200804302007Earnings Report.pdf

. ~~l,~OUNTAIN
April 30, 2008
RECEIVED
08 APR 30 AM to: 1 6
201 South Main, Suite 2300
Salt Lake City, Utah 84111
VI OVERNIGHT DELIVERY
FULLle
COMMiSSiON
Idaho Public Utilities Commission
472 West Washington
Boise,Id 83702-5983
AUntion:Jean D. Jewell
Commssion Secreta
RE:PAC-E-02-03
Rocky Mountain Power Anua Earngs Report
Transmitted herewith, please find an original and 7 copies of Rocky Mountain Power's results of
operations for the Idaho jurisdiction for the twelve mons ended December 31, 2007. The
report provides actual and normalized results of operations, b~ the Revised Protocol
Methodology.
Pursuant to th Stipulation and Agreement between the paries, approved and inlud in the
Commission s Order in Case No. PAC-E-02-03, Rocky Mouta Power agree to file an anua
earngs report with the Gommission.
If there are any questions related to this report, or other additional matters that the Commission
or other paries wish to discuss, please don't hesitate to contact me at [phone] or Ted
Weston at [phone].
Sincerely,
J\~J 0 WO",,).& Ie ~
Steven R. McDougal
Dire*r,.venue Requirement
Enclosures
.... f" C 'ut: ,D.bLt:vi.hi ..~
APR 3 G Arlin: i 9
i D ßl~J~i~J ..f:tl r?~~ 1.ç _-~
UTiLiTiES CUì'iÍMi~~ION
A DIVISION OF PACIFICORP
Idaho Jurisdiction
RESULTS OF OPERATIONS
For Period Ending
December 200i
'-1.0
ROCKY MOUNTAIN POWERStai. of Idaho. EI Utlit ~CEIVCD.Ac, Aduai. & Normliz Ra.ull of Operaoni . Revaa P .. ..L. ·
Twlv Mon Ende De.. 2007
(11 (21 (31 (41 ~ll~adlM iO: l"3 (7
Unaduii.Type 1 Totl AdJuli.Typ2 Totl Noliz
Rnull Adjulmnll Actl Rnulll AdJullmnl Acll Ralll AdJul-"1I R..ull
1 Oprating R_nui:2 Geral Bulil Ravua 1841",833 4,88,334 189.181,187 8,852 slWl.~81
20,1.80
3 Inlrdapart
4 Spalll SII..84281,130 54.281.130 41,541,528 103.82.857
5 Olr Operating R_nu..7,315,43 1383,74)8,151,758 1,821,328 ..781,128
8 Totl Oporang Roya_245,798,384 4,822,660 25,419,054 83,112.835 313,589,383
7
8 Oporatlng expo",":I Si.m Proucti 58421,205 55.421,205 22.813 55.44.818 (31.821 58411,88
10 Nucler Proucti
11 Hyro Prouction 2.1'7.113 53.'38 2,251,130 3.04 2.254.17'11.047 2,281,223
12 Ot "-r Supply 80.133,931 8,22.103 88,338,042 270.241 ".80,283 81.87'.201 138.482,48
13 Tranallion 9.85319 (8,3851 ',857.425 3,211 1.860.53'341.17'10,20611
14 Dlllrbutn 10,80835 (3781 10,8045 20,'78 10,828,43 81,31 10,81.788
15 Cuatr Acou 4,273.420 '.070 4,28249 16._4,29549 33,28 4,1,812
18 Cuator S.1V1c 3,"',850 (2.05.8341 1,810,828 1.520 1.112,34 8,411 1.818,757
17Sale18 Adlnlatr & G...ral ',84U21 547,538 10,3'2,459 14,811 10.407,120 158,80 10,583,02'
xx
11 Totl o&M Expa..171,20.811 4,748042 180,'58032 352,330 181.30.352 52,48,317 23787.58
ii
20 Deprelitlon 24741.891 (31,1751 24708,708 (2,87.541 21.53.181 ..358 2280,530
21 Amtin 3,188,419 (73,8511 3,111,758 4,08 3.11....117.'73 3,313,529
22 To.. 0l Thn Inc 4,857.065 4,857,085 4,55.085 5358 5.28.847
23 Incom Tax.. . Fedl 4,083.241 (48.7411 3.828,500 (531.1281 2,88372 158.318 3.181.880
24 Incom Tax... S_80.287 (4844.1 55818 (32,2821 52.53 ".13'52.275
25 Inom Tax.. . De Na 2,'17.180 (288,2031 2,818,977 811.833 3.23.110 1,23,73 4,.34
28 i__nl Tu Creit Adj.(744801 (744.801 (744801 1744801
27 Mil Rev.nUl & ExPI 178,7'~58180 1182,8011 1182,6081 11.2.011
ii
28 Totl Oprating Expn_:214,835,337 4.38013 21'.328,351 (2,58.801 218,782.447 55.757.034 272,119.481
28
30 Oprating Rev For Rern:30,811,058 22.547 31,080,703 2,583.39 33.58,101 7,38,801 41,03',802
31
32 ~..:
33 Elelr Plt In Salce 13,817.842 7,158.855 847.817.587 31.052,09 17.889.888 28148.827 1.00.018,323
34 Pllnt Hald for Futre U..48.401 (48,411
35 Mil De.. Debll 3,80.249 (28.4021 3,778.54 3,77,84 217.705 3...55.38 Elec Pllnt Ac Ad 4,758.257 4,789,257 4,758,2 4,758257
37 Nucr FUll38 Prymnll 2,247,505 2,247,505 2,247.50 2,7.50
31 Fuel Stok "803,185 5.803,185 "80.185 1.05.114 ..858....
40 Millril & Suppllai 8,887.878 8.817,878 8.887.875 8,88.'71
41 Woing Capil 4,57.502 (1,27.7351 2.'77.888 (4,331 2,87528 74405 3,717.582
42 W..thrlon Lo",8,131.80 8.131.80 8.131.80 '.131.80
43 Mil Rai. Ba..48,384 48384 48,384 484.84
ii
44 Totl Ei. Plant 178,48.317 1.193.117 882,855,43 31.047.781 1.013,703.115 30,184810 1.04...104
4848 Rai... Deuc:47 Acum Pro For Depre (374,35,44'1 310.58 (374,0525831 1.377.754 (372,574.77'1 (48.8491 (373,1557281
48 Acum Pro For Am (21.875,5851 108.'77 (21.589.6081 (2,041 (21.571.6531 2,80 (21,58.841
49 Acum De Inca Tax (8248.8501 84300 (81.122.551 (47328.1 (82,08.8201 (1.227351 (83.31'.551
50 Unaorad IT (84221 (82.8331 (118.8191 (118,851 (116.8811
51 Cuatomer Ad For Co",1 (145.8801 (23,1201 (38''~1 (38811 (38881
52 Cuator Sarv De_II53 MI Rai. Bai. Deuci 14,441,111 ~3,09,8681 1!751,7871 (1,751,571 1!751,7871
54
85 Totl ~ .. Deucon (483,148.8081 (2,341,45'1 (48"488,3871 802,70 (48.888171 (1,701.5781 (4828.7751
58
57 Totl Rai...: 4831UO'3WIM l!.157 0!31 '50,231 52' 107 298 2848303 555l 329
58
81 Rern on Rai. ..'.258%6.25%8.7.3
ii80 Ra on Eq 8.%-0.00%6.274%0.228%8.02%2.13%8.15%
.1
62 TAX CACULAnON:
83 Op8ng RevanUl 37.730.838 (58.7481 37,150.080 2.541!820 38.811,710 8,5.815 48,305
54 Ot Daductli
85 In_t (ANDel
88 ii 14,351.281 1.222085 15.573.34 1,00.83 16.574,180 881.5"17,4779
87 SChadulè "M" Adlli 43.131.11 ..808 44087,651 (2,251.8511 41.8480 77....42818,789
88 Scheule "M Deuctni 84212,158 184088 54376,226 54,378,228 5.347,002 89,723,228
89 1_ 8I Tu 12,21,242 (1.001.0731 11.298.11'(711.081 10.587.103 3,384"3 13.'82,087
70
71 Stai.lncom Tix..~287 ~45441 558,818 (32.2821 528,538 ",73'628 275
72 T..bI InCO.1'VS 1.621 10l3Ù51 li787831 10 °60.567 3295m 11,55:811
13
74 Fadorllnco Tu.i + Otr 4,093,241 (48.7411 3,828.500 (531.1281 2.....372 188,318 3.1'1,880
(11 Type 1 adJuitianlllnvolv normliztion for out of perlod IdJUllmnl and unuaualllmi that occur durlngll. i.it period.
(21 Ty 2 adJuiti.nll.nnualz chanllllat ocu.. durlngth ..t peri..(31 Type 3 adJul_nll '" known ind maaiuribl. lti lIt will ocur In a fure i.it porl.
IDAO SUMMARY OF ADJUSTMENTS TOTAL Pag 1.1
Net Po Co Ot.Rev Adnll O&AdUltm Adus De &Tax Adjusi_ MI Ra Il Adjull
Tol Adus (Tab 31 (Tab 41 (Tab 51 Am (Tab 81 (Tab 71 AdjU (Tab 81 (Tab 91 Ot (Tab 101
1 0p-2__R_18.744.987 18,744.9873~
4 Spo Sole 48,541,52 48,541,525 0I 0p R_1,478,498 1.011.087 38.40
8 T.. 0p R_87.782,88 17,82.053 48,38,36
7
8 0p~8__(8,2)103,02 (112.10)10N__IIHy_81,03 7e.71 (10,048)
12 OIP_Su 58,348.48 1,481.98 58,II,øs13T_33,711 (3,35)342.14814_88.111 88,3115e--.58,82 58,38218C__IIn (2,041,03)(2,04,10)17_18 _I (l 718,108 988,08 (21.50)
18 T..O&~57,551,88 714,981 58854,787 110,048)
20 Do (1,111,351)(8 (1,li,502)(35,187)21_128110 (7,85)(12,701)44,48 104.20
22 T_OITl_83.81 83.81
23_T_:F_(81,551)5,55,88 (158,48)(2,43,708)(371,98)(2,745,175)(1,171,087)
24 St 22,00 801103 (21,28)(33.83 (50.543)(24,433)(180,218)
25 DI _ T_1.52,188 (30,773)(3,472)145,21 778,811 8,042 11537
28 _TIx~Ad.27__I~58,180 782,52 1221.18)",77
28 T.. 0p ~57.58.143 7.258.82 28,357 54.221,100 (1,50,827)(233.885)(352,82)
2t
30 0p RI FOI RI 10.178,l05 10.58.131 (2,357)(4.2l0,1l0)1.50,82 2.332.88 35.82
31
32 -_:33_PIIn_87,158351 (118,420)(3,117)87,318,82
34 PI HI lo FuI UI (458,401)(45,401)
35 _ DI DI 188,30 8,758 18254
38__AoAd37_F..38 ..38F.._1,05,514 1,05,514.40 _ I SU41 Wo Ca (5.010)154,010)42_i.43___
44 T..__87,40.787 (112,870)(38,117)67,557.575
45
48 ll
47 _ _ FOI ll 1,20,72 1.85 852.51 253,404
48__FOI_107,739 17,275 22,81 (2,232 61,70
4I_DI_TIx (85,70)682,158 (58,767)1178,64)(82,22)10,58 (88,775)
5O~ITC (82.33)(8)
51 e.AdFOIC-(2,120 (23',120)52 e-_DI53_~(3,0U88)(2,35,m)(9,88
84
55 T..~:(3 14'.86 (1,458,714)(41.12)(152.08)30,283 (52.06)(V41,76)
58
57 T..__:54.25,821 (1,458.7'.)(184,182)(181,20 30.283 (52,06)85.80.789
58
58
10 e.- Roe in 2.36%4.87'.(1.18%.1.754%0.6_0._-1._0,_0._
81
82
83
54 TAXCAULTl:
85
88 0p R..10.821,48 17,0334 1477,58)(8,80,48)1,881,03 (630,882)(8,145)8701~81 1_ (AUD88_3,114,498 3,114,48870_"M_(513.05)98,80 (38,853)(2874,317)1,878,108n_"M~5.511,070 173,27 (8,081 5.347.00
731__TIx 1,684 17,82,05 148,373)(7,287,138)11,113,279)(3,745.310 (3,52,03)
7478_I_T_22,00 li,30 (21,28)(33,83)(50,543)(24,433)(180,218)
77T_I_1,80,837 17,018,50 (447,108)18,58,30 11,06,738)(3,52.117)(3,36,820)
787IF_I_T_831,551 5855.86 158,481 ,434.708 371,958 ,745175 1,179017
.
.
.
.
Rocky Mountain Power
RESULTS OF OPERATIONS
USER SPECIFIC INFORMATION
STATE:
PERIOD:
IDAHO
DECEMBER 2007
FILE:
PREPARED BY:
DATE:
TIME:
JAM Semi DeC07
Revenue Requirement Department
4/2312008
4:53:47 PM
TYPE OF RATE BASE:
ALLOCATION METHOD:
FERC JURISDICTION:
Beginning/Ending
REVISED PROTOCOL
Separate Jurisdiction
80R 12CP:12 Coincidental Peaks
DEMAND %
ENERGY %
75% Demand
25% Energy
TAX INFORMATION
Page 2.1
RECEIVED
i;Di~,J10PtJEiLjC
UTILITiES COMMiSSl N
TAX RATE ASSUMPTIONS:
FEDERAL RATE
STATE EFFECTIVE RATE
TAX GROSS UP FACTOR
FEDERAUSTATE COMBINED RATE
TAX RATE
35.00%
4.54%
1,614
37.95%
CAPITAL STRUCTURE INFORMATION
CAPITAL
STRUCTURE
EMBEDDEDÇQ WEIGHTED
COST
DEBT
PREFERRED
COMMON
50.20%
0,40%
49,40%
100.00%
6,24%
5.41%
10.25%
3.132%
0.022%
5,06%
8.218%
OTHER INFORMATION
REVISED PROTOCOL Page 2.2
BegjnnlnaJEnding
RESULTS OF OPERATIONS SUMMARY.UNADJUSTED RESULTS IDAHO
Description of Account Summary:Ref TOTAL OTHER IDAHO ADJUSTMENTS ADJTOTAL
1 Operating Revenues
2 Generl Business Revenues 2.3 3,228,941,107 3,04,741,273 184,199,833 16,744,967 200,94,800
3 Interdepartental 2.3 0 0 0 0 0
4 Speal Sales 2.3 856,864,831 802,583,701 54,281,130 49,541,526 103,822,657
5 Oter Operati Revenues 2.4 156,475,422 149,159,992 7,315,430 1,476,496 8,791,926
6 Tota Operating Revenues 2.4 4,242,281,360 3,996,484,966 245,796,394 67,762,989 313,559,383
7
8 Operating Expenses:
9 Steam Proucln 2.5 854,983,104 799,561,899 55,421,205 (9,208)55,411,998
10 Nucr Proucion 2.6 °0 0 0 0
11 Hydro Proucn 2.7 34,359,368 32,162,175 2,197,193 68,030 2,265,223
12 Oter Powr Supply 2.9 1,199,378,442 1,119,244,504 80,133,939 58,348,546 138,482,484
13 Transmisson 2.10 154,194,872 144,331,053 9,863,819 338,791 10,202,611
14 Distrbuton 2.12 221,340,872 210,736,037 10,60,835 86,931 10,691,766
15 Customer Accunting 2.12 95,457,786 91,184,366 4,273,420 56,392 4,331,812
16 Customer servce & Info 2.13 46,969,452 43,100,792 3,868,660 (2,049,903)1,818,757
17 5aes 2.13 0 °0 0 0
18 Administrtie & General 2.14 180,356,471 170,511,550 9,84,921 718,109 10,563,029
19
20 Total 0 & M Expense 2.14 2,787~04o.36ll_2,1O.s32,3Tl~~1I6.iQZ,j)91 57,559,689 -~~.!~?,-~-
21
22 Depreation 2.16 417,781,814 393,039,933 24,741,881 (1,941,351)22,800,530
23 Amotion 2.17 64,157,451 60,972,032 3,185,419 128,110 3,313,529
24 Taxes Oter Thn Inc 2.17 101,472,747 96,815,682 4,657,065 630,882 5,287,947
25 Incme Taxs. Fedral 2.20 148,n4,136 144,680,895 4,093,241 (931,551)3,181,690
26 Inc Taxes - State 2.20 23,057,920 22,453,653 60,267 22,008 626,275
27 Incoe Tax . Def Net 2.19 79,627,843 76,910,663 2,917,180 1,552,166 4,469,346
28 Investnt Tax Creit Adj.2.17 (5,854,860)(5,109,951)(744,909)°(744,90)
29 Mise Revenue & Expense 2.4 (11,343,723)(10,616,925)(726,798)564,190 (162,608)
30.31 Total Operating Expeses 2.20 3,60,913,696 3,369,978,358 214,935,337 57,584,143 272,519,481
32
33 Operating Revenue fo Return 637,367,664 606,506,606 30,661,056 10,178,845 41,039,902
34
35 Rat Base:
36 Ele Plant in service 2.30 15,787,758,656 14,847,900,714 939,857,942 67,158,381 1,007,016,323
37 Plnt Helc for Future Use 2.31 8,529,582 8,071,181 458,401 (458,401)°
38 Mise Deferr Debits 2.33 120,693,483 116,888,233 3,805,249 189,304 3,994,553
39 Ele Plant Acq Adj 2.31 74,565,289 69,797,032 4,768,257 0 4,768,257
40 Nuclear Fuel 2.31 0 0 0 0 0
41 Prepaents 2.32 37,262,181 35,014,677 2,247,505 °2,247,505
42 Fuel Sto 2.32 88,485,802 82,682,617 5,803,185 1,056,514 6,859,699
43 Materil & Supplies 2.32 139,617,944 130,950,068 8,667,876 0 8,667,876
44 Workin Capital 2.33 82,743,141 78,485,539 4,257,602 (540,010)3,717,592
45 Weatherition Loans 2.31 11,821,982 5,690,076 6,131,906 0 8,131,90
46 Micellaneos Rate Base 2.34 5,994,104 5,529,710 46,394 °464,394
47
48 Total Elecc Plant 16,357,472,163 15,381,009,847 976,462,317 67,405,787 1,043,868,104
49
50 Rate Base Deuctons:
51 Accm Pro For Depr 2.38 (6,053,908,945)(5,679,545,496)(374,363,449)1,207,720 (373,155,729)
52 Accm Prov For Amor 2.39 (391,421,787)(369,745,202)(21,676,585)107,739 (21,568,846)
53 Accm Def Ince Taxes 2,35 (1,274,447,966)(1,191,981,116)(82,466,850)(852,704)(83,319,555)
54 Unamortze rrc 2.35 (11,355,352)(11,301,125)(54,227)(62,633)(116,859)
55 Customer Adv for Const 2.34 (13,914,n5)(13,768,896)(145,880)(239,120)(384,99)
56 Customer Serice Deposits 2.34 0 0 0 °0
57 Mis. Rate Base Deducons 2.34 (76,494,100)(72,052,183)(4,441,918)(3,309,869)(7,751,787)
58
59 Total Rate Base Deuctions (7,821,542,925)(7,338,394,017)(483,148,908)(3,148,667)(486,297,n5)
60
61 Totl Rate Base 8,535,929,238 8,042,615,830 493,313,409 64,256,921 557,570,329
62
63 Retum on Rate Base 7.467%6.256%7.360%
64
65 Retur on Equity 8.730%6.279%8.515%
.::Net Powr Costs 940,860,037 62,679,194 65,978,995
100 Basis Points in Equity:
68 Revenue Requirement Impa 67,958,372 3,927,490 4,439,068
69 Rate Base Decease (529,683,729)(36,103,917)(35,067,813)
REVSED PROTOCOL Page 2.3
Beglnnlngndlng
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT AOJTOTAL.70 Sales to Ultmate Customers
71 440 Residential sales
72 °S 1,263,790,934 1,214,263,337 49,527,597 7,88,534 57,412,131
73
74 81 1,263,790,934 1,214,263,337 49,527,597 7,884,534 57,412,131
75
76 442 Commercal & Industral Sales
77 °S 1,928,738,024 1,794,308,878 134,429,145 8,659,446 143,086,592
78 P SE
79 PT SG
80
81
82 81 1,928,738,024 1,794,308,878 134,429,145 8,659,446 143,088,592
83
84 44 Public Strt & Highwy Ughtng
85 °S 18,902,690 18,659,599 243,091 200,986 44,On
86 °SO
87 81 18,902,690 18,659,599 243,091 200,986 444,071
88
89 445 Other Sales to Pubic Autri
90 °S 17,509,459 17,509,459
91
92 81 17,509,459 17,509,459
93
94 448 Interdepartental
95 DPW S
96 GP SO
97 81
98
99 Totl Saes to Ultmat Customers 81 3,228,941,107 3,04,741,273 184,199,833 16,744,967 200,94,800
100
101
102
103 447 sales fo Resale-Non NPC
104 WSF S 7,616,288 7,616,288~05 7,616,288 7,616,288
:106
07 447NPC sales for Resale-NPC
108 WSF SG 862,870,229 807,691,912 55,178,318 48,64,339 103,822,657
109 WSF SE (13,621,886)(12,724,499)(897,187)897,187
110 WSF SG
111 849,248,543 794,967,413 54,281,130 49,541,526 103,822,657
112
113 Tot Sales fo Resale 81 85,864,831 802,583,701 54,281,130 49,541,526 103,822,657
114
115 449 Provision for Rate Refund
116 WSF S 3 3
117 WSF SG
118
119
120 81 3 3
121
122 Totl Salei frm Electrcity B1 4,085,805,940 3,847,324,977 238,480,964 66,286,493 304,767,457
123 450 Forfited Discunts & Interest
124 CUST S 6,784,670 6,416,032 36,639 368,639
125 CUST SO
126 81 6,784,670 6,416,032 368,639 368,639
127
128 451 Misc Elecc Revenue
129 CUST S 7,204,337 7,062,014 142,323 142,323
130 GP SG
131 GP SO 10,908 10,259 649 849
132 81 7,215,245 7,072,273 142,972 142.972
133
134 453 Water Sales
135 P SG 107,480 100,607 6,873 6,873
136 81 107,480 100,607 6,873 6,873
137
138 454 Rent of Elecc Propert
139 DPW S 12,809,490 12,473,816 335,675 335,675.40 T SG 5,274,071 4,936,813 337,264 337,264
141 GP SO 6n,192 636,878 40,314 40,314
42 81 18,760,759 18,047,507 713,252 713,252
143
144
REVED PROTOCOL Page 2,4
BeginninglEnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADTOTAL.45
146 456 Oter Ele Revenue
47 DMSC S 28,947,692 28,946,013 1,679 1,679
148 CUST CN
149 OTHSE SE 15,573,968 14,548,195 1,025,774 61,176 1,086,949
150 OTHSO SO 244,061 229,532 14,529 14,529
151 OTHSGR SG 78,841,54 73,799,831 5,041,713 1,415,320 6,457,033
152
153
154 B1 123,607,265 117 ,523,571 6,083,694 1,476,496 7,560,190
155
156 Totl Oter Electrc Revenues B1 156,475,419 149,159,989 7,315,430 1,476,496 8,791,926
157
158 Totl Electrc Operating Revenues B1 4,242,281,360 3,996,484,966 245,796,394 67,762,989 313,559.383
159
160 Summary of Revenues by Factr
161 S 3,292,303,586 3,107,255,438 185,048,148 16,744,967 201,793,115
162 CN
163 SE 1,952,282 1,823,696 128,586 958,363 1,086,949
164 SO 932,162 876,869 55,492 55,492
165 SG 947,093,330 886,529,163 60,56,167 50,059,659 110,623,826
166 DGP
167
168 Total Ele Opetig Revenues 4,242,281,360 3,996,484,966 245,796,394 67,762,989 313,559,383
169 Miscllaneos Revenues
170 41160 Gain on Sale of Utilit Plant. CR
171 DPW 5
172 T SG
173 G SO
174 T SG
175 P SG
176 B1
177
178 41170 Los on Sale of Utility Plant.:DPW 5
T SG
81 B1
182
183 4118 Gain fr Emisio Allownces
184 p 5
185 P SE
r4,863.498l
(13,897,692)(965,806)792,529 (173,27D
186 B1 14,663,498 (13,697,692ì (965,806)792,529 (173,277)
187
188 41181 Gain frm Disposition of NOX Creit
189 P SE
190 B1
191
192 4194 Impact Housing Interest Incoe
193 P SG
194 B1
195
196 421 (Gain) I Loss on Sale of Utility Plant
197 DPW 5 (706,221)(706,221)
198 T SG
199 T SG
200 PTD CN
201 PTD SO 4,175,98 3,927,384 248,600 (229,516)19,08
202 P SG (149,988)(140,396)(9,591)1,177 (8,415)
203 B1 3,319,775 3,080,767 239,008 (228,339)10,669
204
205 Totl Mlscellaneo Revenues (11,34,723)(10,616,925)(726,798)56190 (162,608)
206 Miscllaneous Expeses
207 4311 Interst on Customer Deposit
208 CUST 5
209 B1
210 Totl Miscellaneous Expenses
211
212 Net Mlsc Revenue and Expense B1 (11,34,723)(10,616,925)(726,798)56,190 (162,608)
213.
