of electric plant 1,008,188 720,256 1,728,443
;!b �4� Maln O! misc nyur U l,)lcill L ?Jl,722 753,271 1,501,993
27 Total maintenance 2,732,075 2,635,059 5,367,134
28 Total hydraulic power generation 5,894,959 5,983,668 11, 878, 62"/
Other power generation -
Oporation -
29 546 Oper supv and engineering 149,928 131,841 281,769
30 547 Fuel 0 0
31 548 Generation expenses 55,822 74,367 130, 189
32 549 Misc other pwr gen exp 41,651 55,959 97,610
33 Total operation 247,401 262,167 509,568
JJ6
• IDAHO POWER COMPANY
li'JAGES AND SALARIES (OTHER)
For The Twelve Months Ended December 31, 2003
LINE
NO
FERC
ACCOUNT
NUMBER DESCRIPTION
Y-T-D
Actual
June
Forecast
July Through
December TOTAL
Other power generation - (continued)
Maintenance -
2
3
4
SSl
552
553
554
Main suov and engineering
Main of structures
Main of gen and elec plt
Main misc oth pwr gen plt
69,379
29,855
77,048
0
58,502
33,260
96,371
0
127,881
63, 115
173,419
5
6
Total maintenance
Total other power generation
176,282
423,683
188,132
450,300
364,414
873,983
7
8
9 557 Other expenses 551,681
0
397,259
0 u
948,940
Other power supply expenses ---
555 Purchased power
556 System cont and load disp
•
10
11
Total other power supply expenses
Total power production expenses
551,681
6,957,117
397,259
6,925,885
948,940
13,883,002
IDAHO POWER COMPANY
WAGES AND SALARIES (OTHER)
For The Twelve Months Ended December 31, 2003
LINE
NO
FERC
ACCOUNT
NUMBER DESCRIP'I'ION
Y-T-D
Actual
June
r°Ul.t::Ca.:st
July Through
::iecember TOTAL
Transmission expenses:
Operation -
560 Oper supv and engineering 1
2
3
4
5
6
7
8
561
562
563
564
565
566
567
T.n;;rl rl i sspnr.rhi no
Station expenses
Overhead line expenses
Underground line expenses
Trans of elec by others
Misc trans expenses
Rents
664,663
1.187,928
571,746
200,769
39,239
708,025
1,180,397
627,838
211, 489
0
0
74,174
0
1,372,688
2,368,325
1,199,584
412,258
0
0
113, 413
0
9 Total operation 2,664,345 2,801,923 5,466,268
Maintenance -
1l
12
13
14
��R
569
570
571
573
M�in �11nv nnn enoineerina
Main of structures
Main of station equip
Main of overhead lines
Main of nu sc trans plant
201, 162
843,706
246,125
76
221,549
97
804,074
385,144
255
422,711
97
1,647,780
631,270
331
15 Total maintenance i • 291, 069 1,411,120 2,702,188
16 Total transmission expenses 3,955,414 4, 213, 042 8,168,4�6
2,381,330
2,008,846
762, 1119
2,937,619
677,406
67,072
4,652,134
382,093
2,778,732
0
i • 244, 006
1,112,633
176,791
1,652,017
412,476
29,882
2,954,053
194,607
1,201,285
0
285,354
1,285,602
264,930
37,190
1,698,081
187,486
1,577,447
1,137,324
896,214
Oper supv and engineering
Load dispatching
SLc:1Llu11 �.x..v�use::s
Overhead line expenses
Underground line expenses
St light and sgnl sys exp
Meter expenses
Customer install expenses
Misc distribution exp
Re>nts
581
582
583
584
585
586
587
588
�R'l
Distribution expenses:
Operation -
580 17
18
19
20
21
22
23
24
25
26
27 Total operation 7,369,629 9,277,753 16,647,382
MctlULt=Ud.J.lC� -
28
29
30
31
32
33
311
35
36
590
591
592
593
594
595 �'ln
597
598
Main supv and engineering
Main of structures
Main of station equip
Main of overhead lines
Main of underground lines
Main of line transformers
Main of st loht-sqnl svs
Main of meters
Main of misc dist plant
15,219
861,883
1,479,175
354,897
380,024
86,878
632,342
44,673
34,273
0
870,222
1, 712, 321
417,681
430,727
107, 132
646,127
52,939
49,492
0
1,732,105
J,l�l,4�b
772, 578
810,752
194,010
1,278,469
97,612
37 Total maintenance 3,855,091 4,271,422 8,126,513
38 Total distribution expenses 11, 224, 720 13,549,175 24,773,895
IDAHO POWER COMPANY
WAGES AND SALARIES (OTHER}
For The Twelve Months Ended December 31, 2003
LINE
NO
FERC
ACCOUNT
NUMBER DESCRIPTION
Y-T-D
Actual
June
Forecast
July Through
December TOTAL
customer accounts expenses:
OpQor�t-inn -
1
2
3
4
5
901
902
903
904
905
Supervision
Meter reading expenses
Cust recrds - collect exp
Uncollectible accounts
Misc customer accts exp
162,075
1,601,495
3,017,364
181,062
1,685,397
1,839,778
0
611
343, 137
3,286,892
4,857,142
0
611
6 Total customer accounts expenses
Customer service and informational expenses:
()p�r.-::.t-inn -
4,780,935 3,706,848 8,487,783
7
8
9
10
11
907
908
909
910
912
Supervision
customer assistance exp
Info and instruct adv exp
Misc cust svc and inf exp
Demo and selling exp
190,187
1,410,992
0
154,330
0
J.48,058
1,575,346
0
113, 062
0
338,244
2,986,338
0
267,392
0
12
Total customer service and
informational expenses 1,755,509 1,836,466 3,591,975
13
14
15
16
17
18
19
20
21
??
23
24
25
921
922
923
924
925
926
927
928
929
930.1
930.2
931
Office supplies and exp
Au.lulu e.x..p t.i, cu1.5 £ - er
Outside services employed
Property insurance
Injuries and damages
Emp pensions and benefits
Franchise requirements
Reg commission expenses
Duolicate charoes - er
General advertising exp
Misc general expenses
Rents
13,138,933
775,978
0
0
0
62,791
0
0
0
0
0
35
0
13,818,175
803,041
0
0
0
65,937
0
0
0
0
0
115
0
26,957,108
1,579,019
0
0
0
128, 729
0
0
0
0
0
150
0
Administrative and general expenses:
Operation -
920 Admin and gen salaries
26 Total operation
Maintenance -
13,977,738 14,687,268 28,665,006
27 935 Main of general plant 385,464 316,578 '/U<!, 04:1
•
28
29
30
Total maintenance
Total administrative and
general expenses
Total electric operation
and maintenance expenses
385,464
14,363,202
43,036,896
316,578
15,003,846
45,235,264
702,042
29,367,048
88,272, 159
Jlf
,
:DAHO POWER COMPANY
WAGES AND SALARIES (THERMAL PLANTS)
For The Twelve Months Ended December 31, 2003
FERC Y-T-D Forecast
LINE ACCOUNT Actual July Tl!.c uuyl1
NO NUMBER DESCRIPTION J1..;ne December 'I'OTAL
Power production expenses:
Steam power generation -
Operation -
1 500 Operand supv engineering 298,144 278,900 577,044
l 501 Fuel 1, 126, c;47 1,104,300 2,230,847
3 502 Steam expenses 1,181,221 894,100 2,075,321
4 505 Electric expenses 381,667 381,000 762,667
5 506 Misc steam power expenses 767,477 598,600 1,366,077
6 507 Rents 0 0 0
7 Total operation 3,755,055 3,256,900 7,011,955
Maintenance -
8 510 Main supv and engineering 382,848 727,400 1,110,248
9 511 Main of structures 30,925 23,200 54,125
lU e i z Ha..i.11 of boiler pla.nt 3,0?1,fl()? .792.900 4,815,902
1l 513 Main of electric plant 887,462 404,800 i . 292, 262
12 514 Main of misc steam plant 1,742,400 2,781,900 4,524,300
13 Total maintenance 6,066,638 5,730,200 11, 796, 838
14 Total stearr. power generation 9,821,693 8,987,100 18,808,793
Hydraulic power generation -
Operation -
15 535 Oper supv and engineering 0
16 536 Water for power 0
17 537 Hydraulic expenses 0
18 538 Electric expenses 0
19 539 Misc hydro pwr gen exp 0
20 540 Rents 0
21 Total operation 0 0 0
Maintenance -
L2 �41 Mo.in �upv a.nd engineering 0
23 542 Main of structures 0
24 543 Main of res,daros,waterwys 0
25 544 !1ain of electric plant 0
26 545 Main of misc hydro plant: 0
27 Total maintenance 0 0 0
28 Total hydraulic power generation 0 ·O u
Other power generation -
O!Jt::i:a.tion -
29 546 Oper supv and engineering 0
30 547 Fuel 0
31 548 Generation expenses 0
32 549 Misc other pwr gen exp 0
33 Total operation 0 0 0
JJO
• IDAHO POWER COMPANY
WAGES AND SALARIES (THERMAL PLANTS)
For The Twelve Months Ended December 31, 2003
LINE
NO
FERC
ACCOUNT
NUMBER DESCRIPTION
Y-T-D
Actual
June
Forecast
July Through
December TOTAL
1
2
3
4
5
6
Other power generation - (continued)
Maintenance -
551 Main supv and engineering
552 Main of structures
533 Main of gen and elec plt
554 Main misc oth pwr gen plt
Total maintenance
Total other power generation
0
0
0
0
0
u
0
0
0
0
7
8
9
556
557
System cont and load disp
Other expenses
619
0
600
0
0
l,�l�
0
Other power supply expenses -
555 Purchased power
10
11
Total other power supply expenses
Total power production expenses
619
9,822,312
600
8,987,700
1,219
18,810,012
JJI
IDAHO POWER COMPANY
WAGES AND SALARIES (THERMAL PLANTS)
For The Twelve Months Ended December 31, 2003
LINE
NO
FERC
ACCOUNT
NUMBER DESCRIPTION
Y-T-D
Actual
June
F'u.Lec:ast
July Through
December TOTAL
Transmission expenses:
Operation -
560 Oper supv and engineering 1
3
4
5
6
7
8
561
562
563
564
565
566
567
Load rli�pr1rrhina
Station expenses
Overhead line expenses
Underground line expenses
Trans of elec by others
Misc trans expenses
Rents
14,866 9,100
0
0
23,966
0
0
0
0
0
9 Total operation 14,866 9,100 23,':lbb
Maintenance -
10
11
12
13
14
56Q
569
570
571
573
M;:i. in c:11rnr r1nn PnOi nP.P-rina
Main of structures
Main of station equip
Main of overhead lines
Main of misc trans plant
0 22,300
0
0
22,300
0
0
15 Total maintenance 0 22,300 22,300
16 Total transmission expenses 14,866 31,400 4b,2bb
0
0
0
0
0
0
0
0
0
0
Oper supv and engineering
Load dispatching
S Lc1Llu11 �.X.1Jt:!'1U:,e,::;
Overhead line expenses
Underground line expenses
St light and sgnl sys exp
Meter expenses
Customer install expenses
Misc distribution exp
Rents
581
582
583
584
585
586
587
588
589
Distribution expenses:
Operation -
580 17
18
19
20
21
22
23
24
25
7Fi
27 Total operation 0 0 0
Total maintenance •
28
29
30
31
32
33
14
35
36
37
590
591
592
593
594
595
596
597
598
Main supv and engineering
Main of structures
Main of station equip
Main of overhead lines
Main of underground lines
Main of line transformers
Main of st loht-sonl svs
Main of meters
Main of misc dist plant
0 0
0
0
0
u
0
0
0
0
0
0
38 Total distribution expenses 0 0 0
J),2
IDAHO POWER COMPANY
WAGES AND SALARIES (THERMAL PLANTS)
For The Twelve Months Ended December 31, 2003
LINE
NO
FERC
ACCOUNT
NUMBER DESCRIPTION
Y-T-D
Actual
June
Forecast
July Through
December TOTAL
Customer accounts expenses:
Operation
1
2
3
4
5
901
902
903
904
905
Supervision
Meter reading expenses
Cust recrds - collect exp
Uncollectible accounts
Misc customer accts exp
0
0
0
0
0
6 Total customer accounts expenses
Customer service and informational expenses:
0 0 0
Operation
7 907 Supervision 0
8 908 Customer assistance exp 0
9 909 Info and instruct adv exp 0
10 910 Misc cust SVC and inf exp 0
12. 912 Demo and selling exp 0
Total customer service and
12 informational expenses 0 0 u
13
14
15
16
17
18
19
20
21
23
24
25
922
923
924
925
926
927
928
939
930.1
930.2
931
Actm1n exp transr - er
Outside services employed
Property insurance
Injuries and damages
Emp pensions and benefits
Franchise requirements
Reg commission expenses
DuplicatQ �h�raP� - r.r
General advertising exp
Misc general expenses
Rents
0
0
0
0
0
0
0
0
0
0
0
0
0
Administrative and general expenses:
Operation -
920 Admin and gen salaries
921 Office supplies and exp
26
27
28
29
30
Total operation
Maintenance -
935 Main of general plant
Total maintenance
Total administrative and
general expenses
Total electric operation
and maintenance expenses
0
0
0
9,837,178
0
0
0
9,019,100
0
u
0
0
18,856,278
IDAHO POWER COMPANY
WAGES AND SALARIES
For The Twelve Months Ended December 31, 2003
FERC Y-T-D Forecast
LINE ACCOUNT Actual July Through
NO NUMBER DESCRIPTION June December TOTAL
Power production expenses:
Steam power generation -
Operation -
1 500 Oper and supv engineering 376,448 3G3,665 740, 114
2 501 Fuel 1,126,547 1,104,300 2,230,847
3 502 Steam expenses 1,181,221 8�4,lUU 2,075,321.