REVISED PROtOCOL page 2,5
BeginningEnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT OESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.14 500 Operaio Supervision & Enginenng
15 P SG 20,195,720 18,90,256 1,291,464 103,048 1,394,512
16 P SSGCH 1,310,396 1,233,955 76,441 (404)76,36
217 82 21,506,117 20,138,212 1,367,905 102,643 1,470,548
218
219 501 Fue Related-Non NPC
220 P SE 12,819,982 11,975,599 84,383 959 845,342
221 P SE
222 P SE
223 P SSECT
224 P SSECH 1,762,999 1,656,485 106,514 106,514
225 82 14,582,982 13,632,084 950,898 959 951,857
226
227 501NPC Fuel Related-NPC
228 P SE 516,191,536 482,192,770 33,998,767 (329,706)33,669,061
229 P SE
230 P SE
231 P SSECT
232 P SSECH 50,403,877 47,358,848 3,045,229 330,36 3,375,665
233 82 56,595,413 529,551,417 37,043,996 730 37,044,726
234
235 Totl Fue Related 581,178,395 543,183,501 37,994,894 1,689 37,996,583
236
237 502 Stem Exnses
238 P SG 31,714,301 29,686,254 2,028,047 2,028,047
239 P SSGCH 2,053,090 1,933,324 119,765 119,765
240 82 33,767,391 31,619,578 2,147,813 2,147,813
241
242 503 Stem From Other Sourcs-Non-NPC
243 P SE
244 82
245
246 503NPC Steam Fro Otr Sorcs-NPC
247 P SE 4,845,079 4,525,960 319,119 (113,540)205,519
248 82 4,845,079 4,525,960 319,119 (113,540)205,579.49
50 505 Elec Expenses
51 P SG 2,687,282 2,515,437 171,845 171.845
252 P SSGCH 1,320,614 1,243,577 77,037 77,037
253 82 4,007,896 3,759,14 248,882 248,882
254
255 506 Mi Steam Exnse
256 P SG 40.241,240 37,667,916 2,573,323 2,573,323
257 P SE
258 P SSGCH 1,603,350 1,509,820 93,530 93,530
259 82 41,84,590 39,177,736 2,666,853 2,66,853
260
261 507 Rents
262 P SG 743,38 695,522 47,515 47,515
263 P SSGCH 116,165 109,389 6,776 6,776
26 82 859,203 804,911 54,292 54,292
265
266 510 Maint Supeision & Engineenng
267 P SG 4,413,141 4,130,932 282,209 282,209
268 P SSGCH 1,786,866 1,682,631 104,235 104,235
269 82 6,200,007 5,813,563 386,444 386,444
270
271
272
273 511 Maintenance of Structres
274 P SG 21,651,22 20,26,869 1,384,552 1,384,552
275 P SSGCH 862,871 812,536 50,335 50,335
276 82 22,514,293 21,079,405 1,434,887 1,434,887
277
278 512 Maintenance of Boiler Plant
279 P SG 90,472,543 84,687,058 5,785,485 5,785,485
280 P SSGCH 3,997,568 3,764,373 233,195 233,195
281 82 94,470,112 88,451,432 6,018,680 6,018,680
282
283 513 Maintenance of Elecnc Plant.84 P SG 31,041,437 29,056,417 1,985,020 1,985,020
85 P SSGCH 797,219 750,714 46,505 46,505
86 82 31,838,656 29,807,131 2,031,525 2,031,525
287
286 514 Matenance of Misc. Steam Plant
289 P SG 9,395,338 8,794,530 600,808 600,808
290 P SSGCH 2,556,029 2,406,925 149,104 149,104
291 82 11,951,367 11,201,456 749,911 749,911
292
293 Totl Stem Power Generation 82 854,983,104 799,561,899 55,421,205 (9,208)55,411,998
REVSED PROTOCOL Page 2,6
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.94 517 Operation Super & Engineering
95 P SG
96 82
297
298 518 Nudear Fuel Exense
299 P SE
300
301 82
302
303 519 Conts and Water
30 P SG
305 B2
306
307 520 Steam Expenses
308 P SG
309 82
310
311
312
313 523 Elecc Exnses
314 P SG
315 B2
316
317 524 Mise. Nucear Exnses
318 P SG
319 82
320
321 528 Maintenan Super & Engineering
322 P SG
323 82
324
325 529 Mantnance of Strctres
326 P SG
327 82
328.29 530 Maintenance of Reactor Plant
30 P SG
31 82
332
333 531 Mainteanc of Ele Plant
334 P SG
335 B2
336
337 532 Maintenanc of Mise Nudear
338 P SG
339 B2
340
341 Tot Nuclear Power Generation B2
342
343 535 Operation Super & Enginering
34 P DGP
345 P SG 4,922,053 4,607,301 314,753 7,822 322,575
346 P SG 3,506,438 3,282,211 224,228 6,310 230,537
347
348 82 8,428,491 7,889,511 538,980 14,132 553,112
349
350 536 Wate For Powr
351 P DGP
352 P SG 146,556 137,184 9,372 9,372
353 P SG 70,232 65,741 4,491 4,491
354
355 82 216,788 202,925 13,863 13,863
356
.
REVISED PROTOCOL Page 2,7
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.57 537 Hyraulic Expenses
58 P DGP
59 P SG 4,299,292 4,024,364 274,929 274,929
360 P SG 406,674 380,668 26,00 26,00
361
362 B2 4,705,966 4,405,032 300,934 300,934
363
364 538 Eie Expenses
365 P DGP
366 P SG
387 P SG
368
369 B2
370
371 539 MI Hyro Exnses
372 P DGP
373 P SG 8,629,629 8,077787 551,842 59,684 611,526
374 P SG 6,507,896 6,091,733 416,163 (6,430)409,733
375
376
377 B2 15,137,525 14,169,520 968,006 53,254 1,021,259
378
379 540 Rents (Hydro Generation)
380 P DGP
381 P SG - - 34;r~-------"3-;--- -- ----"2,187--2,187
382 P SG 11,233 10,515 718 (6)713
363
384 B2 45,426 42,521 2,905 (6)2,899
38538 541 Malnt Supervision & Enginering
387 P DGP
388 P SG
389 P SG
390
391 B2.92
93 542 Mantenc of Strctures
94 P DGP
395 P SG 896,136 838,831 57,306 57,306
396 P SG 124,785 116,805 7,980 (41)7,938
397
398 B2 1,020,921 955,636 65,285 (41)65,244
399
400
401
402
403 543 Maintenance of Dams & Wateiys
404 P DGP
405 P SG 730,038 683,352 46,684 46,884
406 P SG 287,859 269,451 18,408 692 19,100
407
408 B2 1,017,895 952,803 65,092 692 65,784
409
410 54 Maitenance of Eletric Plant
411 P DGP
412 P SG 1,129,866 1,057,614 72,252 72,252
413 P SG 54,628 513,545 35,083 (0)35,083
414
415 B2 1,678,495 1,571,159 107,335 (0)107,335
416
417 545 Maintenance of Misc. Hyro Plant
418 P DGP
419 P SG 1,330,440 1,245,362 85,078 85,078
420 P SG 777,420 727,708 49,714 49,714
421
422 B2 2,107,860 1,973,068 134,792 134,792
423
424 Totl Hydraulic Power Generation B2 34,359,368 32,162,175 2,197,193 68,030 2,265,223
.
REVISED PROTOCOL
Page 2,8
Beglnninglndlng
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
.~546 Opetion Supe & Engineeng
P SG 729,753 683,087 46,66 (254)46,412
428 P SSGCT
429 82 729,753 683,087 46,666 (254)46,412
430
431 547 FueNonNPC
432 P SE
433 P SSECT
43 82
435
436 547NPC Fuel-NPC
437 P SE 261,141,972 243,941,952 17,200,020 7,422,257 24,622,277
438 P SSECT 64,695,537 59,689,603 5,005,934 (3,211,230)1,794,705
439 82 325,837,509 303,631,554 22,205,955 4,211,027 26,416,982
440
441 548 Generation Expense
442 P SG 11,819,366 11,063,54 755,818 3,496 759,314
443 P SSGCT 10,636,272 9,852,008 784,264 (588,321)195,943
44 82 22,455,638 20,915,556 1,540,082 (584,825)955,257
44544 549 Misclaneous Oter
447 P 50 5,931,466 5,552,164 379,302 577,080 956,382
448 P SSGCT
449 82 5,931,466 5,552,164 379,302 577,080 956,382
450
451
452
453
454 550 Rents
455 P SG 986,996 923,880 63,116 63,116
45 P SSGCT 10,977,690 10,168,251 609,439 (458,955)350,484
457 82 11,964,686 11,092,132 872,554 (458,955)413,600
458
459 551 Maint Supervision & Engineering.0 P SG
61 82
-i62
463 552 Maintenance of Structures
464 P SG 339,854 318,121 21,733 21,733
465 P SSGCT 276,119 255,760 20,360 (6,630)13,530
46 82 615,974 573,881 42,092 (6,830)35,262
487
468 553 Mat of Genration & Elec Plant
469 P SG 3,359,178 3,144,367 214,811 214,811
470 P SSGCT 1,271,491 1,177,738 93,753 (42,594)51,159
471 82 4,830,669 4,322,105 308,564 (42,594)265,970
472
473 554 Maintenance of Mise. Oter
474 P SG 113,448 106,194 7,255 7,255
475 P SSGCT 282,634 261,794 20,640 (10,075)10,785
476 82 396,083 367,988 28,095 (10,075)18,020
477
478 Total Oter Power Generation 82 372,561,778 347,138,468 25,423,310 3,884,575 29,107,885
479
480
481 555 Purchase Powr-Non NPC
482 DMSC S (22,499,508)(17,131,485)(5,388,023)5,368,023
483 (22,499,508)(17,131,485)(5,368,023)5,368,023
484
485 555NPC Purcased Powr-NPC
486 P SG 633,103,890 592,818,348 40,485,342 51,955,700 92,441,042
487 P SE 153,134,779 143,048,813 10,086,168 (4,246,324)5,839,842
488 sesonal Co P SSGC 691,568 691,588
489 DGP
490 786,238,469 735,868,960 50,571,509 48,400,964 98,972,472
491
492 Total Purcased Powr 82 783,738,961 718,535,475 45,203,486 53,768,987 98,972,472
493
...558 System Contrl & Load Dispat
495 P SG 2,535,081 2,372,969 182,112 182,112
96
497 82 2,535,081 2,372,969 162,112 162,112
496
499
REVSED PROTOCOL
Beginning/EndingFERC BUS
ACCT DESCmp FUNC Ref
UNADJUSTED RESULTSTOTAL OTHER IDAHO
Page 2,9
IDAHO
ADJUSTMENT ADJ TOTAL*~~2
503
504
505
506
507
508
509
510
511
512
513
514
515
516
517
518
519
520
521
522
523
524
525
526
527
528
529
530
531
532
533_34
35
36
537
538
539
540
541
542
54354
545
54
547
548
549
550
551
552
553
554
555
556
557
558
559
560
561
562
56356
565
56
567
568
,~
FACTOR
557 Ot Exnses
P
p
P
P
P
P
S
SG
SGCT
SE
SSGCT
TROJP
Embeed Cost DiferentialsCompany Owed Hyd P OGPCompany Ow Hyd P SGMid.C Contrct P MCMi-C Contrct p SGExstng OF Contr P SExsting OF Contrct P SG
Toml CHer Power Supp~
Toml Proucton Expense
Summary of Prouc Exnse by Facor
S
SG
SE
SNPPH
TROJP
SGCT
DGP
DEU
DEP
SNPPS
SNPPO
OGU
MC
SSGCT
SSECT
SSGC
SSGCH
SSECH
Total proucton Exse by Factor
560 Opetion Supervsion & EngineringT SG
561 Loa OÏ$patcingT SG
562 Station ExnseT SG
563 Overead Une ExpenseT SG
56 Underground Line ExpenseT SG
(183,792)
59,521,272
1,122,425
82,718
(150,819)
55,715,041
1,050,366
76,619
(32,973)
3,806,231
72,059
6,099
1,191,104
(292,808)
(3,311)
1,158,130
3,513,423
72,059
2,788
82 60,542,623
(92,090,202)
92,090,202
(38,943,305)
38,943,305
44,237,180
(44,237,180)
B2 826,816,664
196,159,705B22,088,720,914
21,553,880
1,092,151,261
948,133,348
1,122,425
(92,090,202)
(38,943,305)
23,526,925
64,695,537
82
16,404,169
52,166,876
2,088,720,914
56,691,207
(92,090,202)
88,201,272
(38,135,147)
38,452,981
43,485,808
(41,408,327)
(5,493,615)
772,106,036
1,950,968,518
26,203,504
1,022,311,014
885,664,892
1,050,366
(92,090,202)
(38,135,147)
21,792,170
59,689,603
15,447,245
49,015,133
1,950,968,578
3,851,417
5,888,930
(808,158)
2,490,324
751,372
(2,828,853)
5,493,615
54,710,629
137,752,336
(4,649,824)
69,840,246
62,448,456
72,059
(808,158)
1,734,755
5,005,934
956,924
3,151,743
137,752,336
894,984
54,663,970
58,407,369
6,559,127
52,414,292
2.733,64
(1,110,086)
(3,211,230)
691,588
(40)
330,436
58,407,369
4,746,400
5,888,930
(808,158)
2,490,324
751,372
(2,828,853)
5,493,615
109,374,599
1,909,503
122,254,539
65,182,102
72,059
(808,158)
624,669
1,794,705
691,588
956,520
3,482,179
196,159,705
8,207,350 527,8787,682,512 524,839 3,040
82 8,207,350 527,878
7,888,745
7,682,512
7,364,280
524,839
504,465
3,040
504,465
82 7,888,745 504,465
1,006,028
82 1,00,028
125,807
7,384,280
941,695
941,695
117,762
504,465
64,333
64,333
8,045
64,333
84,333
8,045
82 125,807 8,045117,762 8,045
82
.70
71
. 572
573
574
575
576
577
578
579
580
581
582
583
584
565
586
587
588
589
590
591
592
593
594
595
596
597
598
599
600
601
602
603
604.6:
07
606
609
610
611
612
613
614
615
616
617
616
619
620
621
622
623
624
625
626
627
628
629
630
631
632
633
634
635
636
637
638_639
840
41
42
843
REVISED PROTOCOL
Beginning/Ending
FERC
ACCT
585
BUS
DESCRIP FUNC FACTOR
Transmission of Elericity by OthersT SGT SE
565NPC Transmissio of Eleci by OtrsNPCT SGT SE
Total Transmissio of Electy by Others
566 Mise. Transmissio ExpenseT SG
567 Rents - TransmissionT SG
568 Maint Supervision & EngineeringT SG
569 Maintenc of Slietres
T SG
570 Maintnance of Station EquipmetT SG
571 Maintenanc of Overhead LinesT SG
572 Matenance of Underrond LinesT SG
573 Mat of Mise, Transmission PlantT SG
Totl Transmission Expense
Summary of Trasmission Expense by Factor
SE
SG
SNPT
Total Transmission Expense by Factor
580 Option Supervision & EngineeringDPW SDPW SNPD
581 Lo Dispatching
DPW
DPW
S
SNPD
582 Station Exnse
DPW
DPW
S
SNPD
Ref
UNADJUSTED RESULTSTOTAL OTHER IDAHO
Page 2.10
IDAHO
ADJUSTMENT ADJ TOTAL
104,789,310
1,802,800
106,592,110
82 106,592,110
2,751,804
82 2,751.804
1,358,267
98,088,305
1,684.059
99,772,365
6,701,005
118,741
6,819,746
455,146
(113,002)
342,146
7,156,154
5,739
7.161,892
7,161,89299,772,365 6,819.746 342,146
(6,395)
(6,395)
189,5762,575,833 175,971
169,576
86,730
82 1,356,267 86,730
82
56,234
56,234
82
3,233,567
3,233,567
9,272,545
2,575,833 175,971
3,596 3,596
3,596
1,269,538 86,730
3,596
206,778
206,778
592,955
82 9,272,545 592,955
1,269,538 86,730
13,323,841
52,638
52,638
3,028,789 206,778
852,025
82 13,323,841 852,025
3,026,789 20,778
82
8,679,590 592,955
380,572
8,679,590 592,955
24,337
338,791
24,337
10,202,611
82
82
380,572
154,194,872
1,802,800
152,392,072
154,194,872
82
197,509
19,530,509
19,728,019
82
12,861,549
12.661,549
82
3,361,261
14,696
3,375,957
12,471,816 852,025
12,471,816 852,025
356,235 24,337
356,235 24,337
144,331,053 9,863,819
1,684,059
142,646,994
144.331.053
118,741
9,745,079
-
9,863,819
236,002
18,629,976
18,865,978
(38,492)
90,533
862.041
12,077,737
12,077,737
583,812
583,812
3,187,322
14,018
3,201,340
173,939
678
174,616
(113,002)
451,793
338.791
5,739
10,196,872
10.202,611
16
(8,051)
(8,035)
(38,476)
892,461
854,006
7,584
7,564
591,376
591,376
1,861
9
1,870
175,799
687
176,486
REVISED PROTOCOL
Page 2.11
Beginninglndlng
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADJTOTAL.583 Overhad Line Expenses
DPW S 6,970,600 6,802,998 167,601 2,646 170,247
46 DPW SNPD 642,038 612,435 29,804 318 29,922
647 B2 7,612,638 7,415,433 197,205 2,963 200,168
648
649 584 Undrgrond Line Expense
650 DPW S 230,535 230,535
651 DPW SNPD
652 82 230,535 230,535
653
654 585 Strt Lighting & Signal Systems
655 DPW S
656 DPW SNPD 248,162 236,720 11,443 214 11,656
657 B2 248,162 236,720 11,443 214 11,656
658
659 586 Meter Expeses
660 DPW S 4,825,918 4,360,927 284,990 4,134 269,124
681 DPW SNPD 1,189,500 1,115,576 53,925 870 54,595
682 82 5,795,418 5,478,503 318,915 4,804 323,719
88368 587 Customer Installation Expnses
685 DPW S 9,337,558 8,702,201 635,356 10,072 845,429
686 DPW SNPD
867 B2 9,337,558 8,702,201 635,356 10,072 845,429
688
689 588 Mise Distrbution Expenses
870 DPW S 2,742,204 2,535,001 207,204 1,723 208,927
671 DPW SNPD 8,356,655 8,063,558 293,099 12,267 305,386
872 82 9,098,860 8,598,557 500,303 13,990 514,293
673
874 589 Rents
675 DPW S 3,921,526 3,872,496 49,029 58 49,088
878 DPW SNPD 388,405 351,418 16,987 18,987
6n 82 4,289,931 4,223,915 68,016 56 68,072.n
79 590 Maint Supervsion & Engineering
80 DPW S 543,078 520,148 22,928 353 23,281
681 DPW SNPD 5,959,341 5,884,562 274,779 4,228 279,007
682 82 6,502,417 6,204,710 297,707 4,581 302,288
883
884 591 Maintenance of Strures
685 DPW S 1,248,887 1,158,881 90,006 90,006
686 DPW SNPD 134,105 127,922 8,183 6,183
687 82 1,382,792 1,286,802 96,189 96,189
688
689 592 Maintenance of Statin Equipment
690 DPW S 9,975,463 9,621,888 353,n5 4,367 358,142
891 DPW SNPD 1,788,399 1,686,880 81,539 1,589 83,109
692 82 11,743,862 11,308,548 435,314 5,937 441,250
693 593 Mantenanc of Overhead Lines
894 DPW S 89,828,682 84,885,111 4,961,551 26,687 4,988,217
695 DPW SNPD 1,680,189 1,802,717 n,472 (752)76,719
896 82 91,506,851 68,467,828 5,039,022 25,914 5,084,937
697
898 594 Maintenanc of Underground Lines
699 DPW S 22,n2,712 22,023,721 748,990 8,492 757,482
700 DPW SNPD 28,951 27,616 1,335 14 1,349
701 82 22,801,663 22,051,337 750,325 8,508 758,831
702
703 595 Maintenance of Line Transformers
704 DPW S 80,888 80,888
705 DPW SNPD 884,278 852,724 31,551 196 31,147
706 82 744,96 713,412 31,551 196 31,747
707
708 596 Maint of Strt Lighting & Signal Sys.
709 DPW S 4,335,96 4,170,152 185,812 2,440 168,252
710 DPW SNPD
711 82 4,335,964 4,170,152 165,812 2,440 168,252
712.
REVSED PROTOCOL
Pag 2.12
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO AOJUSTMENT ADJTOTAL.13 597 Maintenance of Meters
14 DPW S 3,956,999 3,672,402 284,598 4,509 289,107
15 DPW SNPD 1,519,486 1,449,424 70,062 441 70,503
716 82 5,478,485 5,121,826 354,660 4,950 359,610
717
718 598 Maint of Mise. Distrbution Plant
719 DPW S 3,487,765 3,446,380 39,384 200 39,584
720 DPW SNPD 979,485 934,322 45,163 708 45,871
721 82 4,467,250 4,382,702 84,547 908 85,456
722
723 Total Distrbution Expense B2 221,340,872 210,736,037 10,604,835 86,931 10,691,766
724
725
726 Summary of Dibun Exnse by Facor
727 S 167,595,125 159,468,455 8,126,671 67,537 8,194,207
728 SNPD 53,745,741 51,267,583 2,478,184 19,395 2,497,559
729
730 Total Distrbut Exse by Factor 221,340,87 210,736,037 10,604,635 86,931 10,691,766
731
732 901 Suprvisi
733 CUST S 262,967 252,m 10,689 169 10,859
734 CUST CN 2,493,732 2,392,393 101,339 94 102,283
735 82 2,756,699 2,844,670 112,029 1,113 113,142
736
737 902 Me Reading Expense
738 CUST S 27,323,838 25,747,110 1,576,728 19,283 1,596,010
739 CUST CN 84,132 809,829 34,303 277 34,581
740 82 28,167,970 26,556,939 1,611,031 19,560 1,630,591
741
742 903 Customr Recipts & Collecions
743 CUST S 6,419,019 8,191,137 227,882 3,519 231,401
744 CUST CN 49,188,818 47,189,905 1,998,914 1,595 2,000,508
745 82 55,607,837 53,381,042 2,226,795 5,114 2,231,909
748
747 904 Uncoleible Accunts.48 CUST S 9,383,54 9,022,016 341,28 341,528
49 P SG
50 CUST CN (812,507)(79,489)(33,018)32,510 (508)
751 82 8,551,037 8,242,527 308,510 32,510 341,020
752
753 905 Mise, Customer Accnts Expense
754 CUST S 3,768 3,768
755 CUST CN 370,476 355,420 15,055 95 15,150
758 82 374,243 359,188 15,055 95 15,150
757
758 Totl Custoer Accounts Expense 82 95,457,786 91,184,366 4,273,420 58,392 4,331,812
759
760 Summary of Custoer Acc Exp by Factr
761 S 43,373,135 41,216,309 2,156,827 22,971 2,179,798
762 CN 52,084,650 49,988,057 2,116,593 35,421 2,152,014
763 SG ...
784 Total Customer Accnts Expense by Factor 95,457,786 91,184,366 4,273,420 58,392 4,331,812
765
766 907 Supervsion
767 CUST S
768 CUST CN 423,544 406,332 17,212 174 17,386
769 82 423,544 406,332 17,212 174 17,386
no
n1 90 Custo Assistance
772 CUST S 38,718,172 35,171,471 3,546,701 (2,042,021)1,504,680
n3 CUST CN 4,038,065 3,873,968 164,097 1,520 185,811
774
775
776 82 42,756,237 39,045,439 3,710,798 (2,040,501)1,670,297
m
.
REVISED PROTOCOL Page 2.13
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.:909 Infoatal & Instrctional Adv
CUST S 629,957 618,253 11,705 (8,280)3,424
80 CUST CN 3,154,588 3,026,394 128,195 (1,29)126,898
781 82 3,784,546 3,64,646 139,899 (9,577 130,323
782
783 910 Misc. Customer serv
784 CUST S 2,000 1,376 624 624
785 CUST CN 3,126 2,999 127 127
786
787 82 5,126 4,375 751 751
788
789 Totl Customer Service Expense B2 46,969,462 43,100,792 3,868,660 (2,04,903)1,818,757
790
791
792 Summiyof Custoer Serice Ex by Factor
793 S 39,350,128 35,791,099 3,559,029 (2,050,301 )1,508,728
794 CN 7,619,324 7,309,693 309,631 398 310,029
795
796 Totl Customer se Exnse by Facor 82 46,969,452 43,100,792 3,868,660 (2,049,903)1,818,757
797
798
799 911 Supervsion
800 CUST S
801 CUST CN
802 B2
803
804 912 Deonstrti & Selling Expense
805 CUST S
806 CUST CN
807 82
808
809 913 Advrtsing .Expense
810 CUST S
811 CUST CN
812 82.13
14 916 Mise Sales Expese
15 CUST S
816 CUST CN
817 82
818
819 Tot Sales Expense 82
820
821
822 Totl Sales Exse by Factor
823 S
824 CN
825 Total Sales Expese by Factor
826
827 Totl Custmer Service Exp Including Sales B2 46,969,462 43,100,792 3,868,660 (2,049,903)1,818,757
828 920 Administrtive & General Salaries
829 PTD S 351,795 351,795
830 CUST CN
831 PTD SO 82,949,771 78,011,705 4,938,066 (202,556)4,735,510
832 82 83,301,566 78,363,500 4,938,066 (202,556)4,735,510
833
834 921 Of Supplies & expenses
835 PTO S (937,464)(938,909)1,425 (1,264)161
836 CUST CN
837 PTO SO 12,717,213 11,96,147 757,066 (37,968)719,098
838 82 11,779,729 11,021,238 758,491 (39,232)719,259
839
840 922 A&G Expenses Transferred
841 PTO S
842 CUST CN
843 PTO SO (20,697,8051 (19,465,648)(1,232,157)37,639 (1,194,518)
64 82 (20,697,805 (19,465,648)(1,232,157)37,639 (1,194,518)
845.
REVISED PROTOCOL Page 2,14
Beginningndlng
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.!923 Outside Services
PTD 5 40,783 40,783
CUST CN
849 PTO 50 9,759,436 9,178,449 580,967 (6,156)574,831
850 B2 9,800,219 9,219,232 580,987 (6,156)574,831
851
852 924 Propert Insurance
853 PTD 50 24,516,013 23,056,555 1,459,458 1,459,458
854 B2 24,516,013 23,056,555 1,459,458 1,459,458
855
856 925 Injuries & Damages
857 PTD 50 11,291,287 10,619,108 672,179 672,179
858 B2 11,291,287 10,619,108 672,179 872,179
859
860 926 Empl Pensions & Benefits
861 LABOR 5
862 CUST CN
863 LABOR 50
864 B2
865
866 927 Franchise Requirements
867 OM5C 5
868 OMSC 50
869 B2
870
871 928 Regulatory Commission Expense
872 DM5C 5 8,088,821 7,760,056 328,764 328,764
873 CU5T CN
874 OM5C 50 407 383 24 24
875 FERC SG 1,922,411 1,799,478 122,933 (150,503)(27,570)
876 B2 10,011,639 9,559,918 451,722 (150,503)301,218
877
878 929 Duplicte Charges
879 LAOR 5
...LABOR 50 ~5,845,340l (5,497,362)(347,978)(619)(348,596)
881 B2 5,845,340 (5,497,362ì (347,978)(619)(348,596)
82
83 930 Mi Generl Expenses
884 PTD 5 12,190,297 12,189,673 624 171,936 172,560
885 CU5T CN 5,724 5,491 233 233
886 LA80R 50 13,372,148 12,576,093 796,055 90,102 1,700,157
887 82 25,568,169 24,771,257 796,911 1,076,038 1,872,950
888
889 931 Rents
890 PTO S 902,697 902,697
891 PTD 50 5,389,807 5,068,948 320,860 320,860
892 82 6,292,504 5,971,645 320,860 320,860
893
894 935 Maintenance of Genral Plant
895 G 5 42,149 42,149
896 CU5T CN
897 G 50 24,29,341 22,849,960 1,446,381 3,498 1,449,879
898 B2 24,338,489 22,892,108 1,44,381 3,498 1,449,879
89990 Total Administrtive & General Expense B2 180,356,471 170,511,550 9,84,921 718,109 10,563,029
901
902 Summary of A&G Expense by Factor
903 5 20,679,057 20,348,243 330,814 170,672 501,485
90 SO 157,749,278 148,358,337 9,390,941 697,940 10,088,881
905 5G 1,922,411 1,799,478 122,933 (150,503)(27,570)
906 CN 5,724 5,491 233 233
907 Totl A&G Expese by Facr 180,356,471 170,511,550 9,844,921 718,109 10,563,029
908
909 Total O&M Expense 82 2,787,040,368 2,610,832,317 176,207,991 57,559,689 233,767,680
~
REVseD PROTOCOL.
Page 2.15
BeginningEnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.!403SP Stem Depration
P SG 37,507,935 35,109,400 2,398,535 2,398,535
P SG 40,335,873 37,756,498 2,579,375 2,579,375
913 P SG 80,606,591 56,730,956 3,875,835 (2,885,967)1,189,668
914 P SSGCH 9,113,517 8,581,887 531,830 (80,450)451.180
915 B3 147,563,915 138,178,741 9,385,174 (2,788,417)8,818,758
916
917 403NP Nucear Depation
918 P SG
919 B3
920
921 403HP Hyro Deecation
922 p SG 4,979,312 4,660,898 318,414 318,414
923 P SG 1,187,400 1,111,489 75,931 75,931
924 P SG 5,278,568 4,939,145 337,423 37,819 375,242
925 P SG 1,477,963 1,383,451 94,512 105,345 199,857
926 83 12,921,243 12,094,963 826,280 143,185 989,445
927
928 4030P Oter Proucton Depreatin
929 P SG 39,783 37,239 2,54 2,54
930 P SG 29,280,267 27,407,870 1.872,397 1,124,154 2,996,552
931 P SSGCT 3,181,554 2,928,438 233,117 (42,875)190,241
932 P SSGCH
933 83 32,481,604 30.373,548 2,108,058 1,081.279 3.189,337
934
935 403TP Trasmission Depreiaton
936 T SG 12,270,765 11,486,082 784,884 784,684
937 T SG 13,361,846 12,507,203 854,443 854,443
938 T SG 31,738,237 29,708,859 2,029,578 (13,687)2,015,891
939 83 57,370,648 53,701,943 3,888,704 (13,687)3,855.017
940
941
942
943 403 Disbu Dereation
94 36 La, La Rl DPW S 274,805 257,33 17,469 17,469
.~361 si DPW S 933,033 918,355 14,878 14,878
36 Sl Eq DP S 14,029,409 13,854,855 374,754 374,754
363 -,IIEqDPW S 142,101 142,101
94 36 PoI & T-. DPW S 34,352,246 32,283,440 2,068,808 (237,774)1,831,032
949 365 OH CO DPW S 18,53,844 15.848,882 881,962 881,982
950 38 UGe:DPW S 8,473,439 6,319,003 154,436 154,438
951 367 UG Co DPW S 13,788,826 13,327,754 461,073 481,073
952 388 UnT..DPW S 23,342,420 21,974,708 1,367,712 1,367,712
953 389 Sel DPW S 9,972,443 9,438,983 533,480 533,480
954 370 Ma DPW S 8,471,780 6,014,806 456,974 456,974
955 371 InoCUI..DPW S 379,042 371,772 7,270 7,270
956 372 ~I'DPW S 1,293 1,166 127 127
957 373 -lJ DPW S 2,373,814 2,341,318 32,296 32,296
958 B3 129,065,095 122,894,059 8,371,038 (237.774)8.133,282
95996 403GP Geral Depeciatin
961 G-SITUS S 12,940,217 12,073,438 888,780 (89,186)777,594
962 G-DGP SG 489,209 439,204 30,005 30,005
963 G-DGU SG 807,218 755,597 51,619 51,819
96 P SE 37,803 35,128 2,477 (39)2,438
965 CUST CN 1,384,927 1,328.847 58,280 (2,825)53,455
968 G-SG SG 4,911,245 4,597,183 314,061 (29,882)284,179
967 PTD SO 17,841,227 18,591,030 1,050,198 (27,880)1,022,517
968 G.SO SSGCT 18,958 15,708 1,250 (38)1,212
969 G-G SSGCH 170,708 180,750 9,958 (872)9,088
970 83 38,379,310 35,996,882 2,382,828 (150.523)2,232,105
971
972 403GVO Genel Vehicls
973 G-G SG
974 B3
975
976 403MP Mining Depreation
977 P SE 2.808 2,808
978 83 2,808 2,608
em
REVISED PROTOCOL Page 2,16
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAl.80 403EP Exrimental Plant Deprecation
981 P SG
82 P SG
. 983 83
984 4031 ARO Depreation
985 P S
986 83
987
988
989 Total Depreiation Expense B3 417,781,814 393,039,933 24,741,881 (1,941,351)22,800,530
990
991 Summary 5 142,005,312 134,767,495 7,237,817 (326,960)6,910,856
992 OGP
993 OGU
994 SG 15,619,156
995 SO 1,050,196
996 CN 56,280
997 SE 2,477
998 SSGCH 541,588
999 SSGCT 234,367
100 Totl Deprtion Expse By Factor ' 41,881
1001
1002 404GP Amrt of L T Plant - Capil Lease Gen
1003 I-SITUS S 967,674 967,674
1004 I-G SG
1005 PTO SO 1,708,800 1,607,074 101,726 101,728
1006 I-DGU SG
1007 CUST CN 232,427 222,982 9,445 9,44
1008 I-DGP SG
1009 84 2,908,901 2,797,730 111,172 111,172
1010
1011 40SP Amo of L T Plant - Cap Lease Steam
1012 P SG
1013 P SG
1014 B4.015
016 4041P Amort of L T Plat - Intangible Plant
017 I-ITUS 5 38,191 17,790 20,401 20,401
1018 P SE 3,711 3,486 244 244
1019 I-G SG 6,479,693 6,065,334 414,360 414,360
1020 PTO SO 28,791,417 27,077,441 1,713,976 (3,765)1,710,211
1021 CUST CN 4,849,670 4,652,591 197,079 197,079
1022 I.SG SG 2,057,084 1,925,539 131,545 194,457 326,013
1023 I-SG SG 309,688 289,884 19,804 19,804
1024 1-0GP SG
1025 I-G SSGCT
1026 I-SG SSGCH 5,777 5,440 337 337
1027 I-OGU SG 17,884 18,740 1,144 1,144
1028 B4 42,553,115 40,054,225 2,498,890 190,703 2,689,592
1029
1030 404MP Amort of L T Plant - Mining Plant
1031 P SE
1032 B4
.1033
1Ò34 4040P Amort of L T Plant - Ot Plant
1035 P SSGCT 293,921 272,249 21,672 (12,705)8,967
1036 B4 293,921 272,249 21,672 (12,705)8,967
1037
1038
1039 404HP Amortzation of Other Elecc Plant
1040 P SG 2,284 2,138 146 146
1041 P SG 38,242 35,797 2,445 2,445
1042 P SG
1043 B4 40,526 37,935 2,592 2,592
104
1045 Total Amortzation of Umit Term Plant B4 45,796,464 43,162,139 2,634,325 177,998 2,812,322
1046
1047
1048 405 Amortzation of Oter Electc Plant
_:GP 5
051 B4
052
REVSED PROTOCOL
Page 2.17
Beinning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.53 406 Amrtzall of Plant Acquisition Adj
54 P S
055 P 5G
1056 P 5G
1057 P 5G 5,479,353 5,128,962 350,390 350,390
1058 . P 50
1059 54 5,479,353 5,128,962 350,390 350,390
106 407 Amo of Pro Loss, Unre Plant, etc
1061 DPW 5 9,752,248 9,752,248
1062 GP 50
1063 P 5G-P 780,128 730,240 49,887 49,887
106 P 5E
1065 P 5G 333,105 311,803 21,301 (49,887)(28,588)
106 P TROJP 2,016,153 1,888,638 129,515 129,515
1067 54 12,881,634 12,680,931 200,703 (49,887)150,816
1068
1069 Totl Amortzation Expese B4 64,157,451 60,972,032 3,185,419 128,110 3,313,529
1070
1071
1072
1073 Summary of Amorttion Exse by Facor
1074 5 10,758,114 10,737,713 20,401 20,401
1075 SE 3,711 3,466 244 244
1076 TROJP 2,016,153 1,886,638 129,515 129,515
1077 DGP
1078 DGU
1079 50 30,500,217 28,68,515 1,815,702 (3,765)1,811,938
1080 55GCT 293,921 272,249 21,672 (12,705)8,967
1081 55GCH 5,m 5,440 337 337
1082 CN 5,082,097 4,875,573 20,524 206,524
1083 5G 14,717,333 13,776,197 941,135 144,580 1,085,716
1084 Totl Amotin Exnse by Factor 63,371,323 60,241,92 3,135,532 128,110 3,263,642
1085 408 Taxes Other Than Income
1086 DMSC 5 23,301,297 23,301,297
t~GP GPS 89,102,426 84,988,703 4,113,723 830,882 4,744,605
088 GP 50 8,523,359 8,015,957 507,402 507,402
089 P 5E 545,68 50,724 35,940 35,940
090 P 5G
1091 DMSC OPRV-ID
1092 GP EXCTAX
1093 GP 5G
109
1095
109
1097 Totl Taxes Oter Than Income B5 101,472,747 96,815,682 4,657,065 630,82 5,287,947
1098
1099
1100 41140 Deferr Investment Tax Creit - Fed
1101 PTD DGU (5,854,860)(5,109,951)(744,909)(744,909)
1102
1103 87 (5,854,860)(5,109,951)(744,909)(744,909)
1104
1105 41141 Derr investment Tax Credit - Idaho
1106 PTD DGU
1107
1108 87
1109
1110 Totl Deferr ITC B7 (5,854,860)(5,109,951)g44,909)(744,909)
1111
,
REVSED PROTOCOL
Page 2.18
BeginningEnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
.112
113 427 Interet on Long-Tenn Debt
114 GP S 3,114,498 3,114,498
1115 GP SNP 278,731,910 262,506,849 16,225,061 16,225,061
1116 B6 278,731,910 262,506,849 16,225,061 3,114,498 19,339,560
1117
1118 428 Amoiztion of Debt Disc & Exp
1119 GP SNP 7,864,485 7,218,333 44,152 44,152
1120 B6 7,66,485 7,218,333 446,152 446,152
1121
1122 429 Amozation of Premium on Debt
1123 GP SNP
156,884)
(55,457)(3,428)(3,428)
1124 B8 (55,457j (3,428)(3,428)58,884)
1125
1126 431 Othr Interst Exnse
1127 NUTIL OTH
1128 GP SO
1129 GP SNP 29,764,583 28,031,978 1,732,605 1,732,605
1130 B6 29,764,583 28,031,978 1,732,605 1,732,605
1131
1132 432 AFUOC - Bo
1133 GP SNP
128,853,980)
(26,986,024)(1,667,956)(1,667,956)
1134 28,653,980)(26,986,024)(1,667,956)(1,667,956)
1135
1136 Totl EIe Interet Deducons fo Tax B6 287,448,113 270,715,679 16,732,434 3,114,498 19,84,932
1137
1138 NonUtilit Poron of Interest
1139 427 NUTIL NUTIL
1140 428 NUTIL NUTIL
1141 429NUTL NUTIL
1142 431 NUTIL NUTIL
1143
1144 Totl Nonutlity Interest
1145
1146 Total Interet Deuctios fo Tax B6 287,448,113 270,715,679 16,732,434 3,114,498 19,846,932
.147
148
1149 419 Interet & Dividends
1150 GP S
1151 GP SNP 2,381,153)
1152 Tota Operating Deucons fo Tax B6 2,381,153)
1153
1154
1155 41010 Dete Inc Tax - Federal-DR
1156 GP S 362,440,419 348,567,360 13,873,059 6,042 13,879,101
1157 P TROJO 14,659 13,717 942 942
1158 PT OGP 2,438 2,438
1159 LABOR SO 35,789,683 33,659,094 2,130,589 (60,334)2,070,254
1160 GP SNP 21,316 20,075 1,241 1,241
1161 P SE 7,127,368 6,657,927 469,441 65,760 535,202
1162 PT SG 7,668,825 7,178,423 490,402 (7,884)412,517
1163 GP GPS 1,001 941 60 60
1164 DITEXP orrxp 1,847,457 1,847,457
1165 CUST BAOOEBT 1,887,380 1,819,286 68,094 68,094
1166 CUST CN 23,817 22,849 968 968
1167 P IBT 121,199 118,023 3,176 3,176
1168 OPW SNPO
1169 B7 415,098,105 398,060,133 17,037,972 1,781,041 18,819,012
1170
.
RESED PROTOCOL Pag 2,19
Belnnlnglndlng
FERC BUS UNADJUSTED RESULTS IDAH
AceT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADUSTMENT ADJTOTAL.71
72
173 41110 Derr Income Tax - Federal-CR
1174 GP S (290,988,771)(279,583,593)(11,405,178)145,221 (11,259,957)
1175 P SE (7,430,238)(6,94,848)(489,390)(366,533)(855,923)
1176 PT DGP (300,173)(300,173)
11n GP SNP (1,765,373)(1,662,610)(102,763)(102,763)
1178 PT SG (11,033,420)(10,327,861)(705,559)(84,425)(769,983)
1179 GP GPS (531,558)(499,914)(31,64)(31,64)
1180 LABOR SO (22,243,997)(20,919,794)(1,324,203)56,862 (1,267,341)
1181 PT SNPD (38,879)(37,086)(1,793)(1,793)
1182 CUST CN
1183 P SGCT (356,221)(333,352)(22,869)(22,869)
1184 DITEXP DITEXP
1185 P TROJD (581,63)(54,239)(37,393)(37,393)
1186 P SSGCH
1187
1188
1189 87 (335,270,262)(321,149,471)(14,120,792)(228,874)(14,349,666)
1190
1191 Totl Deferr Income Taxes B7 79,827,843 76,910,663 2,917,180 1,552,166 4,469,346
1192 SCHMAF Addits - Flow Throh
1193 SCHMA S
1194 SCHMAF SNP
1195 SCHMAF SO
1196 SCHMAF SE
.1197 SCHMAF TROJP
1198 SCHMAF SG
1199 86
1200
1201 SCHMAP Aditns - Peranent
1202 P S
1203 P SE 87,039 81,306 5,733 5,733
1204 LABOR SNP 1,09,54 1,032,714 63,830 63,830
1205 SCHMAP-SO SO 11,167,890 10,503,057 66,833 684,833
.206 SCHMAP SG 119,015 111,404 7,611 7,611
207 DPW BADDE8T
208 86 12,470,488 11,728,481 742,007 742,007
1209
1210 SCHMAT Additions. Tempory
1211 SCHMAT-SITS S 29,272,039 28,462,675 809,384 (382,653)426,711
1212 P SSGCH
1213 DPW CIAC 65,638,740 62,612,202 3,026,538 3,026,538
1214 SCHMAT-SNP SNP 60,n1,286 57,233,n3 3,537,513 3,537,513
1215 P TROJD 1,532,586 1,434,056 98,530 98,530
1216 P SG
1217 SCHMAT-SE SE 19,578,509 18,288,978 1,289,531 965,806 2,255,337
1218 P SG 28,819,660 26,976,717 1,842,943 169,757 2,012,700
1219 SCHMAT-GPS GPS 1,400,64 1,317,284 83,382 83,382
1220 SCHMAT-SO SO 15,680,298 14,746,837 933,461 933,461
1221 SCHMAT-SNP SNPD 29,370,967 28,016,700 1,354,267 1,354,267
1222 CUST CN
1223 P SGCT 938,633 878,373 60,260 60,260
1224 BOOKDEPR SCHMDEXP 495,661,101 46,307,052 29,354,049 (1,265,966)28,088,083
1225 B6 748,684,466 706,274,628 42,389,838 (513,056)41,876,782
1226
1227 TOTAL SCHEDULE. M ADDITONS Be 761,134,953 718,003,108 43,131,845 (513,056)42,618,789
1228
.
REVISED PROTOCOL Page 2.20
Beglnninglndlng
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.9 SCHMDF Deuctons. Flow Through