4 505 Electric expenses 381,667 381,000 762,667
5 506 Misc steam power expenses 775,966 608,494 1,384,460
6 507 Rents 0 0 0
7 Total operation 3,841,849 3,3Sl,559 7,193,408
Maintenance -
8 510 Main supv and engineering 382,848 727,400 i,110,248
9 511 Main of structures 30,925 23,200 54,125
111 :,12 Main of boiler plant 3,023,002 1,792,900 4,815,902
11 513 Main of electric plant 887,462 404,800 l,292,2t5.Z
t z 514 Main of misc steam plant 1,742,400 2,781,900 4,524,300
13 Total maintenance 6,066,638 5,730,200 11, 796, 838
14 'l'otal steam power generation 9,908,486 9,081,759 18,990,245
nydraulic power generation -
Operation -
15 535 Oper supv and engineering 1,392,464 1,466,197 2,858,660
16 536 Water for power 74,418 49,663 124,080
17 537 Hydraulic expenses 748,583 883,181 1,631,764
18 ::;30 Electric oxpgn�Qc:: 425,512 344,406 769, 918
19 539 Misc hydro pwr gen exp 521,907 605,163 1,127,070
20 540 Rents 0 0
21 Total operation 3,162,883 3,348,609 6,Sli,493
Maintenance -
77 541 Main supv and engineering 465,820 478,787 945,607
23 542 Main of structures 307,517 3%, Hbb 704,386
24 543 Main of res,dams,waterwys 197,828 285,876 483,704
25 544 Main of electric plant 1,008,188 720,256 1,728,443
26 �4i:i Main of mi�c hynrr, r,l;ant 751,722 753, 271 1,504,993
27 Total maintenance 2,732,075 2,635,059 5,367,134
28 Total hydrauJ.ic power genero.L.luu 51094,959 S,983,668 11,878,627
Other power generation -
Operation -
29 546 Oper supv and engineering 149,928 r s i . 841 281, 769
30 547 Fuel 0 0
31 548 Generation expenses 55,822 74,367 130,189
32 549 Misc other pwr gen exp 41,651 55,959 97,610
33 Total operation 247,401 262,167 509,568
J;2;
• IDAHO POWER COMPANY
WAGES AND SALARIES
For The Twelve Months Ended December 31, 2003
LINE
NO
FERC
ACCOUNT
l,J""lJMBER DESCRIPTION
Y-T-D
Actual
June
l'Orecasc:
July Through
December TOTAL
Other power generation - (continued)
Maintenance -
551
55Z
553
554
Main supv and engineering
[¥Jal11 u[ e t.a-u c t.cc-e a
Main of gen and elec plt
Main misc oth pwr gen plt
69,379
29,855
77,048
0
<;R. c;n?
33,260
96,371
0
1?7.881
63,115
173,419
5
6
Total maintenance
Total other power generation
Other power supply expenses -
llb,L8L
423,683
155, l.32
450,300 873,983
7
l:l
9
555
556
557
Purchased power
5y::sLt'!ll 1..,.:vul. and loo.cl diop
Other expenses
619
551,681
0
1,nn
397,259
0
1.219
9118,940
10
11
Total other power supply expenses
Total power production expenses
552,301
16,779,429
397,859
15, 913, 585
950, c.60
32, 693, 01,1
IDAHO POWER COMPANY
WAGES Ai'ID SALARIES
For The Twelve Months Ended Dece!l'ber 31, 2003
LINE
NO
FF:RC:
ACCOUNT
NUMBER DESCRIPTION
Y-T-D
Actual
June
Forecast
July Through
December TOTAL
1,372,688
2,368,325
1,223,550
412,258
0
0
113,413
0
708,025
1,180,397
GJG,9)0
211,489
0
0
74,174
0
39,239
664,663
1,187,928
586,612
200,769
Oper supv and engineering
Load dispatching 561
562 Station expenses
563 Overhead line expenses
564 Underground line expenses
565 Trans of elec by others
566 Misc trans expenses
567 Rents
Transmission expenses:
Operation -
560 1
2
3
4
5
6
7
8
Total operation. ?.fi7Q.211 2. 811. 023 5,490,234
Maintenance -
10
11
12
l.3
14
568
569
570
571
573
Main supv and engineering
Main ot structures
Main of station equip
Main of overhead lines
Main of misc trans plant
201,162
843,706
246,125
76
221,549
97
326,374
385,144
255
422,711
!)'7
1,670,080
631,270
33"�
15 Total maintenance 1,291,069 1,433,420 2,724,488
Tutal tran�mio�ion c,�cncoc ,.Q7fL?RO 4.2'14.442 8,214,723
2,381,330
2,008,846
762,148
2,937,bl':!
677,406
67,072
4,652,134
382,093
2,778,732
0
1,244,006
1,112,633
476,794
1,652,017
412,476
29,882
2,954,053
194,607
1,201,285
0
1,137,324
896, 214
285,354
1,285,602
264,930
37,190
1,698,081
187,486
1,577,447
Meter expenses
Customer install expenses
Misc distribution exp
Rents
Oper supv and engineering
Load dispatching
Station expenses
Overhead line expenses
Underground line expenses
St light and sgnl sys exp
584
585
586
587
588
589
581
582
583
Distribution expenses:
Operation -
580 17
18
19
20
21
22
23
24
25
26
27 Total operation 7,369,629 9,277,753 16,647,382
Maintenance -
28
29
30
31
32
33
34
35
36
590
591
592
593
594
595
596
597
598
Main supv and engineering
Main of structures
Main of station equip
Main of OVQrhQad l]nQ�
Main of underground lines
Main of line transformers
Main of st lght-sgnl sys
Main ot meters
Main of misc dist plant
15,219
861,883
1.479.175
354,897
380,024
86,878
632,)42
44,673
34,273 a
870,222
�.712,321
417,681
430, 727
1.07,132
6�6,127
52,939
4'.I, 4�Z
0
1,732,105
3,191,496
772, 578
810,752
194,010
l,:l7B,1!69
97,612
37 Total maintenance 3,855,091 4,271,422 8,126,513
38 Total distribution expenses 11,224,720 13,549,175 24,773,895
IDAHO POWER COMPANY
WAGES AND SALARIES
For 1'he Twelve Months Ended December 31, 2003
LINE
NO
FERC
ACCOUNT
NUl"iliEK DESCRIPTION
Y-T-D
Actual
June
Forecast
July Through
December TOTAL
343,1)7
3,286,892
4,857,142
0 s i i
161,062
1,685,397
1,839,778
611
lb2,U/:,
1,601,495
3,017,364
Misc customer accts exp
Supervision
Meter reading expenses
Cust recrds - collect exp
Uncollectible accounts
902
903
904
905
Customer accounts expenses:
Operation -
901
4
5
2
6 ToLal customer accounts expenses 4,780,935 3,706,848 8,487,783
C;.istomer service and informational expenses:
Operacion
7
8
9
10
11
907
908
909
910
912
Supervision
Customer assistance exp
Info and ins t ruc t adv exp
Misc cust svc and inf exp
Demo and selling exp
BU,ll:ll
1,410,992
0
154,330
0
l\lB,U:55
1,575,346
0
113, 062
0
3.)6, 24."1:
2,986,338
0
267,392
0
12
Total customer service and
intormac1ona1 exJJeu:se:s 1,755,509 1.ll36,4hh 1,591.975
26,957,108
1,579,019
0
0
0
128, 729
0
0
0
0
0
150
0
13,818,175
803,041
0
0
0
65,937
0
0
0
0
0
115
0
13,138,933
775,978
0
0
0
62,791
0
0
0
0
u
35
0 Rents
Admin and gen salaries
Office supplies and exp
Arlmin exo transf - er
Outside services employed
Property insurance
Injuries and damages
Emp pensions and benefits
Franchise requirements
Reg commission expenses
Duplicate charges - er
General advertising exp
Mi.sc general expenses
921
922
923
924
925
926
927
928
929
930.1
930.2
931
Administrative and general expenses:
Operation -
920 13
14
15
16
17
18
19
20
21
22
23
24
25
26 Total operation 13,977,738 14,687,268 28,665,006
Maintenance -
935 1'1d.l!1 v[ general plant 395,464 ,, f;, "i78 702,042
28 Total maintenance 385,464 316,578 702,042
29
Total administrative and
general expenses 14,363,202 15,003,846 29,367,048
30
Total electric operation
and maintenance expenses 52,874,074 54,254,364 107,128,438
JJ?