30 SCHMDF S
231 SCHMDF DGP
1232 SCHMDF DGU
1233 B6
1234 SCHMDP ~ons. Pennnem
1235 SCHMDP S
1236 P SE 4,395,479 4,105,973 269,507 289,507
1237 PTO SNP 381,063 358,882 22,182 22,182
1238 SCHMDP IBT
1239 P SG 10,900,494 10,203,435 697,058 697,058
1240 SCHMDP-SO SO 25,050,142 23,558,887 1,491,255 1,491,255
1241 B6 40,727,178 38,227,176 2,500,002 2,500,002
1242
1243 SCHMDT Deucns. Tempory
1244 GP S 68,145,601 66,295,851 1,849,750 1,849,750
1245 DPW BADDEBT 4,973,203 4,793,777 179,426 179,426
1246 SCHMDT.SNP SNP 62,812,294 59,155,973 3,656,321 3,656,321
1247 SCHMDT CN 62,756 60,206 2,550 2,550
1246 SCHMDT TROJD 38,625 36,142 2,483 2,483
1249 CUST DGP 6,423 6,423
1250 P SE 22,94,826 21,435,441 1,511,38 173,27 1,684,661
1251 SCHMDT.SG SG 12,022,379 11,253,579 768,800 22,686 791,686
1252 SCHMDT.GPS GPS 66,940,561 62,955,536 3,985,025 3,985,025
1253 SCHMDT.SO SO 66,849,736 62,870,117 3,979,618 (9,209)3,970,410
1254 TAXDEPR TAXDEPR 604,113,141 568,336,344 35,776,797 5,324,116 41,100,913
1255 DPW SNPD
125 B6 908,911,545 857,199,389 51,712,156 5,511,070 57,223,226
1257
1258 TOTAL SCHEDULE. M DEDUCTIONS B6 949,638,723 895,426,565 54,212,158 5,511,070 59,723,228
1259
1260 TOTAL SCHEDULE. M ADJUSTMENTS B6 (188,503,770)(177,423,457)(11,080,313)(6,024,126)(17,104,439)
1261
1262
1263.=40911 State Ince Taxes
IBT IBT 23,057,920 22,453,653 604,267 76,401 680,868
266 IBT IBT
1267 REC P SG (54,393)(54,393)
1268 IBT IBT ....
1269 Totl State Tax Expenie 23,057,920 22,453,653 604,267 22,008 626,275
1270
1271
1272 Callation ofTax Inme:
1273 Operating Revenues 4,242,261,36 3,99,484,966 245,796,394 67,762,989 313,559,383
1274 Operating Deuctions:
1275 o & M Expeses 2,767,040,368 2,610,832,377 176,207,991 57,559,669 233,767,680
1276 Depreation Expense 417,781,814 393,039,933 24,741,881 (1,941,351)22,800,530
1277 ~~tin Expense 64,157,451 60,972,032 3,185,419 128,110 3,313.529
1278 Tax Oter Than Income 101,472,747 96,815,682 4,657,065 630,882 5,287,947
1279 Interest & Dividends (AFUDC.Equit)(40,90,060)(38,524,907)(2,381,153)(2,381,153)
1280 Mise Revenue & Exnse (11,343,723)(10,616,925)(726,798)564,190 (162,608)
1281 Totl Opeting Deducts 3,318,202,597 3,112,518,192 205,684,405 56,941,520 262,625,925
1282 Otr Deductons:
1283 Interet Deductons 287,448,113 270,715,679 16,732,434 3,114,498 19,846,932
1284 Interst on PCRBS
1285 Schedule M Adjustments (188,503,770)(177,423,457)(11,080,313)(6,24,126)(17,104,439)
1286
1287 Incme Before State Taxes 448,126,879 435,827,638 12,299,242 1,682,845 13,962,087
1288
1289 State Incoe Taxes 23,057,920 22,453,653 604,267 22,008 826,275
1290
1291 Total Taxable Income 425,068,959 413,373,985 11,694,975 1,660,837 13,355,811
1292
1293 Tax Rate 35,0%35.0%35.%35.0%35.0%
1294
1295 Federal Incme Tax . Calclated 148,774,136 144,680,895 4,093,241 581,293 4,674,534
1296
1297 Adjustments to Calclate Tax:
1298 40910 PMI P SE.299 40910 REC P SG (1,512,84)(1,512,84)
300 40910 P SO
301 40910 IRSS_LABOR S
1302 Federal Income Tax Expense 148,774,136 144,680,895 4,093,241 (931,551)3,161,690
1303
1304 Totl Operatlng Expenses 3,604,913,696 3,389,978,358 214,935,337 57,584,143 272,519,481
REVSED PROTOCOL
Beginning/Ending
FERC
ACCT
310.~1308
1309
1310
1311
1312
1313
1314
1315
1316
1317
1318
1319
1320
1321
1322
1323
1324
1325
1326
1327
1328
1329
1330
1331
1332
1333
1334
1335
1336
1337
1338.1E;
342
1343
134
1345
134
1347
1348
1349
1350
1351
1352
1353
1354 SP
1355
1356
1357
1358
1359
1360
1361
1362
1363
1364
1365
1366
1367
1368
1369
1370
1371
1372
1373
e1374
1375
~376
377
311
312
314
315
316
317
BUS
DESCRIP FUNC
Land and Land Rights
p
P
P
P
P
Strures and Improvements
p
p
P
P
Boiler Plant Equipment
P
P
P
P
Turbenerator Units
P
P
P
P
Accssry Elecc Equipment
P
P
P
P
Mise Powr Plnt Equipment
P
P
P
P
Stem Plant ARO
P
FACTOR
SG
SG
SG
S
SSGCH
SG
SG
SG
SSGCH
SG
SG
SG
SSGCH
SG
SG
SG
SSGCH
SG
SG
SG
SSGCH
SG
SG
SG
SSGCH
S
Unclassified Steam Plant - Accunt 30P SG
Totl Steam Proucton Plant
Summary of Steam Proucon Plant by Facor
S
DGP
DGU
SG
SSGCH
Total Steam Proucton Plant by Factor
320 Land and Land Rights
P
P
321 Strres and Improvements
P
P
SG
SG
SG
SG
Ref
UNADJUSTED RESULTSTOTAL OTHER
2,329,517
34,798,446
49,617,190
B8
1,246,363
87,991,516
B8
235,801,003
328,398,258
177,328,983
49,781,64
791,309,887
B8
736,597,256
881,187,724
1,181,26,483
225,983,471
2,805,034,933
B8
149,324,012
148,143,206
395,314,559
53,612,242
746,394,018
B8
88,303,558
139,536,216
62,798,950
48,958,470
337,597,194
B8
5,164,527
6,241,113
12,34,688
3,144,722
26,915,050
2,180,551
32,573,175
46,44,299
1,173,657
82,371,882
220,722,139
307,398,039
185,989,253
48,877,871
740,987,103
689,493,768
637,627,532
1,087,006,497
212,800,905
2,626,928,701
139,775,128
138,669,831
370,035,216
50,484,814
698,96,989
82,656,774
130,613,236
58,783,119
44,219,185
316,272,314
4,852,99
5,842,010
11,555,277
2,961,277
25,211,554
Page 2,21
IDAHO
ADJUSTMENT ADJ TOTALIDAHO
148,967
2,225,271
3,172,891
72,706
5,619,834
15,078,864
21,000,219
11,339,729
2,903,973
50,322,764
47,103,488
43,560,192
74,259,986
13,182,566
178,106,232
9,548,884
9,473,375
25,279,343
3,127,427
47,429,029
5,846,784
8,922,980
4,015,830
2,739,285
21,324,879
331,537
399,103
789,411
183,445
1,703,496
4,285,120
7,692,279
11,971,400
148,967
2,225,271
3,172,891
72,706
5,619,834
15,078,86
21,00,219
11,339,729
2,903,973
50,322,784
47,103,488
43,560,192
74,259,986
13,182,566
178,106,232
9,548,884
9,473,375
29,56,463
10,819,707
59,406,429
5,64,784
6,922,980
4,015,830
2,739,285
21,324,879
331,537
399,103
789,411
183,445
1,703,496
B8
B8
3,464,353
3,464,353
B8 4,798,706,950 316,705,190
4,417,980,040
380,726,910
4,798,706,950
3,242,816
3,242,816
4,493,979,160
4,135,461,651
358,517,509
4,493,979,160
221,536
221,536
304,727,790
282,518,389
22,209,401
304,727,790
11,977,40
4,285,120
7,692,279
11,977,400
221,536
221,536
286,803,509
29,901,880
316,705,190
B8
B8
REVSED PROTOCOL
Page 2.22
Beglnninglnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.78
79 322 Reactr Plan Equipment
80 P SG
1381 P SG
1382 88
1383
1384 323 Turbenerator Units
1385 P SG
1386 P SG
1387 88
1388
1389 324 Land and Land Rights
1390 P SG
1391 P SG
1392 88
1393
1394 325 Misc. Pow Plant Equipment
1395 P SG
1396 P SG
1397 88
1398
1399
1400 NP Unclasified Nuclear Plant. Ace 300
1401 P SG
1402 88
1403
1404
1405 Totl Nuclear proucton Plant B8
1406
1407
1408
1409 Summaiy of Nucar Proucn Plant by Factor
1410 DGP
1411 DGU
1412 SG.413
414 Totl Nucear Plant by Factor
415
1418 330 Land an Land Right
1417 P SG 10,827,138 9,947,560 879,578 879,578
1418 P SG 5,308,218 4,968,789 339,447 339,447
1419 P SG 3,073,580 2,8n,032 196,547 196,547
1420 P SG 635,700 595,048 40,851 40,851
1421 B8 19,84,832 18,388,409 1,258,223 1,258,223
1422
1423 331 Strure and Improvements
1424 P SG 21,835,235 20,251,718 1,383,517 1,383,517
1425 P SG 5,395,895 5,050,854 345,041 345,041
1428 P SG 49,188,594 48,04,111 3,145,483 3,145,483
1427 P SG 8,885,819 8,445,302 440,318 440,318
1428 88 83,105,144 n,790,785 5,314,359 5,314,359
1429
1430 332 Resrvoirs, Dams & Waterwys
1431 P SG 154,814,949 144,914,933 9,900,015 9,900,015
1432 P SG 20,883,26 19,547,833 1,335,431 1,335,431
1433 P SG 73,887,929 88,975,778 4,712,152 878,829 5,590,981
1434 P SG 33,845,550 31,494,004 2,151,546 343,823 2,495,189
1435 88 283,031,891 284,932,547 18,099,144 1,222,452 19,321,598
1438
1437 333 Water Wheel, Turbines, & Generators
1438 P SG 32,98,180 30,858,187 2,107,973 2,107,973
1439 P SG 9,704,26 9,083,702 620,563 820,563
1440 P SG 35,024,227 32,784,519 2,239,709 2,239,709
1441 P SG 11,591,574 10,850,323 741,251 741,251
1442 88 89,284,228 83,574,731 5,709,495 5,709,495
1443
144 334 Accssoiy Elecc Equipment
1445 P SG 5,190,479 4,858,561 331,918 331,918
1448 P SG 4,058,731 3,799,185 259,545 259,545
e4a
p SG 29,488,231 27,581,941 1,884,289 1,88,289
1448 P SG 3,845,857 3,412,714 233,143 233,143
449 88 42,381,297 39,852,402 2,708,895 2,708,895
450
REVISED PROTOCOL Page 2,23
Beinning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.51
52
453 335 Mise, Powr Plant Equipment
1454 P SG 1,371,951 1,284,218 87,733 87,733
1455 P SG 200,192 187,391 12,802 12,802
1456 P SG 98,383 921,435 62,949 62,949
1457 P SG 15,123 14,156 967 967
1458 88 2,571,649 2,407,199 164,450 164,450
1459
1460 336 Roads, Railrods & 8ridges
1461 P SG 4,638,647 4,342,017 296,629 296,629
1462 P SG 836,256 782,780 53,476 53,476
1463 P SG 7,732,926 7,238,426 494,501 494,501
1464 P SG 591,550 553,722 37,828 37,828
1465 88 13,799,379 12,916,944 882,435 882,435
146
1467 337 Hydro Plant ARO
1468 P S
1469 88
1470
1471 HP Uncassifi Hyro Plant - Ac 300
1472 P S
1473 P SG
1474 P SG
1475 P SG
1476 88
1477
1478 Totl Hydraulic Prouction Plant B8 533,798,18 49,663,016 34,135,002 1,222,452 35,357,453
1479
1480 Summaiy of Hydraulic Plant by Factor
1481 S
1482 SG 533,798,18 499,663,016 34,135,002 1,222,452 35,357,453
1483 DGP
1484 DGU ..-.
1485 Total Hydraulic Plant by Facor 533,798,018 499,663,016 34,135,002 1,222,452 35,357,453
.486
487 340 Land and Land Rights
488 P SG 21,542,430 20,164,847 1,77,583 1,377,583
1489 P SG
1490 P SSGCT
1491 88 21,542,430 20,164,847 1,377,583 1,377,583
1492
1493 341 Strctre and Improvements
1494 P SG 76,609,247 71,710,284 4,898,963 4,898,963
1495 P SG 170,926 159,996 10,930 10,930
1496 P SSGCT 4,237,997 3,925,509 312,488 312,488
1497 88 81,018,170 75,795,789 5,222,382 5,222,382
1498
1499 342 Fuel Holders, Proucers & Acssries
1500 P SG 16,813,666 15,738,475 1,075,190 1,075,190
1501 P SG 121,339 113,580 7,759 7,759
1502 P SSGCT 2,257,625 2,091,159 166,466 166,466
1503 B8 19,192,629 17,943,214 1,249,415 1,249,415
1504
1505 343 Prime Mo
1506 P S
1507 P SG 774,173 724,666 49,506 49,506
1508 P SG 666,532,969 623,909,911 42,623,058 42,623,058
1509 P SSGCT 51,317,832 47,533,918 3,783,914 (39,117)3,744,797
1510 88 718,624,974 672,168,495 46,456,479 (39,11)46,417,361
1511
1512 344 Generato
1513 P S
1514 P SG
1515 P SG 158,474,140 148,340,129 10,134,011 29,709,707 39,843,718
1516 P SSGCT 15,873,643 14,703,202 1,170,441 1,170,441
1517 88 174,347,783 163,043,331 11,304,452 29,709,707 41,014,159
.
REVISED PROTOCOL Page 2.24
Beginning/Ending
FERC BUS UNAJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.518
519 345 Accssory Elecc Plant
520 P SG 70,789,297 66,262,504 4,526,792 4,526,792
1521 P SG 156,586 146,573 10,13 10,13
1522 P SSGCT 4,041,177 3,743,201 297,976 297,976
1523 B8 74,987,059 70,152,278 4,834,781 4,834,781
1524
1525
1526
1527 346 Misc. Powr Plant Equipment
1528 P SG 5,181,032 4,849,719 331,314 331,314
1529 P SG 11,813 11,058 755 755
1530 B8 5,192,845 4,860,776 332,069 332,069
1531
1532 347 Other Proucn ARO
1533 P S
1534 B8
1535
1536 OP Unclssified Other Pro Plant.Acc 300
1537 P S
1538 P SG
1539
1540
1541 Totl Oter Production Plant B8 1,094,905,891 1,024,128,731 70,777,161 29,670,590 100,447,750
1542
1543 Summary of Other Procton Plant by Facor
154 S
1545 DGU
1546 SG 29,709,707 94,755,583
1547 SSGCT 39,11 5,692,168
1548 Totl of Oter Proucton Plant by Factr 9,0, 90 00,44 ,750
1549
1550 Exmental Plant
1551 103 Expementl Plant
1552 P SG.553 Totl Experimental Prouction Plant B8
554
555 Total prouction Plant B8 6,427,410,860 6,017,770,907 40,639,952 42,870,441 452,510,393
1556 350 Land and Land Rights
1557 T SG 21,253,588 19,894,474 1,359,112 1,359,112
1558 T SG 48,636,647 45,526,459 3,110,188 3,110,188
1559 T SG 23,003,746 21,532,718 1,471,030 1,471,030
156 88 92,893,978 86,953,649 5,940,329 5,940,329
1561
1562 352 Strctures and Impvements
1563 T S
1564 T SG 7,680,455 7,189,310 491,145 491,145
1565 T SG 18,272,147 17,103,690 1,168,456 1,168,456
156 T SG 33,546,557 31,401,342 2,145,215 2,145,215
1567 B8 59,499,159 55,694,342 3,804,817 3,804,817
1568
1569 353 Station Equipment
1570 T SG 134,359,329 125,767,397 8,591,931 8,591,931
1571 T SG 196,780,332 164,196,739 12,583,593 12,583,593
1572 T SG 663,784,06 621,336,791 42,447,273 (21,907)42,425,386
1573 B8 994,923,724 931,300,927 63,622,797 (21,907)63,600,890
1574
1575 354 Tow and Fixtures
1576 T SG 156,369,123 146,369,722 9,999,401 9,999,401
1577 T SG 126,993,462 118,872,559 8,120,903 8,120,903
1578 T SG 119,294,971 111,68,367 7,628,605 7,628,605
1579 88 402,657,556 376,908,648 25,748,909 25,748,909
1580
1581 355 Poles and Fixtres
1582 T SG 68,811,064 64,410,775 4,400,289 4,400,289
1583 T SG 118,660,645 111,072,60 7,588,041 7,588,041
1584 T SG 331,313,252 310,126,627 21,186,625 7,690,436 28,817,061
1585 B8 518,764,962 485,610,006 33,174,956 7,690,436 40,865,391
1586.
REVISED PROTOCOL Page 2.25
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.87 356 Clearing and Grading
88 T sG 207,662,334 194,382,865 13,279,469 13,279,469
589 T sG 158,693,877 148,545,815 10,148,063 10,148,063
1590 T sG 312,230,54 292,263,750 19,966,304 19,966,304
1591 B8 678,586,266 635,192,430 43,393,835 43,393,835
1592
1593 357 Underground Conduit
1594 T sG 6,371 5,96 407 407
1595 T sG 162,746 152,339 10,407 10,407
1596 T sG 3,108,283 2,909,516 198,767 198,767
1597 B8 3,277,400 3,067,819 209,581 209,581
1598
1599 358 Undrground Conducrs
1600 T sG
1601 T sG 1,018,663 953,522 65,141 65,141
1602 T sG 8,301,423 5,898,463 402,960 402,960
1603 B8 7,320,085 6,851,985 468,101 468,101
1604
1605 359 Roads and Trails
1606 T sG 1,897,971 1,776,600 121,370 121,370
1607 T sG 497,979 466,134 31,84 31,844
1608 T sG 9,087,425 8,50,307 581,117 581,117
1609 B8 11,483,374 10,749,042 734,332 734,332
1610
1611 TP Uncassifie Trans Plant. Acc 300
1612 T sG 13,753,120 12,873,644 879,476 879,476
1613 B8 13,753,120 12,873,644 879,476 879,476
1614
1615 TsO Uncassifed Trans Sub Plant. Acc 300
1616 T sG
1617 B8
1618
1619 Totl Transmission Plant B8 2,783,179,626 2,605,202,492 177,977,134 7,668,529 185,645,662
1620 Summary of Transmission Plant by Factor
.:;DGP
DGU
623 sG 2,783,179,626 2,605,202,492 177,977,134 7,668,529 185,845,662
624 Total Transmission Plant by Factor 2,783,179,626 2,605,202,492 177,977,134 7,668,529 16$,645,662
1625 360 Land and Land Rights
1626 DPW S 45,157,893 43,903,924 1,253,969 1,253,969
1627 B8 45,157,893 43,903,924 1,253,969 1,253,969
1628
1629 361 Strres and Imprvements
1630 DPW S 49,196,44 48,399,387 797,057 797,057
1631 B8 49,196,44 48,399,387 797,057 797,057
1632
1633 362 Staon Equipment
1634 DPW S 665,332,015 642,551,589 22,780,426 22,780,426
1635 B8 665,332,015 642,551,589 22,780,426 22,780,426
1636
1637 363 Storage Battery Equipment
1638 DPW S 1,457,805 1,457,805
1639 B8 1,457,805 1,457,805
1640
1641 36 Poles, Towrs & Fixtres
1642 DPW S 820,538,196 766,677,922 53,860,274 2,953,713 56,813,987
1643 B8 820,538,196 766,677,922 53,860,274 2,953,713 56,813,987
164
1645 365 Ovrhd Conductrs
184 DPW S 595,871,504 563,419,932 32,451,572 32,451,572
1847 B8 595,871,504 563,419,932 32,451,572 32,451,572
1648
,
.~51
1652
1653
1654
1655
1656
1657
1658
1659
1660
1661
1662
1663
1664
1665
1666
1667
1668
1669
1670
1671
1672
1673
1674
1675
1676
1677
1678
1679
1680
1661
1682.1== DP
686
1687
1688
1689
1690
1691
1692
1693
1694
1695
1696
1697
1698
-
REVSED PROTOCOL
BennlngJndlng
FERC
ACCT
366
367
368
369
370
371
372
BUS
DESCRIP FUNC
Underground Conduit
DPW 5
FACTOR
Undrground Conductors
DPW 5
Line Transfoers
DPW 5
Servics
DPW S
Meters
DPW S
Instllations on Customers' PremisesDPW S
Lease Propert
DPW 5
373 Strt Lights
DPW S
Uncssified Dist Plant. Acc 300DPW S
DSO Uncssifi Dist Sub Plant. Ac 300DPW S
Totl Distributon Plant
SUmmary of Distrbun Plant by Factor5
Tot Distrbution Plant by Factr
Ref
UNADJUSTED RESULTSTOTAL OTHER IDAHO
88
261,883,449 255,351,582 6,531,868
261,683,449 255,351,582 8,531,868
88
624,968,245 603,524,381 21,443,664
624,968,245 603,524,381 21,443,864
88
939,974,448 880,623,990 59,350,458
939,974,448 880,623,990 59,350,458
88
483,572,023 459,755,269 23,816,753
483,572,023 459,755,269 23,816,753
88
186,655,233 172,922,996 13,732,238
186,655,233 172,922,996 13,732,238
88
8,86,929 8,705,243 159,666
8,864,929 8,705,243 159,686
159,686-
159,686
88
49,658 44,785 4,87349,658 44,785 4,873
88
58,180,189 57,610,017 570,172
58,180,189 57,610,017 570,172
570,172
570,172
88
26,631,530 25,285,133 1,346,397
26,631,530 25,285,133 1,34,397
Page 2.26
IDAHO
ADJUSTMENT. ADJ TOTAL
6,531,868
6,531,868
21,443,864
21,443,864
59,350,458
59,350,458
23.818,753
23,816,753
13,732,238
13,732,238
4,873
4,873
1,346,397
1,34,397
88
B8 4,768,333,561 4,530,233,954 238,099,607
4,768,333,561 4,530,233,954 238,99,607
4,768,333,561 4,530,233,954 238,099,607
2,953,713
2,953,713
2,953,713
241,053,320
241,053,320
241,053,320
.99
00
701
. 1702
1703
1704
1705
1706
1707
1708
1709
1710
1711
1712
1713
1714
1715
1718
1717
1718
1719
1720
1721
1722
1723
1724
1725
1726
1727
1728
1729
1730
1731
1732
e1i:735
736
1737
1738
1739
1740
1741
1742
1743
1744
1745
1746
1747
e
REVSED PROTOCOL
Beginning/Ending
FERC
ACCT
389
BUS
DESCRIP FUNC
Land and Land RighlsG-ITS
CUST
G-OGU
G-SG
PTO
390 Strctres and Improvements
G-5ITUS
G-OGP
G-OGU
CUST
G-SG
PTO
391 Of Furnitre & Equipment
G-SITUS
G-OGP
G.OGU
CUST
G-5G
P
PTO
G-5G
G-G
392 Transpotion EquipmentG-ITS
PTO
G-G
CUST
G-OGU
P
G-OGP
G-SG
G.OGU
393 Stors EquipmentG.SITS
G-OGP
G-DGU
PTO
G-SG
G-OGU
FACTOR
5
CN
SG
SG
SO
5
SG
SG
CN
SG
SO
5
SG
SG
CN
SG
SE
SO
SSGCH
SSGCT
S
SO
SG
CN
SG
SE
SG
SSGCH
SSGCT
S
SG
SG
SO
SG
SSGCT
Ref
UNADJUSTED RESULTSTOTAL OTHER
88
8,429,002
1,128,50
332
1,228
5,598,055
15,157,123
8,231,383
1,082,648
311
1,149
5,26,798
14,580,268
94,472,779
335,969
1,474,631
11,443,822
3,606,568
97,676,732
209,010,499
14,440,532
293,231
246,470
5,614,309
4,869,927
149,812
.68,190,910-
244,788
9,301
94,261,341
85,325,868
8,358,399
13,565,141
9,152
1,024,545
698,462
150,191
334,029
48,227
89,514,013
IDAHO
197,639
45,860
21
78
333,257
576,855
9,649,974
22,952
100,741
464,748
246,386
6,182,844
16,687,646
991,155
20,032
18,974
248,288
332,694
10,563
4,316,423
15,164
740
5,950,035
4,835,342
529,079
926,717
388
69,993
49,248
10,260
20,692
3,839
6,445,558
Page 2.27
IDAHO
ADJUSTMENT ADJ TOTAL
(3,124)
(3,124)
197,639
45,860
21
78
333,257
576,855
9,649,974
22,952
100,741
484,748
246,386
8,182,844
18,687,646
991,155
20,032
16,974
248,288
332,694
10,563
4,318,423
15,184
740
5,950,035
4,835,342
529,079
923,593
388
69,993
49,248
10,260
20,692
3,839
8,442,434
88
104,122,753
358,921
1,575,372
11,928,570
3,852,952
103,859,576
225,898,145
88
15,431,688
313,263
265,44
8,060,597
5,202,621
160,378
72,507,393
259,952
10,042
100,211,376
88
70,161,210
8,887,477
14,491,858
9,539
1,094,538
747,710
180,452
354,721
52,06
95,959,571
88
8,851,742
335,870
863,132
494,538
2,803,96
106,993
13,256,040
8,227,157
314,204
820,728
485,097
2,824,659
99,104
12,350,948
624,585
21,465
42,408
29,440
179,308
7,889
905,091
824,565
21,465
42,406
29,440
179,306
7,889
905,091
REVSED PROTOCOL Page 2.28
BeglnnJnglnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENl ADJTOTAl.48
394 Toos, Shp & Garage Equipment749
50 G-SITUS S 30,655,179 29,077,781 1,577,397 1,577,397
1751 G-DGP SG 2,939,080 2,751,134 187,947 187,947
1752 G-SG SG 17,437,638 18,322,54 1,115,92 27,481 1,142,572
1753 PTD SO 4,173,558 3,925,103 248,455 350,472 598,927
1754 P SE 7,106 6,638 468 468
1755 G-DGU SG 4,305,862 4,030,513 275,349 275,349
1756 G.SG SSGCH 2,003,148 1,886,296 116,852 116,852
1757 G-SG SSGCT 70,469 65,273 5,196 5,196
1758 B8 61,592,041 58,065,285 3,526,756 377,952 3,904,708
1759
1760 395 laboratory Equipment
1761 G-SITUS S 26,594,275 25,285,06 1,309,211 1,309,211
1762 G-DGP SG 69,613 65,162 4,452 4,452
1763 G.DGU SG 690,785 646,611 44,174 44,174
1764 PTD SO 5,56,385 5,235,014 331,371 331,371
1765 P SE 42,438 39,643 2,795 2,795
1766 G-5G SG 5,552,332 5,197,274 355,057 355,057
1767 G-SG SSGCH 244,754 230,476 14,278 14,278
1768 G-SG SSGCT 110,119 101,999 8,120 8,120
1769 B8 38,870,700 36,801,243 2,069,457 2,069,457
1770
1771 396 Por Operated Equipment
1772 G-5ITUS S 89,014,469 82,429,611 6,584,858 6,584,858
1773 G-DGP SG 1,017,722 952,641 65,81 65,081
1774 G-SG SG 27,240,493 25,498,534 1,741,959 1,741,959
1775 PTD SO 1,772,743 1,667,210 105,533 105,533
1776 G-DGU SG 2,369,618 2,218,087 151,531 151,531
1m P SE 73,823 68,961 4,862 4,862
1778 P SSGCT
1779 G-5G SSGCH 724,648 682,376 42,272 42,272
1780 B8 122,213,516 113,517,420 8,696,096 8,696,096
1781 397 Comuniction Equipment
1782 COM_EQ S 106,085,949 99,833,157 6,252,792 6,252,792
.783 COM_EQ SG 5,733,819 5,367,156 36,663 36,663
784 COM_EQ SG 10,815,86 10,124,220 691,647 691,647
785 COM_EQ SO 47,820,936 44,974,117 2,84,819 2,646,819
1786 COM_EQ CN 4,543,876 4,359,224 164,652 184,652
1787 COM_EQ SG 60,376,453 56,515,536 3,860,918 3,860,918
1788 COM_EQ SE 108,187 101,061 7,126 7,126
1789 COM_EQ SSGCH 914,651 861,296 53,355 53,355
1790 COM_EQ SSGCT 51,265 47,485 3,780 3,780
1791 B8 236,451,003 222,183,251 14,267,752 14,267,752
1792
1793 398 Mise Equipt
1794 G-SITUS S 1,133,655 1,072,772 60,883 60,883
1795 G-DGP SG 24,300 22,746 1,554 1,554
1796 G-DGU SG 23,636 22,125 1,511 1,511
1797 CUST CN 189,588 181,884 7,704 7,704
1798 PTD SO 3,108,758 2,923,691 185,067 185,067
1799 P SE 3,531 3,299 233 233
1800 G-G SG 1,164,094 1,089,653 74,441 74,441
1801 G-SG SSGCT 2,650 2,455 195 195
1802 B8 5,650,213 5,318,624 331,588 331,588
1803
1804 399 Coa Mine
1805 P SE 257,696,236 240,723,168 16,973,068 12,163,099 29,136,167
1806 MP P SE
1807 B8 257,696,236 240,723,168 16,973,068 12,163,099 29,136,167
1808
1809 399L WlDCO Capital Lease
1810 P SE B8
1811
1812
1813 Remve Capital leases
1814 B8
1815.
REVSED PROTOCOL Page 2,29
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAl.16 1011390 Genel Capital leases
17 G-SlTUS S 7,306,030 7,306,030
18 P SG 12,411,745 11,618,46 793,699 793,699
, 1819 PTO SO 12,902,451 12,134,358 768,093 768,093
1820 89 32,620,226 31,058,434 1,561,792 1,561,792
1821
1822 Remove Capital leases (32,620.226)(31,058,434)(1,561,792)(1,561.792)
1823
1824
1825 1011346 Geeral Gas line Capil leases
1826 P SG
1827 B9
1826
1829 Remove Capitl Leases
1830
1831
1832 GP Uncasfied Gen Plant - Acc 300
1833 G-SITUS S
1834 PTO SO 450,243 423,439 26,803 26,803
1835 CUST CN
1836 G-SG SG
1837 G-OGP SG
1838 G-DGU SG
1839 88 450,243 423,439 26;803 26.803
1840
1841 399G Unclassifed Gen Plant. Acc 300
1842 G-SlTS S
1843 PTO SO
184 G-SG SG
1845 G-GP SG
1846 G-OGU SG
1847 88
1848
1849 Totl General Plant B8 1,173,206,205 1,096,749,500 76,45,705 12,537,928 88,994,633
.~51 Summary of Gene Plant by Facor
52 S 467,785,952 435,702,115 32,083,837 32,083,837
853 OGP
185 DGU
1855 SG 183,292,804 171,571,704 11,721,100 24,357 11,745,457
1856 SO 267,142,113 251,238,929 15,903,184 35,472 16,253,656
1857 SE 258,839,407 241,791,044 17,048,363 12,163,099 29,211,462
1856 CN 23,860,677 22,891,037 969,640 969,840
1859 OEU
1860 SSGCT
29,760
1861 SSGCH
262,613
1862 Less Capital Leases
1,561,792)
1863 Totl Geral Ptant by Factor
88.994,633
186 301 Organiztion
1865 I.SITUS S
1866 PTD SO
1867 I-SG SG
1868 88
1869 302 Franchis & Consent
1870 I-SITUS S 1,000,000 1,000,000 1,00,00
1871 I-G SG 2,945,256 2,756,915 188,342 188,342
1872 I-SG SG 82,829,189 58,811,425 4,017,764 1,213,382 5,231,146
1873 I-SG SG 9,471,942 8,866,236 605,706 (14,785)590,922
1874 1-0GP SG 1,422,439 1,331,478 90,961 90,961
1875 I-DGU SG 640,289 599,344 40,945 40,945
1876 B8 78,309,116 72,365,398 5,943,718 1.198,597 7.142,315
1877
t
.~~
1881
1882
1883
1884
1885
1886
1887
1888
1889
1890 IP
1891
1892
1893
1894
1895
1896
1897
1898
1899
190
1901
1902
1903
190
1905
1906
1907
1908190
1910
1911
1912.13
14
915
1916
1917
1918
1919
1920
1921
1922
1923
1924
.
REVSED PROTOCOL
Beinning/Ending
FERC
ACCT
303
BUS
DESCRIP FUNC FACTOR
Miscllaneous Intangible Planti-SITS Si-SG SGPTD SOP SECUST CNP SGI.OGP SSGCT
303 less NonUtility Plant
i-SITUS S
Uncssified Intangible Plant - Ace 300I-SITUS Si-SG SGi-OGU SGPTO SO
Totl Intangible Plant
Summaiy of Intangible Plant by Factor
S
DGP
DGU
SG
SO
CN
SSGCT
SSGCH
SE
Total Intngible Plant by Facor
Summaiy of Unclssifed Plant (Accunt 106)
OP
OSO
GP
HP
NP
OP
TP
TSO
IP
MP
SP
Total unclassed Plant by Factr
Totl Eletrc Plant In Serice
Ref
UNADJUSTED RESULTSTOTAL OTHER
1,533,253
61,669,612
38,450,837
2,873,331
107,447,682
34,575
1,140,872
57,726,00
360,623,701
2,684,080
103,081,270
322,541
IDAHO
392,381
3,943,612
22,827,136
189,251
4,366,412
22,035
Page 2.30
IDAHO
ADJUSTMENT ADJ TOTAL
(70,827)
392,381
3,943,612
22,756,309
189,251
4,366,412
22,035
B8 557,319,289 31,670,000525,578,463 31,740,826 (70,827)
557,319,289 31,670,000525,578,463 31,740,826 (70,827)
B8 635,628,405 597,943,861 37,684,54 1,127,770 38,812,314
2,533,253
139,323,303
383,450,837
107,447,682
2,873,331
635,628,405
1,140,872
130,413,938
380,623,701
103,081,270
2,684,080
597,943,861
1,392,381
8,909,365
22,827,136
4,36,412
189,251
37,684,544
1,198,597
(70,827)
-
1,127,770
1,392,381
10,107,962
22,758,309
4,366,412
189,251
38,812,314
26,631,530 1,346,397
450,243
13,753,120
3,46,353
44,299,245
25,285,133
423,439
12,873,84
3,242,816
41,825,032
1,346,397
26,803
879,476
221,536
2,474,213
26,803
879,476
221,536
2,474,213
1,007,016,323B815,787,758,656 14,847,900,714 939,857,942 67,158,381
REVISED PROTOCOL Page 2.31
Beginning/Ending
FERC BUS UNAJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAl.925 Summary of Elec Plant by Factor
926 S 5,238,652,766 4,967,076,941 271,575,825 2,953,713 274,529,538
927 SE 261,712,737 244,475,124 17,237,614 12,163,099 29,400,713
1928 DGU
192 DGP
1930 SG 9,074,751,406 8,494,444,543 580,306,865 44,108,762 624,415,627
1931 SO 650,592,949 611,862,629 38,730,320 279,645 39,009,965
1932 CN 131,308,359 125,972,307 5,336,051 5,336,051
1933 DEU
1934 SSGCH 385,228,784 22,472,014 7,692,279
1935 SSGCT 78,131,878 5,761,04 (39,117)
1936 les Capital Leases 32,620,22)1,561,792)
1937 ' 58,656 939,8 7,942 6 ,158,38
1938 105 Plant Held For Future Use
1939 DPW S 1,375,461 1,375,461
1940 P SG
1941 T SG 6,671,614 6,250,597 427,016 (427,016)
1942 P SG
1943 P SE 476,507 445,122 31,385 (31,385)
194 G SG
1945
1946
1947 Totl Plant Held For Futre Use 810 8,529,582 8,071,181 458,401 (45,401)
1948
1949 114 Elecc Plant Acquisition Adjustments
1950 P S
1951 P SG 142,633,069 133,512,053 9,121,016 9,121,016
1952 P 5G 14,560,711 13,629,591 931,120 931,120
1953 Totl Electrc Plant Acqu(sitlon Adju5tment B15 157,193,780 147,141,644 10,052,135 10,052,135
1954
1955 115 Acm Proision for Asset Acquisition Adjustments
1956 P S
1957 P 5G (4,607,856)
1958 P 5G 676,23)
1959 815 ,283.8 8).960
961 120 Nuclar Fuel
962 P 5E
'1963 Totl Nuclear Fuel B15
196
1965 124 Weathertion
196 DMSC S 5,072,805 5,32,634 40,171 40,171
1967 DMSC 50
12,463)
(2,316)(14~(147)
196 816 5,lFo,342 5,030,318 40,02 40:025
1969
1970 182W Weathenztlon
1971 DMSC 5 6,751,640 659,758 6,091,882 6,091,882
1972 DMSC SG
1973 DMSC 5GCT
1974 DMSC SO ..
1975 816 6,751,640 659,758 6,091,882 6,091,882
1976
1971 188W Weatherization
1978 DMSC 5
1979 DMSC CN
1980 DMSC CNP
1981 DMSC 5G
1982 DMSC 50
1983 816
1964
1985 Totl Weatherization 816 11,821,982 5,690,076 6,131,906 6,131,906
.
REVISED PROTOCOL Page 2,32
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
.986
987 151 Fuel Sto
988 P DEU
1989 P SE 85,712,130 80,066,732 5,645,398 900,265 6,545,663
1990 P SSECT
1991 P SSECH 4,570,393 4,294,265 276.127 156,249 432,376
1992 Total Fuel Stok B13 90,282,522 84,360,997 5,921,525 1,056,514 6,978,039
1993
1994 152 Fuel Stock - Undistributed
1995 P SE
1996
1997
1998 25316 DG&TWorking Capital Deposit
1999 P SE (398,000)(371,786)(26,214)(26,214)
200 813 (398,000)¡371,786ì (26,214)(26.214)
2001
2002 25317 DG&TWorkin Capil Deposi
2003 P SE
f,398,721l
(1,306,594)(92,126)(92,126)
200 813 1,398,721 Î1,306.594ì (92,126)(92,126)
2005
2006 25319 Proo Woring Capitl Deposit
207 P SE
2008
2009
2010 Totl Fuel Sto 813 88,485,802 82,682,617 5,803,185 1,056,514 8,859,699
2011 154 Materals and Supplies
2012 MSS 5 70,04,166 65,887,854 4,156,312 4,156,312
2013 MSS SG 1,854,615 1,736,017 118,598 118,598
2014 MSS SE 3,881,454 3,607,121 254,333 254,333
2015 MSS SO 124,020 116,637 7,383 7,383
2016 MSS SNPPS 68,638,749 64,276,193 4,362,557 4,362,557
2017 MSS SNPPH (21,081)(19,733)(1,348)(1,348)
2018 MSS SNPD (4,610,98)(4,398,372)(212,608)(212,608)
2019 MSS SNPT
2020 MSS SG.21 MSS SG
022 MSS SSGCT
023 MSS SNPP
2024 MSS SSGCH
2025 Totl Materials and Supplies B13 139,890,944 131,205,717 8,685,227 8,685,227
2026
2027 163 Stos Exse Undistrbut
2028 MSS SO
2029
2030 813
2031
2032 25318 Pro Woring Capit Deposit
2033 MSS SNPPS (273,000)(255,649)(17,351)(17,351)
2034
2035 813 (273,000)(255,649)(17,351)(17,351)
2038
2037 Total Maerials & Supplies 813 139,617,944 130,950,068 8,667,876 8,667,876
2038
2039 165 Prepaments
204 DMSC 5 2,901,782 2,737,400 164,382 164,382
2041 GP GPS 8,255,999 7,764,513 491,486 491,486
2042 PT SG 3,874,108 3,626,369 247,739 247,739
203 P SE 3,238,141 3,024,862 213,279 213,279
2044 PTD SO 18,992,151 17,881,533 1,130,618 1,130,618
2045 Totl Prepayments B15 37,262,181 35,014,617 2,247,505 2,247.505
2046
.
REVSED PROTOCOL
P8ge2.33
Begnning/Ending
FERC BUS UNADJUSTED RESULTS iDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.~7 182M Mise Regulatory Assets
048 0052 S 51,948,280 52,252,361 (30,080)6,759 (297,321)
049 DEF5G SG 3,546,418 3,319,634 226,784 22,784
2050 P 5GCT 11,317,786 10,591,189 726,597 726,597
2051 DEF5G 5G-P 182,545 182,545
2052 P 5E °0 0 0
2053 P 55GCT
2054 00502 50 6,550,280 6,160,336 369,943 -389,943
2055 B11 73,362,764 72,323,519 1,039,245 189,304 1,228,549
2056
2057 186M Mise Deferred Debits
2056 LABOR 5 4,270,905 4,270,905
2059 P 5G
2060 P 5G
2061 DEF5G 5G 35,922,452 33,625,3~2,297,148 2,297,148
2062 LABOR 50 196,247 184,56 11,683 11,683
2063 P 5E 6,941,114 6,463,940 457,174 457,174
206 P 5NPP5
2065 GP EXCTAX -..
20 Tot Misc. Det Debits B11 47,330,718 44,564;714 2,766,005 2,766,005
2067
2068 Working Capitl
209 CWC Cash Woring Capital
2070 CWC 5 53,184,798 50,597,090 2,587,708 798,796 3,386,504
2071 CWC SO
2072 CWC 5E
2073 B14 53,184,798 50,597,090 2,587,708 798,796 3,386,504
2074
2075 OWC 0I Wo cap.
2076 131 Cu GP 5NP 22,999,473 21,660,667 1,338,806 (1,338,806)0
2077 135 Wix Fund GP 5G 2,691 2,519 172 172
2078 141 _ Recab GP SO 918,4&0 863,783 54,6n 54,6n
2079 143 OIAI GP SO 16,607,230 15,618,586 988,642 988,642
2080 232 NP PTD 5
2081 232 NP PTD SO (1,278,895)(1,202,762)(76,134)(76,134).082 232 10 P 5E (1,216,83)(1,135,986)(80,097)(80,97)
083 232 NP T SG 2 2 °0
084 2533 Ol __ 01. Ct. P 5
2085 2533 Ol __ 01. en P 5E (5,605,322)(5,236,130)(369,192)(369,192)
2086 230 _ Rel. 0b P 5E (2,401,443)(2,243,273)(158,170)(158,170)
2087 230 __.Ob.P 5
2088 254105 ARReglJ P 5 (30,363)(30,363)
2089 254105 ARReglJ P 5E (437,406)(408,596)(28,810)(28,810)
2090 2533 CIR_P 55ECH
2091 B14 29,558,343 27,888,450 1,669,893 (1,338,806)331,088
2092
2093 Total Working Capitl 814 82,743,141 78,485,539 4,257,602 3,717,592
2094 Miscllaneous Rate Base
205 18221 Unre Plant & Reg Study Costs
2096 P 5
207
2098 B15
2099
2100 18222 Nudear Pænt - Trojan
2101 P 5 (1,231,660)(1,231,660)
2102 P TROJP 2,938,099 2,749,359 188,740 188,740
2103 P TROJD 4,287,665 4,012,011 275,654 275,654
2104 B15 5,994,104 5,529,710 464,394 46,394
2105
2106
.
REVISED PROTOCOL
Page 2.34
Beginning/Ending
FERC BUS UNAJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.07
08 1869 Mise Defeed Debit-Trojan
109 p S
- 2110 P SNPPN
2111 B15
2112
2113 Totl Miscellaneous Rate Base B15 5,994,104 5,529,710 46,394 46,394
2114
2115 Totl Rate Base Additons B15 569,713,507 533,109,133 36,604,375 247,407 36,851,782
2116 235 Customer Service Deposits
2117 CUST S
2118 CUST CN
2119 Totl Customer Service Deposits B15
2120
2121 2281 Pro Ins PTO SO (709,335)(667,107)(42,227)(42,227)
2122 2282 In¡ & Dam PTD SO (4,671,915)(4,393,792)(278,123)(278,123)
2123 2283 Pen & Ben PTO SO (41,762,931)(39,276,750)(2,486,161)(2,486,181)
2124 2283 Pen & Ben PTD S
2125 254 Ins Pro PTO SO 66,470)66,470)
2126 B15 ,3,00),000)
2127
2128 22844 Acm Hyro Relicnsing Obligation
2129 P S
2130 P SO
2131 B15
2132
2133 22842 Prv-Troan P TROJO (2,526,679)(2,36,239)(162,440)(162,440)
2134 230 ARO P TROJP (2,325,760)(2,176,356)(149,404)(149,404)
2135 254105 ARO P TROJP (849,801)(795,211)(54,590)(54,590)
2136 254 P S 125,999 125,999 --
2137 B15 (5,576,241 )(5,209,807)(366,434)(36,434)
2138
2139 252 Custoer Adnces to Constrctn
2140 OPW S (11,982,333)(11,956,287)(26,046)(62,170)(88,217)
.:::
OPW SE
T SO (1 ,n1 ,936) (1,658,626)(113,311)(183,472)(296,783)
143 OPW SO
144 CUST CN 6,523 0
2145 Totl Customer Advances for Constrution B19 39, 20 4,99)
2146
2147 25398 S02 Emissions
2148 P SE i2,350,872)
~2,35O,872)
2149 819 2,350.872)2,350,872)
2150
2151 25399 Oter Defer Creit
2152 P S
2153 LABOR SO (958,997)
2154 P SO
2155 P SE
2156 819
,
REVSED PROTOCOL Page 2.35
Beinning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
.157
158 190 Accumulate Deferr Incme Taxes
159 P S 10,233,594 9,875,889 357,705 (166,075)191,630
2160 CUST CN 124,106 119,063 5,043 5,043
2161 lABOR SO 71,280,601 67,037,210 4,243,391 (58,787)4,184,605
2162 P DGP 1,587 1,587
2163 CUST BADDEBT 3,783,186 3,84,694 136,492 136,492
2164 P TROJD 7,466 6,986 480 48
2165 P SG 23,715,219 22,198,693 1,516,527 1,516,527
2166 P SE 14,30,239 13,363,96 942,275 892,158 1,834,433
2167 PTD SNP 10,657 10,037 620 620
2168 DPW SNPD 758,586 723,609 34,978 34,978
2169 P SSGCT 1,252,667 1,160,302 92,365 92,365
2170 Totl Accurn Deferr Incoe Taxes B19 125,473,911 118,144,033 7,329,878 667,296 7,997,174
2171
2172 281 Accmulated Deferred Income Taxes
2173 p 5
2174 PT DGP (150,087)(150,087)
2175 T SNPT
2176 819 (150,087)(150,087)
21n
2178 282 Accmulated Deferr Incme Taxes
2179 GP S (2,761,061)(2,506,527)(254,534)(254,534)
2180 ACCMDIT OITBAL (1,278,405,455)(1,194,550,780)(83,854,675)(1,429,25)(85,284,200)
2181 PT OGP
2182 lABOR SO (14,444,370)(13,584,485)(859,885)(859,885)
2183 PTO SNP
2184 P SE (11,511,381)(10,753,188)(758,193)(758,193)
2185 P SG 1,557,280 1,457,696 99,584 43,737 143,321
2166 819 (1,305,584,986)(1,219,937,283)(85,627,703)(1,385,788)(87,013,491)
2187
2188 283 Accmulated Deferred Incoe Taxes
2189 GP 5 (33,186,298)(32,781,705)(404,593)(404,593)
2190 P SG (8,736,115)(8,177,463)(558,652)(134,213)(692,865).191 P 5E (14,204,598)(13,269,018)(935,581)(935,581)
192 lA80R 50 (4,572,840)(4,300,427)(272,213)(272,213)
193 GP GP5 (21,483,987)(20,205,028)(1,278,959)(1,278,959)
194 PTO SNP (8,826,525)(8,312,730)(513,794)(513,794)
2195 P TROJO (110,766)(103,645)(7,121)(7,121)
2196 P 'S5GCT
2197 P SGCT (3,085,875)(2,887,763)(198,112)(198,112)
2198 P 5SGCH
2199 819 (94,208,804)(90,037,779)(4,169,025)(134,213)(4,303,238)
2200
2201 Totl Accum Deferr Income Tax B19 (1,274,447,966)(1,191,981,116)(82,466,850)(852,704)(83,319,555)
2202 255 Accmulated Investment Tax Creit
223 PTO 5
220 PTD ITC84 (3,199,757)(3,199,757)
2205 PTO ITC85 (4,741,072)(4,741,072)
2206 PTO ITC86 (2,096,319)(2,096,319)
227 PTO ITC88 (296,316)(296,316)
2208 PTO ITC89 (634,042)(634,042)
2209 PTO ITC90 (387,84)(333,619)(54,227)
2210 PTO IBT
2211 Totl Accumlated ITC B19
2212
2213 Total Rate Base Oeductons
2214
-
REVSED PROTOCOL Page 2.36
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
.215
216
2217 108SP Stem Pro Plant Accmula(ed Depr
2218 P S
2219 P SG (837,394,016)(783,84,836)(53,549,180)(53,549,180)
2220 P SG (911,90,525)(853,590,591)(58,313,934)(58,313,934)
2221 P SG (449,860,467)(421,093,054)(28,767,413)1,342,984 (27,424,429)
222 P SSGCH (215,424,115)(202,857,521)(12,566,594)40,225 (12,526,370)
2223 B17 (2,414,583,122)(2,261,386,002)(153,197,121)1,383,208 (151,813,913)
2224
2225 108NP Nucear Pro Plant Accumulated Depr
2226 P SG
2227 P SG
2228 P SG
229 B17
2230
2231
2232 108HP Hyraulic Pro Plant Accm Depr
2233 P S
2234 P SG (147,514,849)(138,081,656)(9,433,193)(9,433,193)
2235 P SG (27,395,847)(25,843,953)(1,751,893)(1,751,893)
2236 P SG (46,993,812)(43,988,880)(3,005,133)150,505 (2,854,627)
2237 P SG (10,016,317)(9,375,800)(840,518)2,579 (637,938)
2238 B17 (231,920,825)(217,090,088)(14,830,736)153,085 (14,677,652)
2239
2240 1080P Oter Prouctio Plant. Accm Depr
2241 P S
2242 P SG (1,943,487)(1,819,206)(124,281)(124,281)
2243 P SG
2244 P SG (74,94,987)(70,152,449)(4,792,538)(562,077)(5,354,615)
2245 P SSGCT
f4,501,527)
(13,432,259)(1,069,268)22,672 (1,046,596)
2246 B17 91,390,001)(85,403,914)(5,986,087)(539,405)(6,525,492)
2247
2248 108EP Experimental Plant. Accm Depr.249 P SG
250 P SG
251
2252
2253 Totl Prouction Plant Accum Depreciation B17 (2,737,893,948)(2,563,880,04)(174,013,945)996,888 (173,017,056)
2254
2255 Summary of Pro Plant Deprati by Factor
2256 S
2257 DGP
2258 DGU
2259 SG (160,378,82)933,991
2260 SSGCH (12,56,594)40,225
2261 SSGCT 1,069,268)22.672
2262 Totl of Pro Plant Depreciation by Facor
1 4, 13,94 )96.888
223
226
2265 108TP Transmisson Plant Accumulated Depr
2266 T SG
2267 T SG
2268 T SG
2269 Totl Trans Plant Accum Depreciation B17
.
REVSED PROTOCOL Page 2.37
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DeSCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.270 108360 Land and Land Rights
271 DPW S (5,276,092)(5,058,312)(217,780)(217,780)
272 817 15,278,92)(5,058,312)(217,780)(217,780)
2273
2274 108361 Strure and Imprvements
2275 DPW S (15,722,519)(15,188,692)(533,827)(533,827)
226 817 115,722,519)(15,188,692)(533,827)(533,827)
2277
2278 10832 Statin Equipment
2279 DPW S (168,215,913)(160,713,306)(7,502,607)(7,502,607)
2280 817 1168,215,913)(160,713,306)(7,502,607)(7,502,607)
2281
2282 108363 Stra 8attery Equipmnt
2283 DPW S (413,993)(413,993)
2284 817 (413,993)(413,993)
2285
2286 108384 Poles, Towrs & Fixres
2287 DPW S (429,399,408)(405,299,222)(24,100,186)118,687 (23,981,299)
2288 817 1429,399,408)(405,299,222)(24,100,186)118,887 (23,981,299)
2289
2290 108365 Over Conucor
2291 DPW S (243,480,744)(231,527,196)(11,953,548)(11,953,548)
2292 817 1243,480,744)(231,527,196)(11,953,548)(11,953,548)
2293
2294 108366 Undergd Conduit
2295 DPW S (109,395,401 )(106,175,695)(3,219,705)(3,219,705)
22 817 Î109,395,401ì (106,175,695)(3,219,705)(3,219,705)
227
2298 108367 Undrgl'nd Conuct
229 DPW S (228,125,886)(215,863,117)(10,462,769)(10,482,769)
2300 817 (228,125,886ì (215,863,117)(10,462,769)(10,482,769)
2301
2302 108368 Une Transfoer
2303 DPW S (349,591,323)(322,815,426)(28,775,897)(26,775,897)
2304 817 (349,591,323)(322,815,426)(26,775,897)(26,775,897).305 Serv306108369
307 DPW S (145,434,084)(134,832,353)(10,601,731)(10,601,731)
2308 817 (145,434,084ì (134,832,353)(10,601,731 )(10,601,731)
239
2310 108370 Meters
2311 DPW S (82,548,535)(76,998,945)(5,549,590)(5,549,590)
2312 817 182,548,535)(76,998,945)(5,549,590)(5,549,590)
2313
2314
2315
2316 108371 Installations on Custoers' Premises
2317 DPW S (5,894,862)(5,757,901)(136,962)(136,962)
2318 817 15,894,862ì (5,757,901)(136,962)(136,962)
2319
2320 108372 Lease Propert
2321 DPW S (41,533)(36,825)(4,708)(4,708)
2322 817 141,533)(36,825)(4,708)(4,708)
2323
2324 108373 Strt Ughts
2325 DPW S (20,482,590)(20,215,990)(286,600)(266,600)
2326 817 120,482,590ì (20,215,990)(266,600)(266,600)
2327
2328 108000 Uncassified Dist Plant. Ace 300
2329 DPW S
2330 817
231
2332 108DS Uncassifed Dist Sub Plant - Ace 300
2333 DPW S
2334 817
2335
2336 108DP Uncassifed Dist Sub Plant. Ace 300
2337 DPW S
2338 817
2339.340
341 Totl Distrbuton Plant Accum Depreciation B17 (1,802,022,882)(1,700,696,971)(101,325,911 )118,887 (101,207,024)
342
2343 Summary of Distrbutin Plant Depr by Factor
234 S (1,80,022,882)(1,700,696,971)(101,325,911)118,887 (101,207,024)
2345
2346 Totl Disbun Dereiation by Factor 817 (1,802,022,882)(1,700,696,971)(101,325,911)118,887 (101,207,024)
REVISED PROTOCOL
Page 2.38
Beginning/Ending
FERC BUS UNAJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.l 108GP General Plant Accmulated Depr
G.SITUS 5 (146,54,967)(134,712,50)(11,831,463)44,593 (11,788,890)
G-DGP SG (8,43,401 )(7,529,46)(514,355)(514,355)
2350 G.DGU SG (15,450,484)(14,462,465)(988,18)(988,18)
2351 G.SG SG (40,139,148)(37,572,353)(2,566,795)16,434 (2,550,381)
2352 CUST CN (5,920,313)(5,879,726)(240,587)1,413 (239,174)
2353 PTD SO (89,871,749)(84,521,811)(5,350,137)13,840 (5,338,298)
2354 P SE (478,24)(446,539)(31,485)20 (31,465)
2355 G-SG SSGCT (56,489)(52,305)(4,164)19 (4,145)
2358 G-SG SSGCH (2,n1,824)(2,810,132)(161,692)436 (161,256)
2357 817 (309,275,399)(287,586,682)(21,688,716Î 76,754 (21,611,962)
2358
2359238 10BMP Mining Plant Accmulated Depr.