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73/
IDAHO POWER COMPANY
Development of 2003 Test Year Energy Allocator
2003 DATA w/ NEW LOSS FACTORS
Energ� at Generation L�vfl - NQrmalized 2003 kWh_CUST-LVL MWh_CUST-LVL MWh_GEN·LVL
Idaho
130· 2 US Department of Energy (INEEL) J.5% 203,084, 146 203,084 210,192 "
I09T 2 Large General Service 3.5% 5,084,610 5,085 5,466•
1191 2 Large Power Service ··' 3.5% 55,348,183 55,348 61,261 r!Bt ,!•
r.!lT , lrrig�ion Service 3.5%
126· 4 Micron Technology, Inc. 5.0% 636,967,670 636,968 668,816
129. 4 J.R.Simplol Company 5.0% 186,684,665 186,685 196,019 �-
109P 5 Large General Service 7.4% 341,966, 139 341,966 367,369 ;ji
119P 5 Large Power Service 7.4% 1,914,555,523 1,914,556 2,052,702 ;.
101. 6 Residential Service 10.9% 4, 141,393,426 4,141,393 4,596,153 i 107· 6 Small General Service 10.9% 265,335,667 265,336 294,551,'
1095 6 Large General Service 10.9% 2,667,376,237 2,667,376 2,960,874 ,;
11!i. 6 Dusk to Dawn Liohtina 10.9% 5,872,586 5,873 6,513 ,;
1195 6 Large Power Service 10.9% 8,920,531 8,921 9.443
124$ 6 Irrigation Service 10.9% 1,538,694,958 1,538,695 1,706,413:
1255 6 lnigation Time-of-Use Pilot Program 10.9% 82,235,973 82,236 91,200
132· 6 Shielded Street Lighting Service (Ketchum) 109% 33,297 33 17.�: j; 140· 6 Unmetered General Service 10.9% 16,054,942 16,055
141· 6 Municipal Street Lighting Service 10.9% 17,845,445 17,845 19,791
142· 6 Traffic Control Signal Lighting Service 10.9% 9,384,218 9,384 10,407 ,i.
Total Idaho Retail 12,096,838,216 12,096,839 13,275,012 r
!10 ,gl
Oregon
019T 2 Large Power Service 3.5% 99,706,829 99,707 106,796
0000 C L�rgo Co"or�I i;::orvit-OI 7.4% 117,919,341 17,575 18,891
019P 5 Large Power Service 7.4% 153,893,332 153,893 165,069
001· 6 Residential Service 10.9% 187,125,456 187,125 207,710 cs
007· 6 Small General Service 10,9% 15,215,249 15,2i5 16,896 f;
ocss 6 Large General Service 10.9% 17,575,015 117,919 130,945
015- 6 Dusk to Dawn Residential Lighting 10.9% 445,096 445 494
024$ 6 lnigation Service '&f 10.9% 43,985,637 43,986 48,780 &
040· 6 Unmetered General Service � 10.9% 72,856 73 81,
OH. t; M11nl("ir.:11I �tr11M I iohtino �ll!rvir:A 10.9% 869,195 869 964' •
042· 6 Traffic Control Signal Lighting Service 10.9% 46,894 47 52·
Total Oregon Retail 636,854,900 636,854 696,678
FERC '!o ;,;
FCOL 1 City of Colton 3.5% 26,280,000 26,280 27.200 ·
FRAF 4 Raft River Rural Electric Cooperative 5,0% 53,873,709 53,873 56,567
FWEI 4 City of Weiser 125kV 5.0% 49,636,738 49,637 52,119
Total 129.790.447 129,791 135,886 :!P'
4
Total " 1.096715 12,863,483,563 12,863,484 14,107,576
NPSC Model Resource Dispatch ' 14,113,513 �
INPUTS TO "NORMALIZED" TAB:
IDAHO: 18' ->r 2 Major Transmission 3.5% 203,084,146 263,517 276,919
4 Distribution S1atlons 5.0% 823,652,335 823,653 864,835 ,''f; 5 Distribution Primary 12.5-34.SkV 7.4% 2,256,521,662 2,256,522 2,420,071 <
6 Distribution Secondary j� 109% 8,753,147,280 8,753,147 9,713,187
To1al Idaho Retail ,! 12,036,405,423 12,096,839 13,275012{'
OREGON:
2 Major Transmission 3.5% 99,706,829 99,707 106,796
5 Distribution Primary 7.4% 271,812,673 171,468 183,960
6 Distribution Secondary 109% 265,335,398 365,679 405,922
Total Oregon Re1ail oJM,4,900 030,654 090,070';, j
SALES FOR RESALE:
1 i.;ny or conon L.1\.K\'jl 3.5% 26,200,000 2G,2SO 27,:100
4 Raft River Rural Electric Cooperative ('. 5.0% 53,873,709 53,873 56,567;
4 City of Weiser 12.SkV. J:: 5.0% 49,636,738 49,637 52,119 ' 129,790,447 129,791 135,886 �
12,803,050,770 12,863,484 14,107,576
pao: Alloc_kWh_2003.NkWhGEN03.8/1212003.2:07 PM. from P. Werner.
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•
Re:
To:
System Loss Coefficients
Maggie Brilz
Barr Smith
Paul Werner
Terry Mayer
(Intro -Compnn )' Correspondence)
From: Kip Sikes
The most recent System Loss Study results have been incorporated into the Average System
Loss Coefficients, summarized in the table below. The multi-year average is utilized to reduce
variations which may be caused by unusual conditions in any individual year.
Average System Loss Coefficients
Sy::;lem Level
Transmission
Distribution Station
Distribution Primary
Distribution Secondary*
System Level
Transmission
Distribution Station
Distribution Primary
Distribution Secondary*
Typical Peak
Demand
Coefficients
1.055
1.065
1.100
1.130
Annual Energy
Coefficients
1.035
1.050
1.074
1.109
•
* Distribution Secondary includes dlstribuuon line u ausformcrs
Should you have any questions, please call - 2459.
c: R D Schellberg
H C Durick
•
Re:
To:
System Loss Coefficients
Maggie Brilz
Barr Smith
Paul Werner
Terry Mayer
(lntra-Cornpanv Correspondence)
Date: 29 May 2003
From: Kip Sikes
The most recent System Loss Study results have been incorporated into the Average System
Loss Coefficients, summarized in the table below. The multi-year average is utilized to reduce
variations which may be caused by unusual conditions in any individual year.
Average System Loss Coefficients
System Level
Transmission
Distribution Station
Distribution Primary
Distribution Secondary*
System Level
Transmission
Distribution Station
Distribution rrimary
Distribution Secondary*
Typical Peak
Demand
Coefficients
1.055
1.065
1.100
1.130
Annual Energy
Coefficients
1.041
1.051
1.073
1.107
55%>
tG,S�
/0,0 /� ;g.0,$
'/,/$
S, If!,
7,3,?,·
/t;J, ]> Js
•
* Distribution Secondary includes distribution line transformers
Should you have uny questions, please call - 2459.
c: R D Schellberg
H C Durick
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• Average System Loss Coefficients
Peak Demand
Sl£'.stem Level Coefficients Loss Factors
Transmission 1.055 5.21%
Distribution Station 1.065 6.10%
Distribution Primary 1.100 9.09%
Distribution Secondarv 1.130 11.50%
Annual Energ�
Sl£'.stem Level Coefficients Loss Factors
Transmission 1.041 3.94%
Distribution Station 1.051 4.85%
Distribution Primary 1.073 0.00%
Distribution Secondary 1.107 9.67%
•
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2002. Energ� at Generation Level (kWhl Total MWH
Idaho
130- 2 US OQp;utm�nt of F.nProy (INFFI ) 4.2% 209.913.504 209.914
109T 3 Large General Service 5.6% 5,294,041 5,294
119T 3 Large Power Service 5.6% 74,365,449 74,365
124T 3 Irrigation Service 5.6% 294,244 294
126- 4 Micron Technology, Inc. 5.3% 638,938,997 638,939
128- 4 FMC Corporation 5.3% 12,060,799 12,061
129- 4 J.R.Simplot Company 5.3% 237,366,168 237,366
109P 5 Large General Service 7.7% 365,843,816 365,844
119P 5 Large Power Service 7.7% 1,978,167,379 1,978,167
101- 6 Rocidonti2I Sorvico 10.8% 4.689.534.759 4.689.535
103- 6 Master-Metered Mobile Home Park 10.8% 3,625.396 3,625
107- 6 Small General Service 10.8% 301,448. 717 301,449
109S 6 Large General Service 10.8% 2.930,510,070 2,930,510
110- 6 Large Power Winter Service 10.8% 84,895 85
115- 6 Dusk to Dawn Residential Lighting 10.8% 2,510,923 2,511
116- 6 Dusk to Dawn Commercial Lighting 10.8% 3,937,282 3,937
119S 6 Large Power Service 10.8% 9,790,145 9,790
122- 6 Limited Use Service 10.8% 788 1
12�S G lrrig::ition Sgrvico 10.8% 1.871.006.458 1.871.006
125S 6 Irrigation Time-of-Use Pilot Program 10.8% 97,266,040 97,266
132- 6 Shielded Street Lighting Service (Ketchum) 10.8% 33.554 34
140- 6 Unmetered General Service 10.8% 17,910.800 17,911
141- 6 Municipal Street Lighting Service 10.8% 19.365,726 19,366
142- 6 Traffic Control Signal Lighting Service 10.8% 10,289,315 10,289
Total Idaho Retail 13,479,559,262 13,479,559
1 Power Supply Transmission
:2 M::::ijor Tranernleelcn 1�RkV 4.2% 209.913.504 209.914
3 Suotransrrusslon 46& 69kV 5.6% 79,953,734 79,954
4 Distribution Stations 13.2kV 5.3% 888,365,964 888,366
5 Distribution Primary 12.5-34.5kV 7.7% 2,344,011, 194 2,344,011
6 Distribution Secondary 10.8% 9,957,314,867 9,957,315
Total Idaho Retail l.j,4/�,oo�.LOL 13,479,009
09 Large General Service 3,301,647 ,926 3,301,648
19 Large Power Service 2,062,322,973 2,062,323
24 Irrigation Service 1,871,300, 701 1,871,301
Oregon
019T 2 Large Power Service 4.2% 95,996,528 95,997
009P 5 Large General Service 7.7% 19,017,025 19.017
019P 5 Large Power Service /. /v/o 'l:l�,l.l4,'174 103',724
001- 6 Residential Service 10.8% 211,309,439 211,309
007- 6 Small General Service 10.8% 17,262,948 17,263 ooos 6 Large General Service 10.8% 131,522,371 131,522
015- 6 Dusk to Dawn Residential Lighting 10.8% 203,985 204
016- 6 Dusk to Dawn Commercial Lighting 10.8% 274,303 274
024S 6 Irrigation Service 10.8% 48,290,594 48,291
040- 6 Unmetered General Service 10.8% 102,466 102
041- 6 Municipal Street Lighting Service 10.8% 962,241 962
042- 6 Traffic Control Signal Lighting Service 1UJ:S'1o 01,401'1 01
Total Oregon Retail 684,717,543 684,718
1 Power Supply Transmission
2 Major Transmission 138kV 4.2% 95,996,528 95,997
3 Subtransmission
4 Distribution Stations
5 Distribution Primary 12.5-34.5kV 7.7% 178,741,199 178,741
6 Distribution Secondary 10.8% 409,979,817 409,980
Total uregon Keta1t 0!!4, 717.:l43 004,716
09 Large General Service 150,539,396 150,539
19 Large Power Service 255,720,702 255,721 ?4 lrrio::1tion SP.rvi('.A 48.290.594 48.291
FERC
FCOL 1 City of Colton 230kV 3.1% 25,706,954 25,707
FUAM 1 Utah Association Municipal Power System 345kV 3.1% 412,281,435 412,281 �Wt;I 1 <.;1ty 01 vvasnington .34::lKV 3:1% 29,063,014 29,064
FOTE 3 Oregon Trail Electric Cooperative 69kV 5.6%
FRAF 4 Rafi River Rural Electric Cooperative 5.3% 57,902,461 57,902
FWEI 4 City of Weiser 12.5kV 5.3% 54,012,419 54,012
Total 579.486. 783 579,487
Total Idaho Retail 13,479,559,262 13,479,559
Total Oregon Retail 684,717,543 684,718
Total Retail 14, 164,276,806 14,164,277
City of Weiser 54,012,419 54,012
Total Retail Including Weiser 14,218,289,224 14,218,289
6/11/2003 Alloc_kWh_2002 AkWhGen02 Page 1 J63
• An IDACORP company
Memorandum
To: Phil Obenchain
From: Barr Smith
Re: 2003 Normalized Energy
Date: June 23, 2003
Attached are tables of normalized sales (in MWh) for the period January 2003 to December 2003. I have
also forwarded an electronic copy (SL_OUT_N03RC_Ol.xls).