2381 P S
2382 P SE (154,578,471 )(144,397,217)(10,181,254)(1,303)(10,182,558)
238 817 (154,578,471)(144,397,217)(10,181,254)(1,303)(10,182,558)
238 108MP Less Centrlia Situs Depration
2385 P S
236 817 (154,578,471)(144,397,217)(10,181,254)(1,303)(10,182,558)
2367
2388 1081390 Acm Depr - Capitl Lease
2389 PTD SO 817
2370
2371
2372 Rem Capitl Leases
2373 817
2374
2375 1081399 Accm Depr - Capil Lease
2378 P S
2377 P SE 817
2378
2379
2380 Remove Capil Leases
-'817
382
83
384 Total General Plant Accum Depreciation B17 75,451 31,794,520)
2385
2386
2387
2388 Summai of General Depreation by Factor
2389 5 (146,543,987)(134,712,504)(11,831,483)44,593 (11,788,890)
2390 DGP
2391 OGU
2392 SE (155,056,496)(144,843,756)(10,212,739)(1,284)(10,214,023)
2393 SO (89,871,749)(84,521,611 )(5,350,137)13,840 (5,338,298)
2394 CN (5,920,313)(5,679,726)(240,587)1,413 (239,174)
2395 SG (63,633,032)(59,563,865)(4,069,168)16,434 (4,052,734)
2396 DEU
2397 SSGCT (58,469)(52,305)(4,184)19 (4,145)
2398 SSGCH (2,n1,824)(2,610,132)(161,692)43 (161,256)
2399 Remove Capital Leases
...
2400 Total General Deprecatin by Facr (463,853,870)(431,983,899)(31,869,970)75,451 (31,794,520)
2401
2402
2403 Totl Accum Depreciation - Plant In Service B17 6,053,908,945)(5,679,545,496)1,207,720 373155,729)
2404 111SP Accm Prov fo Amort-Steam
2405 P SSGCH
2406 P SSGCT
35,152)
2407 818
,15
2408
2409
2410 111GP Accm Prv for Amort.General
2411 G-SITUS S (16,629,267)(16,629,267)
2412 CUST CN (1,882,804)(1,787,104)(75,700)(75,700)
2413 I-5G SG (547,837)(512,804)(35,033)(35,033)
2414 PTD SO (6,311,685)(5,935,945)(375,740)(375,740)
2415 P SE -.
-"818 (25,351,593)(24,865,121)(486,472)(486,472)
417
REVSED PROTOCOL
Page 2.39
Beinning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT OESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
e'9 111HP Acm Prov fo Amort-Hyro
420 P SG (34,575)(322,541)(22,035)(22,035)
2421 P SG
2422 P SG (3,017)(2,824)(193)(193)
2423 P SG ~292,800)~274,076l (18,724)(18,724)
2424 B18 640,392)599,441 (40,951)(40,951)
2425
2426
2427 1111P Acm Prov for Amort.lntangible Plant
2428 I-ITUS S (715,816)(30,784)(665,032)(665,032)
2429 I-DGP SG (1,422,439)(1,331,478)(90,961)(90,961)
2430 I-DGU SG (310,163)(290,329)(19,834)(19,83)
2431 P SE (790,384)(738,326)(52,058)(52,05)
2432 I-5G SG (29,988,205)(28,070,537)(1,917,668)(1,917,66)
2433 I-G SG (10,850,007)(10,156,177)(693,830)54,730 (639,100)
243 I-SG SG (2,56,044)(2,403,824)(164,220)14,785 (149,435)
2435 CUST CN (7 ,207,762)(74,070,227)(3,137,535)(3,137,535)
2436 P SSGCT
22,99 22,99
2437 P SSGCH (17,091)(16,94)(997)(997)
2438 PTD SO (241,083,157)(226,731,283)(14,351,874)15.231 (14,33&,843)
2439 618 (36,953,068)(343,839,058)(21,114,010)107,739 (21,006,271)
2440 1111P Les Non-Utilit Plant
2441 NUTIL OTH --..
2442 (36,953.068)(343,839,058)(21,114,010)107,739 (21,006,271 )
2443
244 111390 Acm Amtr . Capitl Lease
2445 G-SITS S
2446 P SG
2447 PTO SO
2448
2449
2450 Ra CII... Ar
2451~Tot Accum Provision fo Amortzation B18 (391,421,787)(369,745,202)(21,676,585)107,739 (21.568,846)
53
454
455
2456
2457 Summary of Amorttion by Factor
2458 S (17,345,083)(16,660,051)(685,32)(685,032)
2459 DGP
2460 DGU
2461 SE (790,38)(738,326)(52,056)(52,058)
2462 SO (247,394,842)(232,667,228)(14,727,613)15,231 (14,712,383)
2463 CN (79,070,56)(75,857,331)(3,213,235)(3,213,235)
246 SSGCT (476,735)(441,583)(35,152)22,994 (12,158)
2465 SSGCH (17,091)(18,094)(997)(997)
2466 SG (46,327,087)(43,36,590)(2,962,497)69,514 (2,892,983)
2467 Le Capitl Lease -.-..
2468 Total Prosion For Amotion by Facor (391,421,787)(369,745,202)(21.676,585)107,739 (21,568,846)
,
Pa 3.0 TotIDAHO REVISED PROTOCOLRev Adjus (Tab 3)
TOTAL
3.&3.53.43.33.23.1.Elfec Pnc S02 Emrsi wi Rev Gi TagCha Al Adj RevsRevnuNoIiTemTot Noed Noiliz
1 Opein Rev:
2 Ge Bu Revens3 inpa4 Spe sa
5 Ot Ope Revues
8 Tot Op Reveue
78 Ope Exses:9 stea Pro10 Nu Pn11 Hy Pro12 Ot Pow Su13 Tra14 Dl15 Cii Acc
18 Cii 8e & Info17S..18 Adm & Ge
19 Tol O&M Ei20 De21 Amo
22 Tex Ot Than Inc23 In Tex: Fed24 Si.25 De Inc Tex
28 Inv Tax Cr Adj.27 Mil Rev & Ex28 Tot 0p Exs:
2930 Op Rev For Ret:
31
32 Rate Be:
33 EIe PI8 In Serv
34 PI Hel for Fut Use35 Mil Deem De
3& EJ PIe Acq Adj37 Nu Fue
3& Prei
3l Fue st
40 Maer & Supi41 Wo Cepal42 Weatti Loei
43 Mi Rii Base44 Tot EJ Pla
4548 Des:47 Acc PlO For De
4S Acc PlO For Amo
49 Ace De inc Tax
50 lJmoed ITC
51 Cii Mv For Conit
52 Cuom 8e De53 Misc De
5455 Tot De:
5&
57 Tot Rate Base:
58
5980 Est ROE im
81
82
83
84 TAX CALCULATION:
65
88 Opra Revenue
87 Ot Dedueon
88 Intst (AFUDC)891nt70 Scle "M Add71 SC °Mo De
72 Inc Befor Tax
73
74 Stae inc Tax..
75
78 Taxbl Inc
7778 Fedlnce Tex
11,758,835,79,128(80,793)1&,744,9&7
1,208,993 281,84
1,208,993 281,84
/;)~. '-!!:P ~~.. ...~'." ~('1/\. .-':; ....
?:~~.; ., i. ';¿o ~(\,~ (;~/':"", ... ~L,~~
1,081,087
17,82,05 11,758,835,790,128(80,793)
40,937 87,418
54,88 11,8793,928,877
53,8421,93,53g
28,872(28,55)
(3&,492)
5,955,88
80,30
(30,773)(30,773)
792,529
491,75&
792,529
7,25&,92 458,825 99,2974,46,5192,197,411(305,047)
(498,745)750,188 182,348(491,75&)7,29,1143,592,71810,5&9,131
.
89,158892,158
(2,35,872)(2,35,872)
(1,45,71)
(1,45,714)
(1,458,714)
(1,458,714)
0.30% 0.06%-0.165%2.99%1.474%-0.20%4.3&7%
1,20,993 281,84(792,529)11,758,835,790,12&(803,793)17,033,524
96,80
173,277
96,80
173,277
17,828,05.1,208,993 281,8411,758,8335,790,128(80,793)
54,88 11 ,87953,84228,872(3&,492)80,303
1,154,104 249,78811,224,7915,527,255(7&7,30)17,01&,750
403,937 87,4183,928,8771,93,539(288,55)5,95,88
IDAHO REVSED PROTOCOL Pa 3.0,1 Tot
Reve A~ (Tab 3)
TOTAL
3.7 0 0.0 0 0.0 0 0.Reme ClarkStorge Rev 0 0 0 0 0 0
1 Ope Rev:
2 G- Buli Revenuea3 Inler4 Sp sas
5 QI Openg Revenus (38,55)
8 Tot Opli Revs (3,55)
7
8 0p Exses:9 Ste Pro10 Nuc Pro11 Hy Pro12 Ql Po Su13 Trami
14 Dili15 Cuto Acin18 Ciito Se & Inf
17 sa18 Admtl & Ge
19 Tol O&M Ex20 Det121 Amtl22 T_ QlTh Inc23 Inc Tax..: Fed (130,153)
24 Sta (17,881
25 Deei Inc 'tax..
28 Innt Tax Cre Adj.
27 Mis Rev & Exse
28 Tol 0p Ex:(147,83)
29
30 0p Rev For Retur:(241,712)
31
32 Ret Base:33 Eie Plaln Se.34 Pl Hel fo Fut use:l Mi De De
38 E1 Pla Ac Adj37 Nu Fue38 Pn
39 Fue Sto40 Maer & Su41 WO Cap42 we LOl
43 Mi Ret Baae
44 Tot Ei Pla
45
46 De:47 Ac Pro For Dep
48 Ace Pro For Am48 Ac De Inc Tix50 Ur ITC
51 Cua Adv For COnl52 Ciilom Sar De53 MII De
54
55 Tot Deuc
58
57 Tol Rate Base:
58
5980 Ested ROE im -0.09%O.lJ 0.0l 0.0l 0.0l 0.0l 0.0l
81
62
83
84 TAX CALCULATION:
85
86 Ope Revnu (38,550187 QI De
86 Int(AFUDCI
69 Int70 Sc "M Add.71 SC "M De
72 inc Be Tix (38,55)
73
74 Stae inc Taxs (17,88)
75
78 Tax In (371,88)
77
78 Fed Inc Taxes (130,153)
Rocky Mountain Power PAGE 3.1
Idaho Results of Operations December 2007.Temperature Normalization
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Residential 440 1 334,943 ID Situs 334,943
Commercial 442 1 (1,138,736)ID Situs (1,138,736)
Total (803,793)(803,793)3.1.1
.
Description of Adjustment:
This adjustment normalizes revenues in the test period by comparing actual loads to temperature normalized loads. Weather
normalization reflects weather or temperature patterns which were measurably different than normal, as defined by using 30-year
historical studies by the National Oceanic & Atmospheric Administration. Only residential and commercial sales are considered
weather sensitive. Industrial sales are more sensitive to specific economic factors. This revenue adjustment corresponds with
temperature adjustments made to system peak, energy loads and net power costs,
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Description of Adjustment:
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Rocky Mountain Power PAGE 3,3.Idaho Results of Operations December 2007
Effective Price Change
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Residential 440 2 10 Situs
Commercial 442 2 10 Situs
Industrial 442 2 10 Situs
NuWest 442 2 10 Situs
Monsanto-Firm 442 2 473 10 Situs 473
Monsanto-Non Firm 442 2 8,179 10 Situs 8,179
Monsanto-Curtailed 442 2 10 Situs
Public Street Lighting 44 2 10 Situs
Other Sales to Public Authorities 445 2 10 Situs
Total Type II Adjustment to Income 8,652 8,652 3,1,1
Residential 440 3 2,678,642 10 Situs 2,678,642
Commercial 442 3 45,775 10 Situs 45,775
Industrial 442 3 2,208,589 10 Situs 2,208,589
NuWest 442 3 249,352 10 Situs 249,352
Monsanto-Firm 442 3 353,981 10 Situs 353,981
Monsanto-Non Firm 442 3 5,863,427 10 Situs 5,863,427
Monsanto-Curtailed 442 3 149,229 10 Situs 149,229
Public Street Lighting 44 3 200,986 10 Situs 200,986
Other Sales to Public Authorities 445 3 10 Situs
Total Type II Adjustment to Income 11,749,981 11,749,981 3.1.1.
Description of Adjustment:
The type 2 adjustment annualizes 17 hours of usage by Monsanto on December 31, 2006 at lower rates. Docket No, PAC-E-06-Q4
increased rates effective January 1, 2007, Therefore, an adjustment was necessary to reflect the price change.
The type 3 adjustment reflects the revenue increases as stipulated in Idaho rate case PAC-E-Q7-Q5, An all part settlement was
reached and a stipulation filed with the commission on November 6,2007. The stipulation was approved by the Commission on
December 28, 2007 with an effective date of January 1, 2008 increasing rates by $11.5 millon, Therefore, it is necessary to reflect the
effects of this price change into results. Using December 2007 loads results in $11.75 milion of revenue..
Rocky Mountain Power PAGE 3.4.Idaho Results of Operations December 2007
802 Emmission Allowances
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Income:
Gain From Sale of Allowances 4118 1 14,663,498 SE 6.586%965,806 3.4.1
Allowed Gain From Sale of Allowance!4118 1 (2,630,802)SE 6.586%(173,277)3.4.1
12,032,696 792,529
Adjustment to Rate Base:
Accumulated Deferred Income Taxes 190 1 13,545,326 SE 6,586%892,158 3,4,1
Regulatory Deferred Sales 25398 1 (35,692,484)SE 6,586%(2,350,872)3.4,1
(22,147,158)(1,458,714)
Adjustment to Taxes:
Schedule M Addition SCHMAT 1 14,663,498 SE 6,586%965,806 3.4.1
Schedule M Deduction SCHMDT 1 2,630,802 SE 6.586%173,277 3,4.1
DIT Expense 41010 1 998,416 SE 6.586%65,760 3.4.1
DIT Expense 41110 1 (5,564.944)SE 6,586%(366,533)3.4,1
.
.
Description of Adjustment:
This adjustment reflects the gain on sales of S02 allowances amortized over a fifteen-year period.
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.Rocky Mountain Power
Semi Annual Report - December 2007
S02 Emmission Allowance Sales
3.4.2
ë,ccount .Edit .loto Eir~ItOnrnerli :3'i'::telr Help'~~ _~""s'tr~'''''_~_N~'I_,,''~'''~~''4'~~. '~v~ ;,~\",:q?; ~ ~:;j.'cieli~",\t'!¡~~'i;i'~tj,:æ'.:~Ril¡~~~ff~~g _ ~:~::to:~~J~~~~~4~~~~~~;w
GIL Account Balance Display
..1,322,500.00
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. 2,897,500.00
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14.663,498.13-
Rocky Mountain Power PAGE 3.5
Idaho Results of Operations December 2007.Wheeling Revenue Adj
TOTAL IDAHO
ACCOUNT Ig COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Revenue:
Other Electric Revenues 456 1 (277,028)SG 6,395%(17,715)3.5.2
Other Electnc Revenues 456 2 294,642 SG 6.395%18,842 3,5,2
Other Electric Revenues 456 3 17,931,776 SG 6.395%1,146,691 3.5,2
Other Electric Revenues 456 3 928,810 SE 6,58%61,176 3,5.2
Adjustment Detail:
Actual Wheeling Revenues
Total Adjustments
Normalized Wheeling Revenues
56,190,220
18,878,200
75,068,420
3,5.1
3,5,2
3.5.2
.
Description of Adjustment:
The Company expects to receive additonal amounts over CY2007 levels regarding the Malin-Indian Springs contract. Also,
there were various transactions regarding wheeling revenues during CY2007 that the Company does not expect to occur in the
twelve months ended December 2008. These transactions relate to various prior period adjustments and contract terminations,
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Rocky Mountain Power PAGE 3,6.Idaho Results of Operations December 2007
Green Tag Revenues
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Other Electric Revenues 456 1 681,684 SG 6.395%43,592
Other Electric Revenues 456 1 (42,856)CA Situs
Other Electric Revenues 456 1 (638,828)OR Situs
43,592 3.6,1
Other Electric Revenues 456 3 3,409,868 SG 6.395%218,052
Other Electric Revenues 456 3 (33,833)CA Situs
Other Electric Revenues 456 3 (504,319)OR Situs
2,871,716 218,052 3.6,1
.
.
Description of Adjustment:
A market for green tags or Renewable Energy Credits is developing where the tag or "Green" traits of qualifying power
production facilties can be detached and sold separately from the power itself, These green tags or credits are applied to help
states with Renewable Portolio Standards meet those goals. Wind, solar, geothermal and some other resources qualify as
renewable resources, each state may have a slightly different definition. California and Oregon have Renewable Portolio
Standards that limit the Company's abilty to sell green tags. This adjustment reverses actual sales and allocates the sales for
the 12 months ended December 2008 to the remaining jurisdictions.
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.Rocky Mountain Power Page 3.6.2
Semi Annual Results. December 2007
Green Tag Revenues
Incremental
Description Amount Change
December. 2007
Total Other REC Sales 1,646,375 To 3.6.3
Salt River Project Sales 2,080,738 To 3.6.3
Green Tag Revenues 3,727,113
December. 2008
Foote Creek i 103,423
Glenrock Wind 1,328
Goodnoe 164,423
Leaning Juniper 307,717
Seven Mile 1,434
Rollng Hils 1,026
Marengo 505,098
Total Wind Generation 1,084,448
Rock River I 143,089
OF Mountain Wind 193,417
Wolverine Creek 166,068
Total REC MWH 1,587,022
ID/UTIWAI - Portion 70.72%.Bank CAlOR - Portion 29,28%
MWh Available to Sale 1,122,323
Percent Sold 75%
MWhSoid 841,742
Sales Price $3.50
Green Tag Revenues 2,946,097 1,299,722 To 3.6.1
Blundell 1,566,769 1,566,769 To 3.6.1
Salt River Project 2,085,963 5,225 To 3.6.1
Green Tag Revenues 6,598,829 2,871,716
.
.
.
.
Rocky Mountain Power
Semi Annuai Result. Deember 2007
Gren Tag Revenues
3.6.3
Wind/Other REC Salt River Projec
262,500 $ 176,700.00
468,475 $ 159,600.00
30,013 $ 176,462.50
5,225 $ 171,237.50
210,163 $ 176,700.00
5,700 $ 171,000.00
226,800 $ 176,700.00
$ 176,700.00
5,700 $ 171,00.00
(5,700.00) $ 176,700.00
5,463 $ 171,237.50
432,037.50 $ 176,700.00
1,646,375 2,080,738
Rocky Mountain Power PAGE 3.7.Idaho Results of Operations December 2007
Remove Clark Storage Revenues
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Other Electric Revenue 456 1 (6,091,730)SG 6.395%(389,550)3,7,1
.
.
Description of Adjustment:
The Clark Storage & Integration Agreement was terminated in December 2007, This adjustment removes the revenue credit from
results of operations to reflect a normalized level of ancilary service revenues.
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IDAHO REVED PROTOC Pag 4.0 ToI
O&M Adstm (Tab 4)
TOTAL
4.1 4.2 4.3 4.4 4.5 4.6.Wag & Ben Wag & Be Wa & Befi Wag & Benefi Mis Adjstmnt.Adjstmt.Adjus .Adnt .MEHC Trasit
Totl Nolled Gel Ex Aniiti 1 AMliz 2 Pra 1 Pro 2 Savins
1 () R8V:2 Gal Busis Rev.3 1nt4 Sp Sal5 Ot Opti Revs
6 ToI Opng Raveue
7
6 Op Expes:9 Ste Pr 103,60 22,613 60,99
10 Nuii Pro11 Hy Pn 76,079 3,08 11,047
12 Ot Po Sup 1,461,596 (1,33)8,161 29,29 (2,916)
13 TI'(3,35)3,211 11,50 (11.674)
14 Il 88,931 (379)13,09 7,887 50,96 35,079 (19,712)
15 Cuto Acg 58,392 8,469 34,041 (7)
16 Cuii Se & In (2,049,90)(1,35)1,52 6,411
17 sa18 Adtr & Ge 95,60 (8,7021 14,661 52,511 341,99
19 Tot O&M Ex'714,951 (11.765)50,162 32,53 183,732 128,042 266,915
20 De21 Ar 17.85)
22 Taxs 0l Than Inc23 In T_: Fed (156,488)3,931 (16,759)(10,871)(61,387)(42,760)(95,881)
24 SII (21,26)53 (2,277)(1,477)(8,341)(5,8131 (13,02)
25 De In Taxa.(3,472)
26 in Tax Cr Adj27 Mi Rev & Ex (229,516)
28 Tot 0p Ei"':298,357 (7,30)31,125 20,189 114,00 79,449 178,028
29
30 Op Rev For Ret:(2,357)7,30 (31,125)(20,189)(114,00)(79,449)(178,028)
31
32 Rii Be:
33 EIe Plant In Se (119,4291.34 PI He lo Fut Us35 Mis De De 6,759
38 EI PI Acq Ad
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38 Fue Sto
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43 Mi Rate Bae =;m
44 Tot EIe Plan (112,670)
.~C)
45 0 m
46 Dø:..
47 Ac Pi For De ~
4S Ac Pi For Am 17,275 rn
49 Acm De In Tax (58,787)0
50 u- IT
51 CuMv ForConst fA
52 Cus Se Deit ..
53 Ml8nas De ~
54
55 Tota Dø:(41,512)
56
57 Tot Ra Ba (154,182)
58
59
60 Eslled ROE im -0.118%0.00%-0.013%-0.00%-0.047%-0.033%-0.073%
61
62
63
84 TAXCALCULATlN:
6566 Opti Raven (477,581 11,765 (50,162)(3,531 (183,732)(128,042)(288,915)
67 Ot Døs
68 Intst (AFDCI
69 Intst70 Sch "M Adns.71 Schule"M" Dens (9,20)
72 In Be Tax (46,373)11,765 (50,162)(32,53)(183,732)(128,042)(288,915)
73
74 SII Inc Taxes (21,26)53 (2,27)(1,477 (8.341)(5,813)(13,26)
75
78 Tax in (447,1091 11,231 (47,881 (31,059)(175,391)(122,229)(273,889)
77
78 Fødlnc Taxes (156,4881 3,931 (16,7591 (10,871)(81,387)(42,760)(95,881)
IDAHO REVISED PROTOCOL
Pa 4.0.1 Tot
O& Adjusun (Tab 4)
TOTAl.4.7 4.8 4.9 4.10 4.11 4.12 4.13 4.14
lnat Loa
Con Prra Incl Postage Ince Rem Non K2 Risk Mgml AIlMgtFee
Ad Gen O&M Ad)GRID West Rew Ble Sky Syste Adj(MEHC)
1 Opng Revenues:2 Gø Busiss Revues3 lntnla4 Spe Sas
5 Ot Opti Revenu
6 Tot 0p Revens
7
8 Opng Exses:9 Slell Pr10 Nu Prouc11 Hy Pro $3,947
12 Ot Po Supply 1,114,93 57,0813 Tni (6,39)
14 D1ti15 eu ACC 7,590 9,070
16 eu Sø & Inf (8,4&)
17S..18 Adstne & Ge1 (8l,072)(11,706)(48,67?l (98,221)
19 Tot O&M Exns 1,114,93 577,08 7,590 (22,449)(20,170)(48,679)(98,221)
20 De21 Amli (7,85)
22 T_OlThlnc
23 in Tiis: Fed (372,511)(192,80)(2,531 35,378 6,73 67,8l 32,817
24 Stae (50,818)(28,199)(34)4,807 918 9,198 4,45
25 Qe inc Tiis
26 Intm Tix Cr Ad27 Mil Rev & Exse (83,441 (148,078l
28 Tot Op Expses:891,80 35,073 4,710 Î85,703Î (12,515 t125,718Î (60,845)
29
30 Op Rev Fo Ret:(61,80)(35,07)(4,710)85,703 12,515 125,716 80,94
31
32 Rat8ae:.33 EI Ptln Ser
(119,42)
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37 Nuc Fue36 Prymts
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43 M'is Rat Ba
44 Tot EIe I'
(119,429)
45
48 De47 Ac Pr For De48 Ac Pr Fo Am
17,275
49 Ac De in Tix
50 unmoed ITC
51 Cust Adv For Cosl52 Cusr Sø Desit53 Miscii Dø
54
55 Tot Des:17,275
58
57 Tot Rat Ba:
(102,154)
58
59
80 Estat ROE impa -0.284%-0.147%-0.00%0.00 0.027%0.00%0.05%0.025%
61
62
63
84 TAX CACULTION:
85
66 Opti Revenue (1,114,931 (577,08)(7,590)105,888 20,170 202,60 98,221
67 Ot Des
88 Intsl(AFUOC)
89 Inst,70 SclIe"M" Adds71 Sc "M" Deuc
72 in Be Tix (1,114,93)(577,0801 (7,590)105,888 20,170 20,60 98,221
7374 Sta inc T_(50,816)(26.199)(345)4,807 918 9,198 4,459
7578 Tiibl in (1,06,317)(55,881)(7,248)101,081 19,254 193,410 93,781
77
78 Fed in Taxs (372,511)(192,801 (2,53)35,378 8,73 87,893 32,817
IDAHO REVED PROOC Pa 4.0.2 Tot
O&M Adj (Tab 4)
TOTAL
4.15 4.16 4.17 4.16 4.19 4.20 0.00 0.A&GCOI ID Pe
DSM Amti Cort Pr Co Plan Memip' &Id Inen Exse cash
Remal (MEHC)Ei Subsas Funin Basi 0 0
1 Op Revens:2 Gel Buss Reven3 int
4 Sp Sales
5 Ot Opng Revenu
6 Tot Op Revue
7
8 Opti Exse:9 Ste Pruc10 Nuc Pr11 HydPr12 Ot"-Sup (23,56113 TI'14 Di15 CUlto Acc18 Cu 5e & In (2,04,02)
17 sa.
18 Adstr & Gera (225,6241 (22,977 28,86 1,02,555
19 Tot O&M Ei (2,048,020)(22,624)(223,56)(22,977)28,865 1,02,55520 De21 Amli
22 T_ Ot Th in23 In T_: Fed 68,26 75,38 74,684 7,677 (9,64)(39,901
24 S1 92,98 10,243 10,150 1,04 (1,310)(46,186)
25 om inc Tues (3,472)
26 I~Tu CiilAdj.27 Mis Rev & Exse
28 Tot Opti Ei.:(1,270,776)(139,997)(138,717)(14,257)17,910 63,99
29
30 Op Rev For Ret:1,270,776 139,997 138,717 14,257 (17,910)(63,991
31
32 R8I BaI8:33 EIe PIIn Serv.34 PI He fo Fut Use35 Mi om De 6,759
36 Ele PI Ac Ad37 Nu Fue38 Prls
39 Fue Sto40 M8I & Sups41 Wo Capl42 Wøa Lo
43 Mis R8I Base
44 Toi E1 Plant 6,759
45
46 Dø:47 Ac Pr For De
46 Ac Pr For Am49 Ac De Inc Tu (58,787)
50 un ITC
51 Cu Ad For Co
52 Cu Seric Depo53 Mlne Dø
54
55 Toi Dø:(58,787)
56
51 Toi R8I Base:6,759 (58,787)
58
59
60 Estted ROE im 0.521%0.057%0.057%0.00%-0.00 -0.26%0.00 0.00
61
62
63
64 TAX CALCULATIO:
65
68 Opng Reven 2,04,020 225,624 223,56 22,977 (28,86)(1,02,55)
51 Ot Decl.
68 In (AFUOC)
69 Int.70 Sch"M" Adds71 Sch "M" Deucs (9,201
72 In Be Tu 2,048,020 225,624 223,56 22,977 (28,86)(1,017,341
73
74 Sl8lnc Tues 92,98 10,243 10,150 1,043 (1,310)(46,168)
7578 Tax inc 1,95,04 215,381 213,410 21,933 (27,555)(971,159)
77
78 Fedral Inc Tues 68,26 75,383 74,694 7,677 (9,641 (339,90)
Rocky Mountain Power
PAGE 4.1
Idaho Results of Operations December 2007
Miscellaneous General Expense.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Miscellaneous General Expnse 557 1 .(16.894)SG 6.395%(1,080)
Miscellaneous General Expense 909 (33,217)CN 4,06%(1,350)
Miscellaneous Genera Expnse 921 (42,652)SO 5.953%(2,539)
Miscellaneous General Expense 921 (202)WYE Situs
Miscellaneous General Expense 923 1 (82,434)SO 5.953%(4,907)
Miscellaneous General Expense 546 1 (3,975)SG 6,395%(254)
Miscellaneous General Expense 580 1 (7,119)SNPD 4.611%(328)
Miscellaneous General Expense 598 1 (1,100)SNPD 4.611%(51)
Miscellaneous General Expense 930 (128,625)UT Situs
Miscellaneous General Exense 930 (21,087)SO 5.953%(1,255)
Total Miscellaneous General Expense Removal (337,305)(11,765)4,1,1
t
Decription of Adjustmnt:
This adjustment removes from results of operations certin miscellaneous expenses that should have been charged to non-reulated .acounts.
,
.Page 4.1.1
PacifiCorp
December 2007 Semiannual
Miscellaneous General Expense
Adjustment Summary
FERC Amount to
Description Account Factor Exclude Ref
Review Adjustments 557 SO 16~894 4.1.2
Review Adjustments 909 eN 33,217 4.1.3
Review adjustments 921 SO 42,652
Review adjustments 921 WYP 202
Tota Account 921 Review 42,854 4.1.4
Review adjustments 923 SO 82~434
Review adjustments 923 UT 2,588.Review adjustments 546 SO 3~975
Review adjustments 580 SNPD 7~1 19
Review adjustments 598 SNPD 1~100
Tota Account 923 Review 97~216 4.1.5
Review adjustments 930 UT 128~625
Review adjustments 930 SO 21,087
Tota Account 930 Review 149~712 4.1.6
TOTAL $339~893 T04.l
.
.
.
.
Pacifcorp
December 2007 Semiannual
Miscellaneous General Expense
FERC Account 557 Review - Items to Remove
Description
Charitable Donations & Sponsorships
Scottish Power Intemation Assignee Tax Fees
FERC
Account
557
557
Factor
SO
SO
Page 4,1.2
Amount to
Exclude Ref
15,600
1,294
16,894 To 4.1.1
.
.
.
Pacifcorp
December 2007 Semiannual
Miscellaneous General Expense
FERC Account 909 Review - Items to Remove
Description
Charitable Donations & Sponsorships
Mise Advertising Expense
FERC
Account
909
909
Factor
CN
CN
Page 4.1.3
Amount to
Exclude Ref
25,702
7,515
33,217 To 4.1.1
.
.
,
Pacifcorp
December 2007 Semiannual
Miscellaneous General Expense
FERC Account 921 Review -Items to Remove
Description
Charitable Donations and Sponsorships
Employee Gifts, Flowers, Paries, Cake
Employee Gifts, Flowers, Paries, Cake
Economic Development Corp of Utah
Legislative & Lobbyist
Legislative & Lobbyist
Misc Expense
Rach & Cabin
Retirement Paries
Retirement Paries
Scottish Power
FERC
Account
921
921
921
921
921
921
921
921
921
921
921
Factor
SO
SO
WY
SO
SO
WY
SO
SO
SO
WY
SO
Page 4,1.4
Amount to
Exclude Ref
1,423
4,722
12
5,788
14,739
176
7,076
2,456
6,439
15
9
42,854 To 4.1.1
,
,
,
Pacificorp
December 2007 Semiannual
Miscellaneous General Expense
FERC Account 923 Review - Items to Remove
Description
Ranch Expenses
Rebranding Expense
LegislativelLobby
Mise Expense
Scottish Power Internation Assignee Tax Fees
Scottish Power Internation Assignee Tax Fees
Scottish Power Internation Assignee Tax Fees
Scottish Power Internation Assignee Tax Fees
Scottish Power Internation Assignee Tax Fees
Retiree Ambassador Expense
FERC
Account
923
923
923
923
546
580
598
923
923
923
Factor
SO
SO
SO
SO
SO
SNPD
SNPD
SO
SO
SO
Page 4.1.5
Amount to
Exclude Ref
21,822
18,636
5,630
6,032
3,975
7,119
1,100
20,905
6,025
3,384
94,628 To 4.1.1
.
,
,
Pacificorp
December 2007 Semiannual
Miscellaneous General Expense
FERC Account 930 Review - Items to Remove
Description
Advertising/Sponsorships
Advertising/Sponsorships
Civic Activities
Uta Sport Commission Rent Donation
Uta Economic Development Corporation of Uta Rt
Uta Economic Development Corporation of Utah Rt
FERC
Account
930
930
930
930
930
930
Factor
SO
UT
SO
UT
UT
SO
Page 4,1,6
Amount to
Exclude
912
1,210
175
52,416
74,999
20,000
149,712
Ref
To 4,1.
.
Decription of Adjustment:
The Company has severl labor groups, each with differet effective contract renewal dates. The Company negotiates wage increases with each of
these groups throughout the year, This adjustment annualizes the wage increase during the base period for labor charged to operatin and maintenance
acunts. See page 4.5,1 for more information on how this adjustment was calculated.
Rocky Mountain Power PAGE 4.3
Idaho Result of Operations December 2007
Wage & Benefit Adjustment. Annualization 2.TOTAL IDAHO
ACCOUNT !m COMPANY FACTOR FACTOR % ALLOCATED ßS
Adjustment to Expense:
Distnbution Expense 593 2 34,979 10 Sits 4,881
Distnbution Expense 593 2 (3,562)SNPD 4.611%(164)
Distnbution Expense 594 2 46,490 10 Situs 1,554
Dlstnbution Expense 594 2 68 SNPO 4,611%3
Distnbution Expense 595 2 153 10 Situs
Distnbution Expense 595 2 926 SNPO 4,611%43
Distribution Expense 596 2 6,099 10 Sits 447
Distribution Expense 597 2 11,397 10 Sis 825
Distnbution Expense 597 2 2,089 SNPO 4,611%96
Distnbution Expense 598 2 1,922 10 Sit 37
Distribution Expense 598 2 3,593 SNPO 4.611%166
Customer Acunts 901 2 5,068 CN 4,06%206
Customer Accounts 901 2 709 10 Sits 31
Customer Accunts 902 2 1,490 CN 4,06%61
Customer Accunts 902 2 61,431 10 Sits 3,529
Customer Accunts 903 2 97,871 CN 4.06%3,977
Customer Accounts 903 2 15,991 10 Sits 64
Customer Accunts 905 2 512 CN 4.06%21
Customer Accunts 907 2 937 CN 4.06%38
Customer Service 908 2 8,165 CN 4,06%332
Customer Service 908 2 9,154 10 Situs 1,098
Customer Service 909 2 1,271 CN 4,06%52
Customer Service 909 2 10 Sits
Customer Service 910 2 10 Sits
Customer Servic 920 2 1,021 10 Sis
Administrative & General 920 2 240,672 SO 5.953%14,327
Administrative & General 921 2 10 Sits.Administrative & General 921 2 SO 5.953%
Administrative & General 922 2 (4,947)SO 5,953%(295)
Administrative & General 923 2 10 Sits
Administrative & General 923 2 SO 5,953%
Administrative & General 929 2 (2,268)SO 5.953%(135)
Administrative & General 935 2 122 10 Situ
Administrative & General 935 2 12,825 SO 5.953%763
Wage & Benefit Adj . Annualization 1 Total
Wage & Benefit Adj . Annualization 2 Total
Total Annualizatlon Adjustment
854,757
554,178.
1,408,935
50,162
32,536
82,698 4.5.2
Description of Adjustment:
The Company has several labor grops, each with diferent effective contract reewal dates. The Company negotiates wage increases with each of
these groups throughout the year. This adjustment annualizes the wage increase during the base period for labor charged to operation and
maintenance accunts. Se page 4,5.1 for more infoation on how this adjustment was calculated.
.
Rocky Mountain Power PAGE 4.4
Idaho Results of Operations December 2007
Wage & Benefit Adjustment. Proforma 1.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustmnt to Expense:
Steam Expense 500 3 1,259,727 SG 6,395%80,556
Steam Expnse 500 3 (5,421)SSGCH 5.833%(316)
Steam Expnse 501 3 11,382 SE 6,586%750
Hydro Expense 535 3 95,626 SG-P 6.395%6,115
Hydro Expense 535 3 77,132 SG-U 6,395%4,932
Other Power Generation 548 3 42,741 SG 6,395%2,733
Oter Powr Generation 548 3 30,713 SSGCT 7,373%2,265
Oter Powr Supply 557 3 377,936 SG 6.395%24,168
Oter Power Supply 557 3 860 SSGCT 7.373%63
Transmission Expense 560 3 179,86 SG 6.395%11,502
Distribution Expnse 580 3 74 10 Situs 13
Distribution Expnse 580 3 203,259 SNPD 4.611%9,372
Distribution Expense 581 3 128,242 SNPD 4,611%5,913
Distribution Expense 582 3 21,900 10 Situs 1,520
Distribution Expense 582 3 156 SNPD 4.611%7
Distribution Expense 583 3 70,972 10 Sits 2,161
DistribtilonExpense.-.583 3 .-----.5;387 -SNPD 4.611%248
Distribution Exnse 584 3 17 10 Situs
Distribution Expense 585 3 3,620 SNPD 4.611%167
Distrbution Expense 586 3 47,015 10 Situs 3,317
Distrbution Expense 586 3 11,364 SNPD 4,611%524
Distrbution Expense 587 3 95,211 10 Sits 8,229
Distribution Expense 588 3 27,156 10 Situs 1,08
Distribution Expense 588 3 207,976 SNPD 4.611%9,590
Distribution Expense 589 3 1,330 10 Sits 46
Distribution Exense 589 3 SNPD 4.611%.Distribution Expense 590 3 4,956 10 Situs 288
Distribution Expense 590 3 71,676 SNPD 4.611%3,305
Distribution Expense 592 3 63,920 10 Sits 3,568
Distribution Expnse 592 3 26,608 SNPD 4.611%1,227
Wage & Benefit Adj - Profora 1 Total 3,061,401 183,732
Wage & Benefit Adj - Proforma 2 Totl 1,984,847 128,042
Total Proforma Adjustmnt 5,046,248 311,775 4.5,2
Description of Adjustment:
The Company has several labor groups, each with diferent effecive contract renewal dates, The Company negotiates wage increases with each of
thse groups throghout the year. This adjustment recnizes these increases prospeively and adds them to operation and maintenance accunts. It
als normalizes pension, employe benefits, and incentives to levels the company wil incur for the 12 months ended December 2008. See page 4.5,1
fo more information on ho this adjustment was calculated.
.
Rocky Mountain Power
PAGE 4.5
Idaho Results of Operations December 2007
Wage & Benefit Adjustment - Proforma 2.TOTAL IDAHO
ACCOUNT In COMPANY FACTOR FACTOR % ALLOCATED BW
Adjustmnt to Expense
Distribution Expense 593 3 125,282 10 Situ 21,786
Distribution Expense 593 3 (12,757)SNPO 4,611%(588)
Distribution Expense 594 3 166,510 10 Sits 6,938
Distnbution Expense 594 3 244 SNPD 4,611%11
Distnbution Expense 595 3 550 10 Situs
Distribution Expense 595 3 3,317 SNPD 4.611%153
Distrbution Expense 596 3 21,84 10 Situs 1,994
Distribution Exense 597 3 40,818 10 Sits 3,684
Distrbution Expense 597 3 7,480 SNPD 4.611%345
Distnbution Expense 598 3 6,885 10 Sits 163
Distrbution Exense 598 3 12,867 SNPD 4,611%593
Customer Accunts 901 3 18,152 CN 4,06%738
Customer Accunts 901 3 2,541 10 Sit 138
Customer Accunts 902 3 5,337 CN 4.06%217
Customer Accunts 902 3 220,023 10 Sits 15,753
Customer Accunts 903 3 350,537 CN 4.06%14,245
Customer Accunts 903 3 57,273 10 Situ 2,875
Customer Accounts 905 3 1,832 CN 4.06%74
Customer Accounts 907 3 3,355 CN 4,06%136
Customer service 908 3 29,245 CN 4,06%1,188
Customer Service 908 3 32,784 10 Sits 4,901
Customer Service 909 3 4,554 CN 4.06%185
Customer Service 909 3 10 Sits
Customer Service 910 3 10 Situs
Customer Service 920 3 3,656 10 Sits
Administrative & General 920 3 861,992 SO 5.953%51,315
Administrtive & General 921 3 10 Sits.Administrative & General 921 3 SO 5.953%
Administrative & General 922 3 (17,720)SO 5.953%(1,055)
Administrative & General 923 3 10 Sits
Administrative & General 923 3 SO 5,953%
Administrative & General 929 3 (8,124)SO 5.953%(484)
Administrative & General 935 3 438 OR Situs
Administrative & General 935 3 45,933 SO 5,953%2,734
Wage & Benefit Adj. Proforma 1 Total
Wage & Benefi Adj - Proforma 2 Total
Total Proform Adjustment
3,061,401
1,984,847
5,046,248
183,732
128,042
311,775 4.5.2
DecrIption of Adjustment:
The Company has several labor groups, each wih different effective contract renewal dates. The Company negotiates wage increases
wit each of these groups throughout the year, This adjustment reconizes these increases prospectively and adds them to operation
and maintenance accounts. It also normalizes pension, employee benefis, and incentives to levels the company wil incur for the 12
months ended December 2008. See page 4,5.1 for more information on how this adjustment was calculated,
.
.
.
.
December 2007 Semi-Annual Report
Labor Escalation- December 2007
4.5.1
The base period, annualized, and the proforma labor expenses are summarized on page 4.5.2,
The following is an explanation of the procedures used to develop annualized and pro forma
labor expenses,
1. Actual December 2007 total labor related expenses are identified on page 4.5.2, including bare
labor, incentive, other labor, pensions, benefits, and payroll taxes.
2. Actual December 2007 expenses for regular time, overtime, and premium pay were identified by
labor group and annualized to reflect wage increases during the base period. These annualizations
can be found on pages 4.5.3 - 4,5.4.
3. The annualized December 2007 regular time, overtime, and premium pay expenses were then
escalated prospectively by labor group to December 2008 (see page 4,5.4.). Union costs
were escalated using the contractual rates found on page 4.5.5. Non-union costs were not escalated
in 2008 because the increase wil not be effective until December 26, 2008.
4. Non-union incentive payments were provided by the Human Resources department and were
calculated based on the calendar year 2008 projections, Union employees do not participate in the
Company's annual incentive program; instead, they receive annual increases to their wages that are
reflected in the escalation described above.
5. Proforma December 2008 pension and employee benefits expenses were provided by the Human
Resource department. These expenses can be found on page 4.5,2 and page 4.5,7, The proforma
payroll tax calculations can be found on page 4.5.8, along with the wage amounts used in the
calculation,
.
.
.
Dember 2007 Wage I. Beneft Recondliatlon ..nuaiiz
" '~n'. -- . ~'-.'.~",-
388,566,263 1,635,327
58,247,457 245,1415 524 050 23 249
45'-337771 1-903 717
50005O2X
500XX
501105O5050
SQ109X
5OXX
502550070
501103
5013255023589
501100
501105
501115
501150
501160
501102
50112X
501175
501200
50122
501250
501251
5012755013
5016X50290
58
580700580
Rela Ornaiv 1lOv
Prum Pa
SUbttal fo Eslation
385,930,936
58,002,316
5,50,802
450,434,054
739,293
1,039,430
7,971,169
Cl,239.895)45894,051
29.875,9429,875,948
932,923,64,355
122,169
2,082
348,588
(43.128)
5,010,458
493,830,456
47,2n,772
7,896,56
4,128,733
25,90,110
4,918,126
90,119.30'
926,312
45,625,678
2,857,892
529,198
1,180,752.
18,20,798
1,734,461
51,992
7,222,951
2,90,513
1.266.565
82.522.101
172.641,410
32,,762
2,751,891
141
35600,794
702.072.660
216,470,641
48,602,018
5e Labo AdIJUn Le Acl
Ol Salaiv/Labo CoJOCu
SUbtol Bar! LaboIn
Tota Inctive
Ov MeseReunanc (1)Jo Ow Pe PavPh ExEd AsMinin. SalaryBe CreitTotl Other Labo
SUbttal Labor and Incentie
Pe . FAS 87Pe . ¡SE 57 . FAS 875E PlnPO Re il . FAS 106
PO emplt Befi . FAS 112
Tot Pesions
Pe AdistMelDeVIut5t401(kllES401(k) Adnist
AlI Deth & Dlsallt
LoTem DIItWors cosatl
Ot Salary OvdTotl leneflts
SUl Pensions and Beefits
PI Tax ExPI Tax EiS4Ot Payr Ta
Totl Payroll Taxes
Tot Labor
No an C8 Labo
Tot Utlit Labor
742,418
1,043,823
..77l16?'1245135'46850045
298759429875948
932,3923,64,355
122,1692,0
348,58-(43128
5010458
3,125
4,393
'5240\"905994
495736.450
47,272,772
7,896,568
4,128,733
25,903,110
4918126
90 119.309
926,312
45,625,678
2,57,882
529,198
1,180,752
18,206,798
1,734,461
61,992
7,222,951
2,90,513
1266 565.:i.52~.101
1.905994
17 541410
32,979,774
2.75~:tl
3573" 806
131,013
131,013
704109566
217,0,713
487010,953
No:(1) fl adust Is ma to senæ beus it IS co In th MEH Trans Ad
:L037 007
628,072
1,40935
Pa4.2
932,392
3,64,355
122169
2,08234,58
431285010458
509058160
35,314,5648.100,00
2,60,00
24,553,246
8024685
7 59 496
963,671
50,993,417
2,100,21723,8
1,152,207
23,137,23
336,19472,00
3,363,58
3,092,113
1657007
8710 466
165693962
33,901,266
2,751,891
141
36653298
"'
10,645,233
1,595,758
151338
1 39 328
20,339
28,597
13 321 71
(11.95.20)
20,432
(1,528,733)(1,3,855)
31 560
1 526813
37,359
5,367,740
(75,665)(295,3)
(28.545)
4,93.436
(1,3,267)
10.016
(3,89,362)182599
390443
5 365
694744
921,492
92 492
71 405420
2,249,50 4..11219,348,219
492,057201
7295753 4.11
5,046,248 4.S.11
Pa4.4
4.5.2
45.3.
4.S.3
45.3
4.5.3-.5.4
4.5.6
45.6
45.6
4.5.6
4.5.7
4.5.7
4.5.7
4.5.7
4.5.7
4.5.7
4.5.7
4.5.7
4.5.7
4.5.7
4.5.7
4.5.7
4.5.7
4.5.7
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Composite Labor Increases
. Regular lime/Overtme/Prmium Pay Deber 2007
Totl Annualized Deber 2007Incas
.
.
Tot Pro Fonna Debe 2008Inc
Miscellaneous Bare Labor Escalation
Accunt
50110
500SX
50109X
Dember 2007 Actals
739,293
1,039,430
(1,239,895)
538,828
Annual Incentive Escalation
Accunt505010
5OXX
Dember 2007 Actals
1,222,460
28,653,487
29,875,948
Incrse
0,42%
0,42%
0,42%
450,434,054
452,337,ni
0.42%
464,730,099
2.74%
Dember 2007
Annualized
742,418
1,043,823
(1,245,135)
541,105
Inuease
2.74%
2,74%
2.74%
Deber 2007
Pro Fonna
762,757
1,072,420
(1,279,247)
555,930
Deber 2008
Budget
30,79,505
4.5.6
Reference
4,5.2
4,5.2
4.5,2
Reference
4,5,2
4.5,2
4,5,2
4,5.2
4.5.7
.Roc Mountain Power
Pension. Benefits Adjusbent
Employee Pension and Benefits Summary
12 Months Ended Deber 31, 2007
S01100 Pension - FAS 87 47,272,n2 49,127,34 36,700,000 35,314,564 (11,958,208)4.5,2
S01105 Penson - IBEW 57 . FAS 87 7,896,568 7,896,568 8,100,000 8,100,00 203,432 4.5,2
S01115 5E Plan 4,128,733 4,128,733 2,60,000 2,600,000 (1,528,733)4,5,2
S01150 Po Retrent Benefi. FAS 106 25,903,110 26,690,919 25,300,000 24,553,246 (1,349,865)4.5,2
S01160 Pos Employment Benefits - FAS 112 4,918,126 5,067,706 8,268,750 8,024,686 3,106,560 4,5,2
SUbtl 90,119,309 92,911,270 80,968,750 78,592,496 (11,526,813)4.5.2
S01102 Pensin Administation 926,312 9SO,563 988,90 963,671 37,359 4,5,2
50112X Medicl 45,625,678 47,083,032 52,622,225 50,993,417 5,367,740 4.5,2
501175 Dental 2,857,882 2,972,127 2,184,175 2,100,217 (757,665)4,5.2
501200 VIsion 529,198 552,40 244,063 233,809 (295,390)4.5,2
50122X Ufe 1,180,752 1,215,54 1,186,154 1,152,207 (28,545)4,5.2
S012SO St401(k)/ESP 18,206,798 18,817,619 23,913,466 23,137,234 4,930,436 4,5.2
S01251 401(k) Administraton 1,734,461 1,78,473 346,276 336,194 (1,398,267)4,5,2
501275 Acdental Death & Disbilty 61,992 61,992 72,008 72,008 10,016 4,5,2
501300 Long-Ten Disabilit 7,222,951 7,329,988 3,413,434 3,363,589 (3,859,362)4.5.2
5016XX Worer's copensaon 2,909,513 2,993,608 3,181,485 3,092,113 182,599 4,5,2
50290 Ot salary Overhead 1,266,565 1,268,393 1,659,40 1,657,007 390,443 4.5.2
Subtl 82,522,101 85,031,743 89,811,586 87,101,466 4,579,365 4.5.2
Grand Total 172,641,410 177,943,014 170,780,336 165,693,962 (6,947,448)4.5,2
.