If you have any questions, please call me on extension 2924.
attachments
c: JP Prescott
K E Bokenkamp
D L Sikes
J RGale
MHBrilz
GWSaid
TA Noll
JC Bowman
PA Werner
SD Sparks
T J Brewer
W:IWord\Nonnalized MWh Rcports\Weather Normalized Sales 2003 - Sales and Load Run.doc
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1j 77 /:
•
Date:
To:
From:
Subject:
June 19, 2003
Jeannette Bowman
Barr Smith
2003 Normalized Energy
..
•
The attached tables represent normalized sales in MWh by rate, jurisdiction, and month for the period
January 2003 to December 2003. Normalized sales are typically weather-adjusted sales when appropriate.
However, other adjustments are made to reflect more "normal" energy consumption levels. These
adjustments are described below.
ENERGY NORMALIZATION
Residential, Commercial, Industrial, and Irrigation Normalization
Normalized energy over the period January 2003 through May 2003 was set to weather adjusted energy in
the residential, commercial, and irrigation classes. In the industrial class normalized energy over the period
January 2003 through May 2003 was set to actual energy. Normalized energy over the period June 2003
through December 2003 was set to the prior June 2002 through December 2002 normalized energy
multiplied by escalation or growth factors. The escalation factors were calculated by taking the percent
change in year-to-date (January through May 2003) weather-adjusted sales as compared to the same period
in 2002. Normalized June 2002 through December 2002 residential energy was increased by 1.0%,
commercial by 1.714%, industrial by 3.524%, and irrigation by 0.0% to arrive at the June 2003 through
December 2003 forecast of normalized energy.
Normalization of Simplot Fertilizer Facility
Normalized energy for Simplot Fertilizer was set to January 2003 through May 2003 actual energy and June
2003 through December 2003 forecast energy. A new forecast was prepared that more accurately portrays
"normal" operating conditions at the facility. This is a special circumstance associated with the closing of
Simplot's ammonia processing facility in late August of 2002.
Normalization of Micron Technology
Normalized energy for Micron Technology was set to January 2003 through May 2003 actual energy and
June 2003 through December 2003 forecast energy. A new Micron Technology energy forecast was
completed in June 2003 and was based on Micron's latest short-term load projections.
Normalization of INEEL
Normalized energy for the INEEL was set to January 2003 through May 2003 actual energy and June 2003
through December 2003 forecast energy. The forecast energy figures were taken directly from a power
forecast received from the CNEEL on June 2, 2003.
• Normalization of City of Weiser
Normalized energy for the City of Weiser was set to January 2003 through May 2003 weather adjusted
t:11ergy and June 2003 through December 2003 forecast energy. A new City of Weiser energy forecast was
completed in June 2003 and was based on the most recent economic forecast.
Normalization of Raft River Rural Electric Cooperative, Inc.
Normalized energy for Raft River Rural Electric Cooperative, Inc. was set to January 2003 through May
2003 weather adjusted energy and June 2003 through December 2003 forecast energy. A new Raft River
energy forecast was completed in June 2003.
Normalization of Astaris
The Astaris special contract figures are normalized at zero.
Normalization of Firm Off-System Customers
Normalized energy for UAMPS was set to zero since lTAMPS'i;; contract will expire on December 3 L 2003.
Normalized energy for the City of Colton was set to Colton's contract demand of 3 MW times the number
of hours within each month.
Normalization of Rate 41- Municipal Street Lighting Service - Idaho Jurisdiction
The energy booked in August, September, and October of 2002 was averaged. The average figure was used
in place of booked in each of the respective months to decrease the sales variability and to more accurately
reflect more "normal" sales conditions.
Nnrm1di71dinn of Rate 41 - Municipal Street Liebtine Service - Oregon Jurisdiction
The energy booked in October and November of2002 was averaged. The average figure was used in place
of booked in each of the respective months to decrease the sales variability and to more accurately reflect
more "normal" sales conditions.
ADJUSTMENTS TO ACTUAL ENERGY
Commercial/Industrial Billing Adjustments
The actual sales tables reflect several adjustments that correct billing errors and billing adjustments. These
corrections affect actual sales in Rate 9 (primary, secondary, and transmission service) and Rate 19
(primary, secondary, and transmission service). A description of these billing corrections is attached, as
well as tables showing the corrected amounts for each month. These corrected actual sales represent
normalized sales to Rate 9 and Rate 19.
Rate 3 - Master-Metered Mobile Home Parks - Residential Service - Idaho Jurisdiction
These customers were over billed in June 2002 (16,200 kWh). The correction was made i11 July 2002
(16,200 kWh).
Rate 25 Secondary Service - Time-of-use Pilot Program - Irrigation Service - Idaho Jurisdiction
These customers were over billed in October 2002 (3,360 kWh). The correction was made in January 2003
(3,360 kWh) resulting in a negative booked energy figure.
Prairie Power Jurisdiction Energy Combined with Idaho Jurisdiction Energy
All historical energy associated with the Prairie Power jurisdiction has been combined into the appropriate
Idaho jurisdiction rate schedules. However, prior to combining figures a number of adjustments were made.
These adjustments are discussed below.
• Rate 1 - PA Adjustments - Prairie Jurisdiction
These customers were under billed in February 2002 (219 kWh), March 2002 (226 kWh), April 2002
(46 kWh), May 2002 (805 kWh), June 2002 (2,262 kWh), and July 2002 (40,269 kWh). The correction was
made in August 2002 (43,827 kWh).
Rate 10- PLW Adjustments - Prairie Jurisdiction
These customers were over billed in March 2002 (2,060 kWh) and April 2002 (1,680 kWh), and were under
billed in May 2002 (880 kWh). The correction was made in June 2002 (:l,860 kWh).
Rate 15 - OL Adjustments - Prairie Jurisdiction
These customers were under billed in July 2002 (12 kWh). The correction was made in August 2002
(l2 kWh).
Rate 22 - PLU Adjustments - Prairie Jurisdiction
These customers were over billed in May 2002 (600 kWh) and June 2002 (16 kWh). The correction was
made in July 2002 (616 kWh).
Definition of Rates
The definition of rates represented by the tables differs from the Monthly Revenue Analysis (MRA) as
follows: Rate 15 in the tables is equivalent to MRA Rates 15, 16, and 17 in revenue class 1. Rate 16 in the
tables is equivalent to MRA Rates 15, 16, and 17 in revenue classes 2, 3, and 4.
If you have any questions or require additional information, please let me know (ext. 2924).
Attachments
cc: J P Prescott
KE Bokenkamp
HCDurick
J RGale
D L Sikes
M Brilz
TA Noll
LD Smith
P A Obenchain
PA Werner
MJMowrey
SL Wright
T J Brewer
-
W:\Word\Rate Depamnent\JC Bowman-2003 Weather Normalized Energy Memo.doc
•
•
•
Normalized Megawatthour by Rate and Jurisdiction
- Normalized Megawatthour by Rate and Jurisdiction
Jurisdiction
Month Rate /PUC OPUC NPSC FERC Prairie Power Total
January 2003 R.RESI 493, 125.831 22,944.055 0.000 0.000 0.000 516,069.886
Fohruary znn3 R.RESI 438.961.084 20.873.380 0.000 0.000 0.000 459,834.464
March 2003 R.RESI 391,280.695 18,441.957 0.000 0.000 0.000 409,722.652
April 2003 R.RESI 346,370.369 16,407.299 0.000 0.000 0.000 362,777.668
May2003 R.RESI 281,804.557 11,543.258 0.000 0.000 0.000 293,347.8[5
June 2003 R.RESI 266,559.534 11,413.263 0.000 0.000 0.000 277,972.797
July 2003 R.RESI 293,596.032 13,061.303 0.000 0.000 0.000 306,657.335
August 2003 R.RESI 340,329.912 15,535.968 0.000 0.000 0.000 355,865.880
September 2003 R.RCSI 301,871.058 13,697.910 0.000 0.000 0000 , I s. 'inR. 96R
October 2003 R.RESl 257,449.413 10,679.693 0.000 0.000 0.000 268,129.106
November 2003 R.RESI 316,432.567 13,538.351 0.000 0.000 0.000 329,970.918
December 2003 R.RESI 413,612.374 18,989.019 0.000 0.000 0.000 432,601.393
Total 4,141,393.426 187,125.456 0.000 0.000 0.000 4,328,518.882
January 2003 R.03 0.000 0.000 0.000 0.000 0.000 0.000
February 2003 R.03 u.uuu 0.000 0.000 0.000 0.000 0.000
March2003 R.03 0.000 0.000 0.000 0.000 0.000 0.000
April 2003 R.03 0.000 0.000 0.000 0.000 0.000 0.000
May2003 R.OJ 0.000 0.000 0 000 0000 0.000 0.000
June 2003 R.03 0.000 0.000 0.000 0.000 0.000 0.000
July 2003 R.03 0.000 0.000 0.000 0.000 0.000 0.000
August 2003 R.03 0.000 0.000 0.000 0.000 0.000 0.000
September 2003 R.03 0.000 0.000 0.000 0.000 0.000 U.000
October 2003 R.03 0.000 0.000 0.000 0.000 0.000 0.000
November 2003 R.03 0.000 0.000 0.000 0.000 0.000 0.000
-ecember Z003 R.03 0.000 0.000 0.000 0.000 0.000 0.000
Total 0.000 0.000 0.000 0.000 0.000 0.000
January 2003 R.15 188.437 15.398 0.000 0.000 0.000 203.835
February 2003 R.15 189.562 15.443 0.000 0.000 0.000 205.005
March 2003 R.15 189.209 15.359 0.000 0.000 0.000 204.568
April 2003 R.15 187.072 18.414 0.000 0.000 0.000 205.486
May2003 R.15 190.324 14.861 0.000 U.000 0.000 20,.1s,
June 2003 R.15 190.189 15.512 0.000 0.000 0.000 205.701
July 2003 R.15 191.199 15.570 0.000 0.000 0.000 206.769
August 2003 R.15 190.224 15.485 0.000 0.000 0.000 205.709
September 2003 R.15 189.314 15.626 0.000 0.000 0.000 204.940
October 2003 R.15 188.961 15.644 0.000 0.000 0.000 204.605
November 2003 R.15 194.043 15.574 0.000 0.000 0.000 209.617
December 2003 R.15 191.457 16.149 0.000 0.000 0.000 207.606
Total 2,279.991 189.035 0.000 0.000 0.000 2,469.026
January 2003 R.07 25,04Y.37o 1,)65.990 0.000 0.000 0.000 26,61.5.366
February 2003 R.07 24,804.210 1,547.661 0.000 0.000 0.000 26,351.871
March 2003 R.07 23,464.859 1,408.517 0.000 0.000 0.000 24,873.376
April 2003 R.07 21,,!57.78'1 1,369.351 0.000 0000 0.000 22.827.135
May2003 R.07 19,443.478 946.132 0.000 0.000 0.000 20,389.610
June 2003 R.07 20,269.654 1,150.208 0.000 0.000 0.000 21,419.862
July 2003 R.07 23,322.750 1,125.695 0.000 0.000 0.000 24,448.445
August 2003 R.07 25, 118.918 1,424.548 0.000 0.000 0.000 26,543.466
September 2003 R.07 18,733.166 912.950 0.000 0.000 0.000 19,646.116
� October 2003 R.07 18,711.564 1,058.490 0.000 0.000 0.000 19,770.054
ovember 2003 R.07 21,344.753 1,230.120 0.000 0.000 0.000 22,574.873
December 2003 R.07 23,615.155 1,475.587 0.000 0.000 0.000 25,090.742
Total 265,335.667 15,215.249 0.000 0.000 0.000 280,550.916
/)77
Normalized Megawatthour by Rate and Jurisdiction
Jurisdiction
Month Rate /PUC OPUC NPSC FERC Prairie Power Total
January 2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
February 2003 R.09 0000 0.000 0.000 0.000 0.000 0.000
March 2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
April 2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
May2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
June 2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
July2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
August 2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
September 2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
October 2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
November 2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
December 2003 R.09 0.000 0.000 0.000 0.000 0.000 0.000
Total 0.000 0.000 0.000 0.000 0.000 0.000
January 2003 R.09S 242, 751.588 12,004.364 0.000 0.000 0.000 254,755.952
February 2003 R.09S 227,438.756 11,110.973 U.UUU 0.000 0.000 238,J49.729
March2003 R.09S 219,441.228 10,046.549 0.000 0.000 0.000 229,487.777
April 2003 R.09S 212,108.449 9,095.308 0.000 0.000 0.000 221,203.757
Muy2003 R.093 I ?S,O 14.359 7,168.886 0.000 0.000 noon 102.on 245
June 2003 R.09S 207,385.894 7,987.782 0.000 0.000 0.000 215,373.676
July 2003 R.09S 224,885.884 8,651.157 0.000 0.000 0.000 233,537.041
August 2003 R.09S 242,958.728 9,871.083 0.000 0.000 0.000 252,829.811
September 2003 R.09S 239,642.396 9,745.993 0.000 0.000 0.000 249,388.389
October 2003 R.09S 213,814.788 8,912.864 0.000 0.000 0.000 222,727.652
November 2003 R.09S 216,009.272 11,414.067 0.000 0.000 0.000 227,423.339
-ecember 2UU3 K.U'J� Z2:l,924.89J 11,910.31' 0.000 0.000 0.000 237,835.210
Total 2,667 ,3 76.23 7 117,919.341 0.000 0.000 0.000 2, 785,295.578
January 2003 R.09P 27,900.550 1,816.934 0.000 0.000 0.000 29,717.484
February 2003 R.09P 27,264.877 1,807.676 0.000 0.000 0.000 29,072.553
March2003 R.09P 25,627.295 1,707.741 0.000 0.000 0.000 27,335.036
April 2003 R.09P 25,929.644 1,442.930 0.000 0.000 0.000 27,372.574
May2003 R.09P 25,303.601 1,155.214 0.000 0.000 O.UUU Lo,4:>8.81:1
June 2003 R.09P 29,178.192 1,418.075 0.000 0.000 0.000 30,596.267
July2003 R.09P 31,731.827 1,143.831 0.000 0.000 0.000 32,875.658
August 2003 R.09P 32,884.929 1, 183.778 0.000 0.000 0.000 34,068.707
September 2003 R.09P 30,900.926 1,109.061 0.000 0.000 0.000 32,009.987
October 2003 R.09P 29,511.744 1,358.244 0.000 0.000 0.000 30,869.988
November Jnni R.09P 28.194.245 1,579.343 0.000 0.000 0.000 29,773.588
December 2003 R.09P 27,538.309 1,852.188 0.000 0.000 0.000 29,390.497
Total 341,966.139 17,575.015 0.000 0.000 0.000 359,541.154
January 2003 R.09T 441.366 0.000 u.uuu 0.000 0.000 441.366
February 2003 R.09T 521.447 0.000 0.000 0.000 0.000 521.447
March2003 R.09T 448.820 0.000 0.000 0.000 0.000 448.820
April 2003 R.09T 373.567 0.000 0.000 0000 0 000 1TU67
May2003 R.09T 339.764 0.000 0.000 0.000 0.000 339.764
June2003 R.09T 393.174 0.000 0.000 0.000 0.000 393.174
.lu(v2003 R.09T 404.276 0.000 0.000 0.000 0.000 404.276
August 2003 R.09T 465.837 0.000 0.000 0.000 0.000 465.837
September 2003 R.09T 412.699 0.000 0.000 0.000 0.000 412.699
- October 2003 R.09T 430.567 0.000 0.000 0.000 0.000 430.567
ovember 2003 R.09T 429.586 0.000 0.000 0.000 0.000 429.586
December 2003 R.09T 423.507 0.000 0.000 0.000 0.000 423.507
Total 5,084.610 0.000 0.000 0.000 0.000 5,084.610
J)&
· Normalized Megawatthour by Rate and Jurisdiction
Jurisdiction
Month Rate /PUC OPUC NPSC FERC Prairie Power Total
January 2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
February 2n()3 R.10 0.000 0.000 0.000 0.000 0.000 0.000
March 2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
April 2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
May2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
June 2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
July 2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
August 2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
September 2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
October 2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
November 2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
December 2003 R.10 0.000 0.000 0.000 0.000 0.000 0.000
Total 0.000 0.000 0.000 0.000 0.000 0.000
January 2003 R.16 297.492 21.097 0.000 0.000 0.000 318.589
February 2003 R.16 2'J7.55lS 21.0j/ u.uuu 0.000 0.000 3UU95
March2003 R.16 296.461 20.998 0.000 0.000 0.000 317.459
April 2003 R.16 296.548 24.565 0.000 0.000 0.000 321.113
.May 2003 R.16 297.765 20.77'.l 0.000 0.000 0.000 J 18.SJ7
June 2003 R.16 297.899 20.730 0.000 0.000 0.000 318.629
July 2003 R.16 300.700 20.504 0.000 0.000 0.000 321.204
August 2003 R.16 301.082 21.557 0.000 0.000 0.000 322.639
Sep/ember 2003 R.16 299.956 21.079 0.000 0.000 0.000 321.035
October 2003 R.16 299.267 19.907 0.000 0.000 0.000 319.174
November 2003 R.16 304.319 22.582 0.000 0.000 0.000 326.901
9ecember 2005 R.16 303.548 21.233 0.000 0.000 0.000 324. 781
Total 3,592.595 256.061 0.000 0.000 0.000 3,848.656
January 2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
February 2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
March2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
April 2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
May2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
June 2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
July2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
August 2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
September 2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
October 2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
November 2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
December 2003 R.22 0.000 0.000 0.000 0.000 0.000 0.000
Total 0.000 0.000 0.000 0.000 0.000 0.000
January 2003 R.23 0.000 u.uuu u.uuu u.uuu u.uuo 0.000
February 2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
March 2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
April 2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
May2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
June 2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
July2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
August 2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
September 2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
• October 2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
ovember 2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
December 2003 R.23 0.000 0.000 0.000 0.000 0.000 0.000
Total 0.000 0.000 0.000 0.000 0.000 0.000
J?1
Normalized Megawatthour by Rate and Jurisdiction
Jurisdiction
Month Rate IPUC OPUC NPSC FERC Prairie Power Total
January 2003 R.32 2.753 0.000 0.000 0.000 0.000 2.753
Februury 200] R.J2 2.753 0.000 0.000 0.000 0.000 2.753
March2003 R.32 2.743 0.000 0.000 0.000 0.000 2.743
April 2003 R.32 2.724 0.000 0.000 0.000 0.000 2.724
May2003 R.32 2.724 0.000 0.000 0.000 0.000 2.724
June 2003 R.32 2.800 0.000 0.000 0.000 0.000 2.800
July 2003 R.32 2.800 0.000 0.000 0.000 0.000 2.800
August 2003 R.32 2.800 0.000 0.000 0.000 0.000 2.800
September 2003 R.32 l.800 0.000 0.000 0.000 0.000 2.800
October 2003 R.32 2.800 0.000 0.000 0.000 0.000 2.800
November 2003 R.32 2.800 0.000 0.000 0.000 0.000 2.800
December 2003 R.32 2.800 0.000 0.000 0.000 0.000 2.800
Total 33.297 0.000 0.000 0.000 0.000 33.297
January 2003 R.40 1,329.462 7.028 0.000 0.000 0.000 1,336.490
February 2003 R.40 1,408.997 3.247 0.000 0.000 0.000 1,412.244
March2003 R.40 1,322.063 2.772 0.000 0.000 0.000 1,324.835
April 2003 R.40 1,313.920 2.735 0.000 0.000 0.000 1,316.655
MayLUUJ K.40 1,16::1.::177 2.772 0.000 0.000 0.000 1,168.349
June2003 R.40 1,370.804 7.952 0.000 0.000 0.000 1,378.756
July 2003 R.40 1,285.655 7.952 0.000 0.000 0.000 1,293.607
August 2003 R.40 1,378.567 7.952 0.000 0.000 0.000 1,386.519
September 2003 R.40 1,378.244 7.952 0.000 0.000 0.000 1,386.196
October 2003 R.40 1,359.089 7.673 0.000 0.000 0.000 1,366.762
November 2003 R.40 1,378.077 7.742 0.000 0.000 0.000 1,385.819 -ecember 2003 R.40 1,364.487 7.079 o.uuu U.UUU U.000 1,37U66
Total 16,054.942 72.856 0.000 0.000 0.000 16,127.798
January 2003 R.41 1,454.647 71.818 0.000 0.000 0.000 1,526.465
February 2003 R.41 1,466.420 71.696 0.000 0.000 0.000 1,538.116
March 2003 R.41 1,473.167 71.696 0.000 0.000 0.000 1,544.863
April 2003 R.41 1.484.214 74.043 0.000 0.000 0.000 1,558.257
May2003 R.41 1,515.371 70.230 0.000 0.000 0.000 1,585.601
June 2003 R.41 1,479.066 74.834 0.000 0.000 0.000 1,553.900
July 2003 R.41 1,480.960 74.920 0.000 0.000 0.000 1,555.880
August 2003 R.41 1,489.599 74.920 0.000 0.000 0.000 1,564.519
September 2003 R.41 1,489.598 74.920 0.000 0.000 0.000 1,564.518
October 2003 R.41 1,489.598 69.165 0.000 0.000 0.000 1,558.763
November 2003 R.'11 1,467.177 69.163 0 000 0.000 0.000 1.536.340
December 2003 R.41 1,555.628 71.790 0.000 0.000 0.000 1,627.418
Total 17,845.445 869.195 0.000 0.000 0.000 18,714.640
January 2003 R.42 803.829 3.871 0.000 0.000 0.000 807.700
February 2003 R.42 778.888 3.871 0.000 0.000 0.000 782.759
Ma-,.ch2003 R.42 778.471 3.871 0.000 0.000 0.000 782.342
April lUUJ R.42 776.33::1 4.001 0.000 0.000 0.000 780.336
May2003 R.42 758.577 3.721 0.000 0.000 0.000 762.298
June2003 R.42 785.529 3.937 0.000 0.000 0.000 789.466
July2003 R.42 7&5 'l?Q 3.937 0.000 0.000 0.000 789.466
August 2003 R.42 785.529 3.937 0.000 0.000 0.000 789.466
September 2003 R.42 785.529 3.937 0.000 0.000 0.000 789.466 e October 2003 R.42 782.852 3.937 0.000 0.000 0.000 786.789
Vovember 2003 R.42 788.684 3.937 0.000 0.000 0.000 792.621
December 2003 R.42 774.466 3.937 0.000 0.000 0.000 778.403
Total 9,384.218 46.894 0.000 0.000 0.000 9,431.112
;tfJ
Normalized Megawattliour by Rate and Jurisdiction
Jurisdiction
Month Rate /PUC OPUC NPSC FERC Prairie Power Total
January 2003 R.19S 739.157 0.000 0.000 0.000 0.000 739.157
February 2003 R.l9S 684.432 0.000 0000 0.000 0.000 684.432
March 2003 R.19S 751.543 0.000 0.000 0.000 0.000 751.543
April 2003 R.19S 708.021 0.000 0.000 0.000 0.000 708.021
May2003 R.19S 668.087 0.000 0.000 0.000 0.000 668.087
June 2003 R.19S 816.823 0.000 0.000 0.000 0.000 816.823
July2003 R.19S 719.587 0.000 0.000 0.000 0.000 719.587
August 2003 R.19S 854.938 0.000 0.000 0.000 0.000 854.938
September 2003 R.195 741.886 0.000 0.000 0.000 0.000 7� 1.886
October 2003 R.19S 723.403 0.000 0.000 0.000 0.000 723.403
November 2003 R.19S 722.903 0.000 0.000 0.000 0.000 722.903
December 2003 R.19S 789.751 0.000 0.000 0.000 0.000 789.751
Total 8,920.531 0.000 0.000 0.000 0.000 8,920.531
January 2003 R.19P 155,028.897 12,318.874 0.000 0.000 0.000 167,347.771
February 2003 R.19P 157,943.028 13,402.695 0.000 0.000 u.uuu I'/ l,j4'.l.723
March 2003 R.19P 151,336.428 13,687.467 0.000 0.000 0.000 165,023.895
April 2003 R.19P 156,562.802 13,997.595 0.000 0.000 0.000 170,560.397
MayZOOJ R..191' 1.50,989.699 9,614.397 0.000 0.000 0.000 160,604.096
June 2003 R.19P 156,914.550 13,409.591 0.000 0.000 0.000 170,324.141
July 2003 R.19P 161,586.309 10,709.610 0.000 0.000 0.000 172,295.919
August 2003 R.19P 166,388.441 15,256.371 0.000 0.000 0.000 181,644.812
September 2003 R.19P I 56,835.204 14,164.256 0.000 0.000 0.000 170,999.460
October 2003 R.19P 166,044.670 13,034.536 0.000 0.000 0.000 179,079.206
November 2003 R.19P 169 ,611.294 13,333.085 0.000 0.000 0.000 182,944.379 eecember 2003 R.19P 165,314.:WJ 10,964.lS:55 0.000 0.000 0.000 176,279.0.56
Total 1,914,555.523 153,893.332 0.000 0.000 0.000 2,068,448.855
January 2003 R.19T 5, 184.418 7,489.413 0.000 0000 0.000 12,673.831
February 2003 R.19T 5,383.401 8,244.186 0.000 0.000 0.000 13,627.587
March2003 R.19T 5,439.626 8,883.065 0.000 0.000 0.000 14,322.691
April 2003 R.19T 5,077.978 3,655.711 0.000 0.000 0.000 8,733.689
May2003 R.19T 5,681.468 6,839.465 0.000 0.000 0.000 12,520.933
June 2003 R.19T 4,105.681 9,266.587 0.000 0.000 0.000 13,372.268
July 2003 R.19T 4,484.620 10,226.523 0.000 0.000 0.000 14,711.143
August 2003 R.19T 3,804.855 9,212.426 0.000 0.000 0.000 13,017.281
September 2003 R.19T 4,046.131 9,491.067 0.000 0.000 0.000 13,537.198
October 2003 R.19T 4,277.808 10,009.378 0.000 0.000 0.000 14,287.186
November 1003 R.19T ,,R40.707 8.272.686 0.000 0.000 0.000 12,113.393
December 2003 R.19T 4,021.490 8,116.322 0.000 0.000 0.000 12,137.812
Total 55,348.183 99,706.829 0.000 0.000 0.000 155,055.012
January 2003 R.26 52,745.649 0.000 0.000 0.000 0.000 52,74'.l.649
February 2003 R.26 47,447.849 0.000 0.000 0.000 0.000 47,447.849
March 2003 R.26 52,249.077 0.000 0.000 0.000 0.000 52,249.077
April 2003 R.26 .50,825.020 0.000 0.000 0.000 0.000 50,825.020
May2003 R.26 53,748.590 0.000 0.000 0.000 0.000 53,748.590
June 2003 R.26 53,130.840 0.000 0.000 0.000 0.000 53,130.840
July 7001 R.26 55.582.107 0.000 0.000 0.000 0.000 55,582.!07
August2003 R.26 54,984.639 0.000 0.000 0.000 0.000 54,984.639
September 2003 R.26 52,963.281 0.000 0.000 0.000 0.000 52,963.281
• October 2003 R.26 54,813.054 0.000 0.000 0.000 0.000 54,813.054
November 2003 R.26 53,426.583 0.000 0.000 0.000 0.000 53,426.583
December 2003 R.26 55,050.981 0.000 0.000 0.000 0.000 55,050.981
Total 636,967.670 0.000 0.000 0.000 0.000 636,967.670
J&'
· Normalized Megawatthour by Rate and Jurisdiction
Jurisdiction
Month Rate JPUC OPUC NPSC FERC Prairie Power Total
January 2003 R.29 16,526.076 0.000 0.000 0.000 0.000 16,526.076
February 2003 R.29 14,858.971 0.000 0.000 0.000 0.000 14.858.971
March2003 R.29 16,344.233 0.000 0.000 0.000 0.000 16,344.233
April 2003 R.29 15,709.687 0.000 0.000 0.000 0.000 15,709.687
May2003 R.29 15,930.924 0.000 0.000 0.000 0.000 15,930.924
June 2003 R.29 10,993.719 0.000 0.000 0.000 0.000 10,993.719
July2003 R.29 16,245.279 0.000 0.000 0.000 0.000 16,245.279
August 2003 R.29 16,427.352 0.000 0.000 0.000 0.000 16,427.352
September 2UU3 K.l'J 14,914.492 0.000 0.000 0.000 0.000 14,9H.'192
October 2003 R.29 16,344.556 0.000 0.000 0.000 0.000 16,344.556
November 2003 R.29 15,842.521 0.000 0.000 0.000 0.000 15,842.521
December 2003 R.29 16,546.855 0.000 0.000 0.000 0.000 16,546.855
Total 186,684.665 0.000 0.000 0.000 0.000 186,684.665
January 2003 R.24 0.000 0.000 0.000 0.000 0.000 0.000
February 2003 R.24 0.000 0.000 0.000 0.000 O.UOU 0.000
March 2003 R.24 0.000 0.000 0.000 0.000 0.000 0.000
April 2003 R.24 0.000 0.000 0.000 0.000 0.000 0.000
May2003 R.24 0.000 0.000 0.000 0.000 0.000 0.000
June 2003 R.24 0.000 0.000 0.000 0.000 0.000 0.000
July2003 R.24 0.000 0.000 0.000 0.000 0.000 0.000
August 2003 R.24 0.000 0.000 0.000 0.000 0.000 0.000
September 2003 R.24 0.000 0.000 0.000 0.000 0.000 0.000
October 2003 R.24 0.000 0.000 0.000 0.000 0.000 0.000
November 2003 R.24 0.000 0.000 0.000 0.000 0.000 0.000
.ecember 2003 R.24 0.000 U.OUU 0.000 0.000 0.000 0.000
Total 0.000 0.000 0.000 0.000 0.000 0.000
January 2003 R.24S 795.131 37.655 0.000 0.000 0.000 832.786
February 2003 R.24S 681.688 34.357 0.000 0.000 0.000 716.045
March 2003 R.24S 1,225.015 26.166 0.000 0.000 0.000 1,251.181
April 2003 R.24S 6,726.775 236.639 0.000 0.000 0.000 6,963.414
May2003 R.24S 107,257. 754 4,569.640 0.000 0.000 0.000 111,827.394
June 2003 R.24S 222,664.408 7,501.719 0.000 0.000 0.000 230, 166.127
July 2003 R.24S 335,431.579 7,480.381 0.000 0.000 0.000 342,911.960
August 2003 R.24S 380,512.738 10,111.576 0.000 0.000 0.000 390,624.314
September 2003 R.24S 308,379.055 8,806.620 0.000 0.000 0.000 317,185.675
October 2003 R.24S 134,090.105 3,852.952 0.000 0.000 0.000 137,943.057
November 2003 R.24S 34,346.70'i 1,112.255 0.000 0.000 0.000 35,478.960
December 2003 R.24S 6,584.005 195.677 0.000 0.000 0.000 6,779.682
Total 1,538,694.958 43,985.637 0.000 0.000 0.000 1,582,680.595
January 2003 R.24T 0.000 0.000 0.000 0.000 0.000 u.uoo
February 2003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
March2003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
April 1003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
May2003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
June 2003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
July)003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
August 2003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
September 2003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
• October 2003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
ovember 2003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
December 2003 R.24T 0.000 0.000 0.000 0.000 0.000 0.000
Total 0.000 0.000 0.000 0.000 0.000 0.000
7&J
· Normalized Megawatthour by Rate and Jurisdiction
Jurisdiction
Month Rate /PUC OPUC NPSC FERC Prairie Power Total
January 2003 R.25S 2.939 0.000 0.000 0.000 0.000 2.939
February :wn3 R.25S 4.256 0.000 0.000 0.000 0.000 4.256
March 2003 R.25S 60.395 0.000 0.000 0.000 0.000 60.395
April 2003 R.25S 404.622 0.000 0.000 0.000 0.000 404.622
May2003 R.25S 5,967.106 0.000 0.000 0.000 0.000 5,967.106
June 2003 R.25S 10,848.655 0.000 0.000 0.000 0.000 10,848.655
July2003 R.25S 18,556.454 0.000 0.000 0.000 0.000 18,556.454
August 2003 R.25S 19,449.552 0.000 0.000 0.000 0.000 19,449.552
September 2003 R.258 16,669.871 0.000 0.000 0.000 0.000 16,669.871
October 2003 R.25S 7,897.818 0.000 0.000 0.000 0.000 7,897.818
November 2003 R.25S 2,220.753 0.000 0.000 0.000 0.000 2,220.753
December 2003 R.25S 153.552 0.000 0.000 0.000 0.000 153.552
Total 82,235.973 0.000 0.000 0.000 0.000 82,235.973
January 2003 ASTARlS 0.000 0.000 0.000 0.000 0.000 0.000
February 2003 AST ARIS o.uuu 0.000 0.000 0.000 0.000 0.000
March 2003 AST ARIS 0.000 0.000 0.000 0.000 0.000 0.000
April 2003 AST ARIS 0.000 0.000 0.000 0.000 0.000 0.000
May:1003 AST ARIS 0.000 0.000 0.000 n non 0000 n.onn
June 2003 AST ARIS 0.000 0.000 0.000 0.000 0.000 0.000
July 2003 ASTARIS 0.000 0.000 0.000 0.000 0.000 0.000
August 2003 ASTARIS 0.000 0.000 0.000 0.000 0.000 0.000
September 2003 AST ARIS 0.000 0.000 0.000 0.000 0.000 0.000
October 2003 ASTARIS 0.000 0.000 0.000 0.000 0.000 0.000
Navember 2003 AST ARIS 0.000 0.000 0.000 0.000 0.000 0.000
-ecember 2003 AST ARIS 0.000 0.000 0.000 0.000 0.000 0.000
Total 0.000 0.000 0.000 0.000 0.000 0.000
January 2003 INEEL 19,625.268 0.000 0.000 0.000 0.000 19,625.268
February 2003 INEEL 18,097.598 0.000 0.000 0.000 0.000 18,097.598
March2003 INEEL 17,316.482 0.000 0.000 0.000 0.000 I 7,316.482
April 2003 INEEL 16,616.064 0.000 0.000 0.000 0.000 16,616.064
May2003 IN EEL 14,984.734 0.000 0.000 U.000 U.UUO 14,984.734
June 2003 IN EEL 14,653.000 0.000 0.000 0.000 0.000 14,653.000
July 2003 IN EEL 14,480.000 0.000 0.000 0.000 0.000 14,480.000
August 2003 IN EEL 15,373.000 0.000 0.000 0.000 0.000 15,373.000
September 2003 IN EEL 13,860.000 0.000 0.000 0.000 0.000 13,860.000
October 2003 IN EEL 16,873.000 0.000 0.000 0.000 0.000 16,873.000
November 2003 INEEL 19,052.000 0.000 0.000 0.000 0.000 19,052.000
December 2003 IN EEL 22,153.000 0.000 0.000 0.000 0.000 22,153.000
Total 203,084.146 0.000 0.000 0.000 0.000 203,084.146
January 2003 WEISER 0.000 O.UOU 0.000 5,230.221 0.000 :'.l,230.221
February 2003 WEISER 0.000 0.000 0.000 4,195.994 0.000 4,195.994
March2003 WEISER 0.000 0.000 0.000 4,017.738 0.000 4,017.738
April:1003 WEISER 0.000 0.000 0.000 3,299.745 0 000 3.299.745
May2003 WEISER 0.000 0.000 0.000 3,319.191 0.000 3,319.191
June 2003 WEISER 0.000 0.000 0.000 3,613.318 0.000 3,613.318
July 2003 WEISER 0.000 0.000 0.000 4,464.101 0.000 4,464.101
August 2003 WEISER 0.000 0.000 0.000 4,171.675 0.000 4,171.675
September 2003 WEISER 0.000 0.000 0.000 3,608.617 0.000 3,608.617
• October 2003 WEISER 0.000 0.000 0.000 4,070.513 0.000 4,070.513
'November 2003 WEISER 0.000 0.000 0.000 4,398.801 0.000 4,398.801
December 2003 WEISER 0.000 0.000 0.000 5,246.824 0.000 5,246.824
Total 0.000 0.000 0.000 49,636.738 0.000 49,636.738
1eJ
• Normalized Megawatthour by Rate and Jurisdiction
Jurisdiction
Month Rate /PUC OPUC NPSC FERC Prairie Power Total
January 2003 RAFTRIVR 0.000 0.000 0.000 5,042.294 0.000 5,042.294
February 2003 RAFTRIVR 0.000 0000 0000 4.857.674 0.000 4,857.674
March2003 RAFTRIVR 0.000 0.000 0.000 4,806.844 0.000 4,806.844
April 2003 RAFTRIVR 0.000 0.000 0.000 4,293.671 0.000 4,293.671
May2003 RAFTRIVR 0.000 0.000 0.000 4, 186.860 0.000 4, 186.860
June 2003 RAFTRIVR 0.000 0.000 0.000 3,911.759 0.000 3,911.759
July2003 RAFTRIVR 0.000 0.000 0.000 4,186.470 0.000 4,186.470
August 2003 RAFTRIVR 0.000 0.000 0.000 4,173.733 0.000 4,173.733
September .L003 RAFTRIVR 0.000 0.000 0.000 3,786.054 0.000 3,786.054
October 2003 RAFTRIVR 0.000 0.000 0.000 4,343.007 0.000 4,343.007
November 2003 RAFTRIVR 0.000 0.000 0.000 4,868.518 0.000 4,868.518
December 2003 RAFTRIVR 0.000 0.000 0.000 5,416.825 0.000 5,416.825
Total 0.000 0.000 0.000 53,873.709 0.000 53,873.709
January 2003 UAMPS 0.000 0.000 0.000 0.000 0.000 0.000
February 2003 UAMPS 0.000 0.000 0.000 U.UUU 0.000 0.000
March 2003 UAMPS 0.000 0.000 0.000 0.000 0.000 0.000
April 2003 UAMPS 0.000 0.000 0.000 0.000 0.000 0.000
MayZ003 UAMf'S 0.000 0.000 0.000 0.000 0.000 0 000
June 2003 UAMPS 0.000 0.000 0.000 0.000 0.000 0.000
July2003 UAMPS 0.000 0.000 0.000 0.000 0.000 0.000
August 2003 UAMPS 0.000 0.000 0.000 0.000 0.000 0.000
September 2003 UAMPS 0.000 0.000 0.000 0.000 0.000 0.000
October 2003 UAMPS 0.000 0.000 0.000 0.000 0.000 0.000
November 2003 UAMPS 0.000 0.000 0.000 0.000 0.000 0.000
.December 2003 UAMPS U.UUU 0.000 0.000 0.000 0.000 0.000
Total 0.000 0.000 0.000 0.000 0.000 0.000
January 2003 WCITY 0.000 0.000 0.000 0.000 0.000 0.000
February 2003 WCITY 0.000 0.000 0.000 0.000 0.000 0.000
March2003 WCITY 0.000 0.000 0.000 0.000 0.000 0.000
April 2003 WCITY 0.000 0.000 0.000 0.000 0.000 0.000
May2003 WCITY 0.000 0.000 0.000 0.000 0.000 U.UUU
June 2003 WCJTY 0.000 0.000 0.000 0.000 0.000 0.000
July 2003 WCITY 0.000 0.000 0.000 0.000 0.000 0.000
August 2003 WCITY 0.000 0.000 0.000 0.000 0.000 0.000
September 2003 WCJTY 0.000 0.000 0.000 0.000 0.000 0.000
October 2003 WCJTY 0.000 0.000 0.000 0.000 0.000 0.000
November )003 WCITY 0.000 0.000 0.000 0.000 0.000 0.000
December 2003 WCITY 0.000 0.000 0.000 0.000 0.000 0.000
Total 0.000 0.000 0.000 0.000 0.000 0.000
January 2003 COLTON 0.000 0.000 0.000 2,232.UUU 0.000 2,232.000
February 2003 COLTON 0.000 0.000 0.000 2,016.000 0.000 2,016.000
March2003 COLTON 0.000 0.000 0.000 2,232.000 0.000 2,232.000
April 1003 COLTON 0.000 0.000 0.000 2,157.000 0.000 7,1'\7000
May2003 COLTON 0.000 0.000 0.000 2,232.000 0.000 2,232.000
June 2003 COLTON 0.000 0.000 0.000 2,160.000 0.000 2,160.000
July 2003 r.OI.TON 0.000 0.000 0.000 2,232.000 0.000 2,232.000
August 2003 COLTON 0.000 0.000 0.000 2,232.000 0.000 2,232.000
September 2003 COLTON 0.000 0.000 0.000 2,160.000 0.000 2,160.000
• October 2003 COLTON 0.000 0.000 0.000 2,235.000 0.000 2,235.000
November 2003 COLTON 0.000 0.000 0.000 2,160.000 0.000 2,160.000
December 2003 COLTON 0.000 0.000 0.000 2,232.000 0.000 2,232.000
Total 0.000 0.000 0.000 26,280.000 0.000 26,280.000
J,6£1
· Normalized Megawatthour by Rate and Jurisdiction
Month
Grandtotal
•
Rate JPUC
12,096,838.216
OPUC
636,854.900
Jurisdiction
NPSC
0.000
FERC
129,790.447
Prairie Power
0.000
Total
12,863,483.563
•
•
Adjustments Made to Industrial/Commercial Actual Sales
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Q
oe .,., 0 O'I .,., 00 00 .,., N N N '° O'I ...., r-- M 00 00 00 - - 0""" ..c: r--. 0 ..., N M """· "':. r--. 0 M O'I
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M ..,. "' 00 0 .,., r-- r-- 00 00 N °' 0 """ °' 00 \C) 0 N r-- M I.O \C) M ..,. 0 \C) "" .,., M °' N N 0 °' N .,., O'I .,., ..,. M N N .,., r-- M r-- 00 ..c: 00 II") ..,. "" '° 00 00 o. ..,. 00 '° r-- ..c: ..,. 0 \C) ..,. 00 0 '° N .,., N N 0 ..,. • � > . ...... � � .,.,· t � N• r---" � QO M � ...,; °' r--· 'C � QO QO °' 0 ..; ,...; N .,., ..; QO '° . °' 0 ... 2 00 °' "' ..., "" <'< "<I" .... , "" "° ::0 -; :: <>-· ..... 0-, ..... 0-, ... N "' :.; ..... °' "" "' OS ""l. 0 r-- """· ...., oo_ \C) 0 °' "':. .,., °' N "':. r-- O'I .,., ..,. '°· N 0 '° !'-;, .. "' � ci ci °' .,., r---" � 0 .,., c .,, ....; ..; ....;- ,...; r-f 0 ,...; ..; °' r---" .... E = -; M = .; - .,., Oil ·;: ;;- = II") II") '° .,., \C) '° .,., .,., .,., .,., .,., .,., r-- [-, ;s ::, N N N N N N N N N N \C) 0:: ..... oo. N g,, < .. < t < <
00 N I.O N 00 II") 00 r-- N M r-- °' O'I 00 r-- .,., 0 °' M '° .,., .,., °' °' ...., M r-- °' \C) .,., M """ N 00 II") """ 0 ..., 00 .,., 00 M 00 '° \C) 00 ..c: 0 0 00 \C) r-- N 00 ..,. ": 0 0 r-- = ..c: """ 00 °' '° q_ 0 """ o. r-- .... °' t °' .,., .,., � QO QO N. °' ..; QO QO r---" Q ....; QO oo· r..:- QO ci °' ..; .,., °' r---" = 'C � ·;;; "O � M Q � ,! !! 00 °' N °' °' \C) ..., 00 II") 0 '° ...., "' .. .,., r-- O'I \C) \C) °' ..,. 00 ..,,. 00 .,., M 0 ·;;; .-- � - ..... ,,e ,,e ..... ..... •O ..... ..... ,o ..... .... "' "t: °' oo. 00 "<- "). oq_ """· <"'!. <Xl. �- 00 .,., � "' QO .. ·e oo· 00 o-," \Ci' i--:· "' = = .; .... = -; "' °' r-- r-- r-- oe 00 M ·e .. Q . ..., .a "' "' ;;- = °' g:; ... 'C 0:: = ... "' .. < "' .. < .. = rlJ < ... < "' ,... ... ... rlJ "' °' M r-- .,., r-- 0 '° r-- 0 r-- i� M 0 00 "' .,., r-- """ .,., r-- .,., r-- r.l .... """ '° 00 """ """ r-- '° ..,. N \C N .,., M °' "' N 0 r-- °' \C) O'I °' 0 ... "O = II") """ °' r-- '"'!. ...., ...., ":. """· 00 .,., r-- r-- = 0 0 0 00 N � 00 '° """ .,., M 0 < = ..c: � r---" r--" .,., N• � oo· ,...; °'..; Q ..c: ,..,· .,., r---" N ci °'. 00 <'i "' "' ..; 0 Q ..., ·;;; rlJ c,s ·;;; 'C � 00 °' .,., 0 N N """ N ..,,. r-- t"'l M "' O'I >, "O � .,., ..,. M 00 O'I r-- °' 0 00 °' 0 � °' "' ! M ..., """ """ ..,,. ..,,. """ ""'" .,., ..,,. ...., Mq ... .. °' M r-- \C) .,., 00 .,., ..., """ '° °' '° 00 ... ·e .... � .. ·e . .... .. ....; 6 ... ,..;' "' N• d "' ci ci ci °' � < .; = -; "' .. e .. oi .. ... - ;;l E "' ..... .E = OI ·;: ;;- .E er:: = 'C "' CZ: ... ·;: c,s < ... ... g,, < ... u ... < ..... < g,,. ... < � "' c .... = ... ... .,., "' °' °' r-- "' '° 0 r-- II") """ - - = O'I '° 0 N '° °' '° """ \C) 0 """ ...., r.l Q 0 0 r-- 0 ...., ...., .,., .,., r-- °' ..,,. 00 "' r-- .,., M r-- .,., N r-- ...., r-- ..,,. ..., - O'I "iii .,., r-- N """· N .,., 00 N I.O \C) """ >, .,., � ...., ...., r-- O'I "' \C) r-- O'I N "'1' Q "' ..c: '°. r..:- o" o" """ °' ..,,.· ci ..,,.· r---" °' MOO ..c: ..; ..; ..... 0 .,.;- ...,; 0 � r--· r--" N• V) .. N < ·e 'C � ... 'C � >, 00 O'I ...., 00 r-- 0 '° N N 0 N OI >, °' N '° °' ...., .,., N 0 0 �- .,., � "' "' ... .. '° -. ...., ...., 0 r-- 0 O'I N '° °' ...., ..,,. E "' ... .. '"'!. -. q ":. ""l. oo. oo. � r--. -. ..,,. .... .... "' .a "' ! ,,,; "' c· ,,,.; ...: ...: ...: ...: .,., .,., � oo" .!! OI "' .....; r..:- rlJ c,s OI I: oi N .... ...... M N N N N N N N NM ·;:: .. 5 -� "!! ,... ... ·;: ..... .a ...., ;.. ·;::: = ... 0:: 'C CZ: 'C z g,, < °' g,, < .... ... .. "" °' < < ::; >, 6 .... ... = ... .. rlJ E = "' ;;l � § § ....... ....... ....... ....... ....... .... 8 8 ....... 8 I: ::: .... ....... ...., ....... 8 ....... ....... 8 8 8 ....... ....... ·;: g c:, g c:, c:, c:, c:, ·;: CJ c:, c:, c:, c:, c:, c:, c:, <:::, ..., g,, CJ c:, c:, c:, c:, c:, c:, c:, c:, 1:1., :s c:, c:, c:, c:, c:, <:::, <:::, c:, c:, c:, c:, <:::, Q :s "' "' "' ...... ...... ...... ...... ...... ...... "' "I "I "' "I "' "I ...... "' "' "' ...... ...... ,..... ,..... ,..... < °' "' ..c: "' -c, - ... ... ... ... (' ('..,;: ":::: � O'I ·;::: ..c: "' -0 ..... ... � .... .... C' C' ..,;: :-::::: ?-,. ... ., = ., ·� ;..; ·.::: = :: � � "' "' "' "' c:s � ... ;,; = :: � ::s "' "' "' � �� � .,:, .,:, .,:, .,:, c:s � � ..., � .,:, � .,:, .,:, c:s <::l .!! :, Q E: c e e ::s i:: � .. Q � !:: E: !:: ::s ::s � = ..., � t :: :i = � :: ... "'>: 'C "'>: "' "' IU � .,:, "O Q -.:: � <> � "' � .,:, Q �a ;;. <> a <> ... ... ..c: c "' � .. CID & � "' � ..c: "' :.:: Q .c ... Q ; ... 'C c..:i CJ ... � rlJ ... "1 0
1&7 r
•
•
•
ADJUSTMENTS MADE TO INDUSTRIAUCOMMERCIAL ACTUAL SALES (kWh)
J. R. SIMPLOT COMPANY - CALDWELL
The energy was underbilled in May 2002 (20,382 kWh). The correction was made in November 2002
(20,382 kWh). Only Schedule 19 Primary Service was affected.
FMC CORPORATION
The energy did not bill in June 2002 (2,469,316 kWh) or July 2002 (2,370,432 kWh). The correction was
made in September 2002 (4,839,748 kWh). The energy was overbilled in July 2002 (63,000). The correction
was made in October 2002 (63,000 kWh). Only Schedule 19 Primary Service was affected.
WESTFARM FOODS
The energy was underbilled in August 2002 (184, 132 kWh). The correction was made in November 2002
(184, 132 kWh). Only Schedule 9 Primary Service was affected.
MELBA HIGH SCHOOL
The energy was underbilled in October 2002 (873 kWh). The correction was made in December 2002 (873
kWh). Only Schedule 9 Primary Service was affected.
MERCY MEDICAL CENTER
The energy was underbilled in October 2002 (104,904 kWh) and November 2002 (37,785 kWh). The
correction was made in December 2002 (142,689 kWh). Only Schedule 19 Primary Service was affected.
NORCO, INC.
The energy was underbilled in November 2002 (2,698 kWh). The correction was made in December 2002
(2,698 kWh) Only Schedule 19 Transmission Service was affected .
UNION PACIFIC RAILROAD COMPANY
The energy did not bill in May 2003 (397,317 kWh). The correction was made in June 2003 (397,317 kWh).
Only Schedule 19 Primary Service was affected .
W:\Word\Nonnalized MWh Reports\Adustments to Actual Sales.doc
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LINE
NO
2
3
Idaho Energy Resources Company
Known and Measurable Adjustment
Income Tax Expense
Adjust to Remove Tax Contingencies
2003 Income Tax Expense - Forecasted
2003 Income Tax Expense - Revised
Adjustment Required to Increase Income Tax Exµer1::;e
Adjustment Required to Reduce Subsidiary Rate Base:
$ (813,715)
$ 4, 186,285 1
$ 5,000,000 e
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
December
January
February
March
April
May
June
July
August
September
October
November
December
13 month Average - Decrease Rate Base
1 Forecasted pre-tax income
Less tax-exempt interest income
'raxaoie
Tax at 35%
$
$
$
$ $ (2,000,000)
$ (2,000,000)
$ (2,000,000)
$ (2,000,000)
$ (2,000,000)
$ (2,000,000)
$ (5,000,000)
$ (5,000,000)
$ (5,000,000)
12,127,478
(166,665)
11,960,813
4,186,285
$ (2,076,923)
2 Contingent tax reserves associated with prior years were revalued during 2003
and resulted in a decrease to income tax expense of $2,000,000 in April and
$3,000,000 forecasted to take place in October. For ratemaking purposes,
contingent tax reserve adjustments are not allowed as part of regulated tax
expense.
Idaho Energy Resources Company
Known and Measurable Adjustment
Income Tax Expense
Adjust for 2003 Refunds and Deficiencies
LINE
NO
2003 Income Tax Expense - Adjusted $ 4,186,285
2 1994 Income Tax Refund1 $ (66,303)
3 1995 Income Tax Doficioncyt s 357.573
4 Net 2003 Deficiency - Increase to Income Tax Expense $ 291,270 $ 291,270
5 Adjusted Tax Expense $ 4,477,555
1 The 1994 refund was received 2/11 /03 and the 1995 deficiency was paid 1 /21 /03
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