.
4.5.8
.Payroll Tax Adjustment Calculation
FICA Calculated on Annualized CY 2007 Labor Reference
Annualized Wages Adjustment 1,905,994 4.5.2
Annualized Incentive Adjustment
Total Annualized Wage Increase Adjustment 1,905,994
Medicare Rate (no cap)1.45%
27,637
Soial serity Rate 6.20%
118,172
Percentage of Social Security Ellgible Wages 87.48%
103,376
Total FICA Tax 131,013 4.5.2
FICA Calculated on Pro Forma CY 2008 Labor
Pro Forma Wages Adjustment 12,407,153 4.5.2
Pro Forma Incentive Adjustment 914,557 4.5.2
Total Pro Forma Wage Increase Adjustment 13,321,710
Medicare Rate (no cap)1.45%
193,165.Soial Security Rate 6.20%
825,946
Percentage of Soial Seurity Ellgible Wages 88.18%
728,327
Total FICA Tax 921,492 4.5.2
t
4.5,9.Wage & Employee Benefi Adjustment
December 2007 Semi.Annual Report
Adjust by FERC Accunt and Revised Proto Fact
50 SG 121,223,896 17.27%351,721 121,575,617 1,259,727 122,835,34
SSGCH 521,619 -0.07%1,513 523,132 5,421 528,553
501 SE 1095315 0.16%3,178 1,098,493 11,382 1109,875
535 SG-P 9,202,077 1.31%26,699 9,228,776 95,626 9,324,401
SG-U 7,422,40 1.06%21,53 7,443,94 77,132 7521,076
54 SG 4,112,96 0.59%11,93 4,124,899 42,741 4,167,64
SSGCT 2,955,546 0.42%8575 2,96121 30.713 2,99,834
557 SG 36,36,882 5.18%105,521 36,474,40 377,936 36,852,34
SSGCT 82,718 0.01%240 82,958 88 83,818
56 SG 1730,548 2.47%50,219 17,358,767 179,866 17,538,633
56 iO 1,04 0.00%3 1,043 11 1,05
SNPO 19,559,720 2.79%58,751 19,616,471 203,259 19,819,730
WY-AlL 6,118 0.00 18 6,138 64 6,199
581 SNPO 12,340810 1.76%3580 12,376,616 128,242 12,50,858
582 CA 58,434 0.01%164 58,597 58 57,184
iO 117,38 _0.02%341 117,723 1,220 118,943
OR 785,401 0.11%2,279 787,88 8,162 7èi;842
SNPO 14,98 0.00%43 15,026 156 15,182
UT 748,455 0.11%2,172 750,626 7,778 758,404
WA 143,589 0.02%417 144,00 1,492 145,498
WY.AlL 256,212 0.04%743 256,955 2,662 259,616
58 CA 35,26 0.05%1,039 359,305 3,723 38,026
iO 166,68 0.02%48 167,36 1,734 169,09
OR 2,35,355 0.34%6,83 2,362,189 24,476 2,38,665
SNPO 516,433 0.07%1,50 519,937 5,367 525,325
UT 2,931,246 0.42%8,50 2,939,751 30,481 2,970,211
WA 361,472 0.05%1,04 362,521 3,756 36,277
WY-ALL 656,43 0.09 1,90 658,341 6,622 665162.58 CA 0.00
OR 0.00
UT 0.00
WA 1,65 0.00 5 1,659 17 1,676
WY.AlL 0.00
58 SNPO 34,390 0.05%1,011 349,401 3,620 353021
58 CA 188,612 0,03%547 189,160 1,96 191,120
10 26,755 0.04%757 261,512 2,710 264,221
OR 1,602,367 0.26%5,229 1,607,616 18,730 1,828,34
SNPO 1,09,53 0.16%3,173 1,09,708 11,36 1,108,071
UT 1,249,58 0.18%3,626 1,253,212 12,985 1,266,197
WA 59,337 0.09 1,736 60,073 6,218 80,290
WY-ALL 424,561 0.06%1,232 425,813 4,412 430.225
587 CA 579,873 0.08%1,682 581,555 6,026 587,581
10 83,35 0.09 1,84 837,197 6,602 84,60
OR 3,60,654 0.51%10,447 3,611,101 37,417 3,648,518
UT 2,941,542 0.42%8,53 2,950,077 30,56 2,98,64
WA 767,825 0.11%2,228 770,053 7,979 778,032
WY.AlL 83,94 0.09 1848 638,792 6,619 645,410
58 CA 39,776 0.01%115 39,692 413 40,30
iO 108,678 0.02%315 108,993 1,129 110,122
OR 935,50 0.13%2,714 938,223 9,722 947,94
SNPO 20,013,641 2.65%58,06 20,071,709 207,976 20,279,685
UT 1,195,80 0.17%3,469 1,199,075 12,424 1,211,49
WA 136,294 0.02%39 136,690 1,418 138,106
WY-ALL 197,320 0.03%573 197.892 2,050 199,943
589 CA 5,927 0.00 17 5,94 62 6,00
10 3,55 0.00%10 3,56 37 3,597
OR 50,194 0.01%146 50,339 522 50,861
SNPO 0.00%
UT 25,35 0,00 74 25,432 264 25,695
WA 3,326 0.00%10 3,335 35 3,370
WY.ALL 39,641 0.01%115 39756 412 40,167
590 CA 29,400 0.00 85 29,485 30 29,791
10 22,272 0.00 85 22,337 231 22,568
OR 194,597 0.03%585 195,162 2,022 197,184
SNPO 6,897,372 0.98%20,012 6,917,36 71,678 6,989,06
UT 140,278 0,02%407 140,685 1,458 142,143
WA 11,120 0.00 32 11,152 116 11,267
WY-ALL 79,246 0.01%230 79,476 824 60,299.592 CA 30,459 0.04%895 30,35 3,205 312,559
10 275,484 0.04%799 276,283 2,863 279,146
OR 2,36,141 0.34%6,85 2,369,997 24,557 2,394,554
SNPO 2,56,463 0.36%7,429 2,567,892 26,60 2,594,50
UT 2,023,790 0.29 5,872 2,029,862 21,031 2,050,692
4,5.10.Wage & Employee Benefi Adjustment
Deember 2007 Seii-Annual Report
Adjustnt by FERC Accnt and Revised Protol Factr
WA 417,615 0,06%1,212 418,826 4,34 423,166
WY.ALL 762,510 0.11%2,212 764 722 7924 n2,64
593 CA 2,027,892 0.29%5,88 2,033,775 21,073 2,05,849
10 1,882,128 0.24%4,881 1,887,00 17,480 1,704,489
OR 7,470,377 1.06%21,675 7,492,052 n,63 7,569,882
SNPO (1,227,621)-0.17%(3,562)(1,231,183)(12,757)(1,243,94)
UT (612,962)-0.09 (1,n8)(614,740)(6,370)(621,110)
WA 815,438 0.12%2,38 617,80 8,474 826,278
WY-ALL 673,051 0.10%195 67500 6,99 881,998
594 CA 80,90 0.11%2,332 80,237 8,354 814,591
10 53,652 0.08%1,55 537,20 5,58 542,772
OR 4,286,010 0.61%12,43 4,29,44 44,539 4,342,98
SNPO 23,473 0.00 88 23,541 244 23,765
UT 8,48,700 1.21%24,56 8,491.266 87,98 8,579,249
WA 782,019 0.11%2,269 764,288 8,127 792,415
WY.ALL 1149,063 0.16%3,33 1,152,397 11,941 1,184,338
595 OR 48.395 0.01%135 46,53 482 47.012
SNPO 319.174 0.05%926 320,100 3,317 323,417
UT 6,492 0.00%19 8,511 67 6,578
WY-ALL 0.00%
596 CA 99,50 0.01%289 99,794 1,034 100,829
10 153,83 0.02%447 154,382 1,60 155,981
OR 642,828 0.12%2,44 645,271 8,756 85,030
UT 490,821 0.07%1,424 492,245 5,100 49,34
WA 199,671 0.03%579 200,250 2,075 202,325
WY-ALL 315,331 0.04%915 316246 3277 319,523
597 CA 51,298 0.01%149 51,447 53 51,98
10 284,440 0,04%825 285,265 2,95 288,221.OR 1.073,520 0.15%3,115 1,078,83 11,156 1.087.791
SNPO 719,822 0.10%2,089 721,910 7,48 729.390
UT 1,56,423 0.22%4,539 1,58,962 16.257 1,58,219
WA 389,652 0.05%1,073 370,725 3,841 374,58
WY-AL 5658 0.08%1696 58.276 6,075 592351
598 CA 21,38 0.00 62 21,44 222 21,86
10 12,623 0.00 37 12,68 131 12,791
OR 105,624 0.02%30 105.93 1,09 107,028
SNPO 1,23,216 0.18%3,593 1.41,80 12,867 1,254,676
UT 45,83 0.06%1,322 45,95 4,735 481,693
WA 51,569 0.01%150 51,719 53 52,255
WY-ALL 15756 0.00%46 1580 184 15967
901 CA 3,08 0.00%9 3,091 32 3,123
CN 1,748,726 0.25%5,08 1,751,794 18,152 1.769,94
10 10,889 0.00%31 10,720 111 10,831
OR 80,489 0.01%234 80,722 83 81,559
UT 83,134 0.01%183 63,317 85 63,973
WA 61,243 0.01%178 61,420 83 62,057
WY-ALL 25,839 0.00%75 25,914 269 26,182
902 CA 847,117 0.12%2,45 849,574 8,803 85,378
CN 513,56 0.07%1,490 515,055 5,337 520,391
10 1,216,332 0,17%3,529 1,219,861 12,840 1,232,501
OR 6.85,152 0.98%19,875 6,870,028 71,185 6,941,213
UT 9,022,352 1.29 26,178 9,04,530 93,756 9,142,288
WA 1,43,819 0,20%4,163 1,43,982 14,910 1,453,692
WY.ALL 1,802,081 0.26%5,229 1,807,309 18727 1826,036
90 CA 230,189 0.03%86 230,95 2,392 233,248
CN 33,732,270 4.ll 97,871 33,830,142 35,537 34.180,679
10 221,99 0.03%64 222,837 2,307 224,94
OR 1,95,018 0.28%5,675 1,961,693 20,326 1,982,020
UT 2,36,53 0.34%8,861 2,371,395 24,572 2,39,98
WA 44,715 0.06%1,279 441,99 4,58 44,573
WY.ALL 297926 0.04%864 298,790 3,09 301886
905 CN 176,33 0.03%512 176,845 1,832 178.678
907 CN 322,812 0.05%937 323,749 3355 327,104
90 CA 5,125 0.00 15 5,140 53 5,193
CN 2,814,221 0.40%8,165 2,822,38 29,245 2,851,631
10 378,442 0.05%1,098 379,54 3,933 383,473
OR 1,126,839 0.16%3,269 1,130,108 11,710 1,141,818
UT 96,98 0.14%2,814 972,798 10,08 982,878eWA(0)0.00 (0)(0)(0)(0)
WY-AL 674,466 0.10%1,957 676423 7009 68,431
90 CN 43,193 0.06%1,271 439,465 4,554 44,018
OR 0.00%
910 CN 0.00%
.
.
.
4.5,11
Wage & Employee Benafit Adjuitment
Deember 207 Seml.Annual Report
Adjustmt by FERC Accun and Revised Protol Factr
920 SO 11.81%
WA 0.05%
WY.AlL 0.00
921 SO 0.00
WY.ALL 0.00
922 SO 1.705,187 -0.24%4947 1.710,115 17,720 1,727.83
923 SO 0.00
WA 0.00
929 SO 81,80 -0.11%92,172
93 OR 42,149 0.01%42,709
SO 4420,189 0.63%4478,947
416 NUTl 1.392,374 0.20%1,410,883
426 NUTl 1,292,502 0.18%130.683
capi 249,061.655 35.48%252,372,673
Seca Labo 35276,08 .5.02%35,745,020
Tota La 702,072660 100.00%2,037,007 704,109,666 7,295,753 711,405,420
NonUtiI'and Ca ill 216470,641 30.63%628,072 217,098,713 2.249,50 219,348,219
Utli labor 485602018 68.17%1401,935 487,010,953 5046248 482,057.201
Refernc 4.5.2 4.5.2 4.5.2
Rocky Mountain Power PAGE 4,6
Idaho Results of Operations December 2007
MEHC Transition Savings.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF'
Adjustment to Expense:
Remove CIC severance from Dec 2007 results 920 1 (7,095,634)SO 5.953%(422,409)4.6,1
Remove exp credited at WA reg asset set-up 920 1 1,911,142 SO 5,953%113,772 4.6.1
Remove exp credited at 10 reg asset set-up 920 1 1,830,583 SO 5.953%108,976 4.6.1
Amort of deferre CIC severance 930 3 610,194 10 Situs 610,194 4.6,2
(2,743,714)410,534
Adjustment to Expense for Reduction In Costs
Employees leaving in base period
Other Powr Supply 557 3 (358,359)SG 6.395%(22,916)4.6.3
Transmission Expense 560 3 (182,552)SG 6.395%(11,674)4.6,3
Distrbution Expense 580 3 (427,507)SNPD 4.611%(19,712)4.6.3
Customer Acunting 903 3 (19,150)CN 4,06%(778)4.6.3
Administrtive & General 920 3 (1,151,305)SO 5.953%(68,538)4,6,3
(2,138,874)(123,618)
.
Description of Adjustmnt:
The Company eliminated many positions as a result of th MEHC trnsacton. Thse savings were made possible by the payment of Change-In-Control
Severance. This adjustment defers the severance cost as authorized by the Commission in Docket No. PAC-E-06-11. It is being amored into
exnse over a threeyear period on the boks of the Company as authorized by the Commission in Doet No. PAC-E-07-05. This adjustment reflec
the amorization on a pro forma CY 2008 basis. This adjustment also reflecs the fuure savings of eliminating the positions. Amounts paid to employees
leaving under this proram are removed (this removal includes wage increases in the WEBA adjustment).
.
.PacifiCorp Page 4.6.2
December 2007 Semiannual Report
MEHC Trans Savings -10
MEHC Change-in-Control Severance Amortization Schedule
Beginning Balance per stipulation in Idaho Case PAC-E-Q7-5
Monthly
Month Amortization Balance Expense
1,830,583
Jan-08 1 50,850 1,779,734
Feb-08 2 50,850 1,728,884
Mar-08 3 50,850 1,678,035
Apr-08 4 50,850 1,627,185
May-08 5 50,850 1,576,336
Jun-08 6 50,850 1,525,486
Jul-08 7 50,850 1,474,637
Aug-08 8 50,850 1,423,787
Sep-08 9 50,850 1,372,938
Oct-08 10 50,850 1,322,088
Nov-08 11 50,850 1,271,238
Dec-08 12 50,850 1,220,389 610,194
Ref. 4.6.1
Jan-09 13 50,850 1,169,539.Feb-Q9 14 50,850 1,118,690
Mar-09 15 50,850 1,067,840
Apr-09 16 50,850 1,016,991
May-09 17 50,850 966,141
Jun-09 18 50,850 915,292
Jul-09 19 50,850 864,442
Aug-09 20 50,850 813,593
Sep-09 21 50,850 762,743
Oct-09 22 50,850 711,894
Nov-09 23 50,850 661,044
Dec-09 24 50,850 610,194
Jan-10 25 50,850 559,345
Feb-10 26 50,850 508,495
Mar-10 27 50,850 457,646
Apr-10 28 50,850 406,796
May-10 29 50,850 355,947
Jun-10 30 50,850 305,097
Jul-10 31 50,850 254,248
Aug-10 32 50,850 203,398
Sep-10 33 50,850 152,549
Oct-10 34 50,850 101,699
Nov-10 35 50,850 50,850
Dec-10 36 50,850 (0)
.
. PacifiCorp
December 2007 Semiannual Report
MEHC Trans Savings .10
Savings from MEHC Change-in-Control Severance
.
.
Remove Pay from Base Period.
Org Unit Total Amount
Generation 328,598C&T 56,049Rocky Mt. Power 5,882
Rocky Mt. Power 20,989
Rocky Mt. Power 3,189Pacific Power 231,122Pacific Power 534,455IT 1,002,244
Corporate 553,517
Grand Total 2,736,047
Expense %
92.0%
100.0%
91.2%
91.2%
91.2%
79.0%
79.0%
59.4%
100.0%
Summary of Charges by Account557 358,359 4,6560 182,552 4.6580 427,507 4.6903 19,150 4.6
920 1,151,305 4,6
2,138,874 4.6
Expense Amt.
302,311
56,049
5,367
19,150
2,909
182,552
422,141
594,878
553,517
2,138,874
Page 4.6.3
Acct
557
557
580
903
920
560
580
920
920
*These amounts paid have been escalated and so should be removed from results after escalation as a
type 3 adjustment.
Rocky Mountain Power PAGE 4,7
Idaho Results of Operations December 2007
Irrigation Load Control Program Adj.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Other Purchased Power 557 (1,191,104)SG 6.395%(76,168)4.7,1
Oter Purchase Power 557 1,191,104 10 Situs 1,191,104 4.7.1
1,114,936
.
Description of Adjustment:
Payments made to Idaho irrgators as part of the Idaho Irrgation Load Contr Proram are system allocted in the unadjusted data. This adjustment
situs assigns th paymnts to Idaho. The realloction is reuired as DSM costs are situs assigned to the states in which the costs are incurred to match
Uie benefrt of reuce load refleced in acual lods use to compute inter-jurisdictional allocation factors.
.
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Rocky Mountain Power
Account NO. 514511
DSM - Irrigation Load Control
GIL Account Balance Display
2.55
961.24
.36.49
961.24
736.22
2,092,738.59 1,19t,103.56
36.49
997.73
1,733.95
1,733.95
1,733.95
110,353.95
289,814.81
1,139,413,27
1,629,790.54
1,181,357.14
1,1!lt,103.56.
1,191,103.56
1,1!l1¡103,~6
1,191,103.56
1,191,103.56
1,191,103.56
1,191,103.56
Page 4.7.2
Rocky Mountain Power
PAGE 4,8
Idaho Results of Operations December 2007
Incremental Generation O&M.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
lakeSide 549 2 3,578,388 SG 6.395%228,829 4.8.1
Blundell Bottoming Cycle 549 2 519,987 SG 6.395%33,252 4.8.1
Gonoe Hills 549 3 3,257,935 SG 6.395%208,337 4,8.1
Marengo 549 3 3,998,391 SG 6.395%255,687 4.8,1
Administration 549 3 (2,330,403)SG 6.395%(149,023)4.8.1
9,024,298 571,080
.
Description of Adjustmnt:
This adjustment annualizes the O&M expnse of the Lake Side Plant and Blundell Bottoming Cycle which were place into seivice September 2007
and Dember 2007, This adjustment also adds incrental operation and maintenance expenses for generating units that were nol in serice during
th 12 months ended December 2007 but will be in serice during the 12 months ended Decmber 2008.
,
. Rocky Mountain Power
Incremental Generation O&M
December 2007 Semi-Annual
.
,
2007 Actuals 2008 Budget Variance
Marengo (includes expansion)1,883,256 5,881,647 3,998,391
Goodnoe Hils 0 3,257,935 3,257,935
Administration*76,639 (2,253,764)(2,330,403)
Total:1,959,895 6,885,818 4,925,923
Blundell Bottoming Cycle
Lake Side
20,013
1,845,288
540,000
5,423,676
519,987
3,578,388
Total:-------3,825,19-7 12~849~4 9,024,298 Refer 4.8
* Administration for 2008 includes BPA & Oregon Energy Trut Credits.
4.8.1
Rocky Mountain Power PAGE 4.9
Idaho Results of Operations December 2007
Postage Increase Adj.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustmnt to Expense:
Customer Receipts & Collections 903 2 186,784 CN 4.064%7,590 4.9,1
.
Decription of Adjustmnt:
This adjustment adjusts customer biling postage costs to reflect the U,S. Postal service rate increase of 6.9% ($0.29 to $0.31 for utlity mailngs) on May 14,
2007,
.
.
.
.
Pacificorp
Results of Operations - December 2007
Postage
Postal Service Increase for Utilty Bil Mailngs
Current Rate
New Rate
Increase
Total Customers (per JAM factor calculation for CN)
Increase in Customer Postage Costs (January 1, 2007 through May 14,2007)
Calculated at 1 bils per customer ~ $0.02 for 5.5 months
0.29
0,31
0.02
1,698,035
186,784
4,9.1
.
.
Rocky Mountain Power
Idaho Results of Operations December 2007
GRID West
Adjusbnent to Expense:
No Adjustment Necssry
TOTAL
ACCOUNT Ig COMPANY FACTOR
PAGE 4,10
IDAHO
FACTOR % ALLOCATED REF#
4,10.1
.
Description of Adjusbnent:
In Doket No. PAC-E-063, Idaho Public Utlities Commission authorized PacifiCorp to amortze the principal balance of the Grid West loan over 60 months
beinning January 2007. No Interest is to be allocted to any of Idaho's porton of the loan costs. The deferred balance is being amortzed on the Company's
boks beinning January 1, 2007 as authorized by the Commission in Docket No. PAC-E-G7-GS, Therefore, no adjustment is necssary. Please see 4.10.1
for detils.
10 . RTO Grid West Loan
Account #187083.Idaho Public Utilities Commision authorized Pacificorp to amortize the principal
balance of the Gri West Loan only over 60 months beinning January 2007.
No Interest is to be alloted to any of Idaho's portion of the loan costs.
AMORTIZATION SCHEDULEBeg Monthly
Balance Amortzation
.
Month
Oc-0
No.06
De06
Jan-07
Feb-07
Mar-07
Apr-07
May-07
Jun-7
Jul-D7
Aug-D7
se07
Oc-D7
Nov-D7De7
Jan-8
Feb08
Mar-08....
Ap-D8
Ma-08
Jun-08Ju8
Aug085e8
Oc-08
Nov-08
De08
Jan-09
Feb-9
Mar-09
Apr-09
May-D9
Jun.09
Jut-09
Aug-D95e9
Oc-09
Nov-D9
Dec09
Jan.10
Feb-10
Mar-10
Apr.10
May-10
Jun-10
Jut-10
Aug-10
Sep10
Oc-10
Nov-10
De10
Jan-11
Feb-11
Mar-11
Ap-11
Ma-11
Jun-11
Jut-11
Aug-11
5ep-11
Oct-11
Nov-11
De11
~
137,034.29
135,810.64
135,810.64
133,547.13
131,283.62
129,020.11
126,756.60
124,493.09
122,229.58
119,96.07
117,702.56
115,439.05
113,175.54
110,912.03
108,648.52
106,385,01
104,121.50
101,857.99
99,594.48
97,330.97
95,067.46
92,803.95
90,540.44
88,276.93
86,013.42
83,749.91
81,486.40
79,222.89
76,959.38
74,695.87
72,432.36
70,168.85
67,905.34
65,641.83
63,378.32
61,114.81
58,851.30
56,587.79
54,324.28
52,060.77
49,797.26
47,533.75
45,270.24
43,00.73
40,743.22
38,479.71
36,216.20
33,952.69
31,689.18
29,425.67
27,162.16
24,898.65
22,635.14
20,371.63
18,108.12
15,84.61
13,581.10
11,317.59
9,054.08
6,790.56
4,527.04
2,263.52
1,22.65
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263,51
2,263,51
2,263,51
2,263.51
2,263,51
2,263.51
2,263.51
. 2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,283.51
2,263.51
2,263.51
2,263.51
2,263,51
2,263.51
2,263.51
2,283.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263,51
2,283.51
2,263.51
2,263.51
2,263.51
2,263.51
2,283.51
2,283.51
2,283.51
2,283.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.51
2,263.52
2,263.52
2,263.52
2,263.52
End
Balance
137,034.29
135,810.64 NOTE: $1,223.65 represents partal lon refund
135,810.64
133,547.13
131,283.82
129,020.11
126,756.60
124,493.09
122,229.58
119,966.07
117,702.58
115,439.05
113,175.54
110,912.03 Avg Bal
108,648.52 122,230
106,385.01
104,121.50
101,857.99
99,594.48
97,330.97
95,067.46
92,803.95
90,540.44
88,276.93
86,013.42
83,749.91
81,486.40
79,222.89
78,959.38
74,895.87
72,432.38
70,188.85
67,905.34
85,641.83
63,378.32
61,114.81
58,851.30
56,587.79
54,324.28
52,060.77
49,797.26
47,533.75
45,270.24
43,00.73
40,743.22
38,479.71
36,216.20
33,952,69
31,689.18
29,425.67
27,162.16
24,898.65
22,635.14
20,371.63
18.108.12
15,84.61
13,581.10
11,317.59
9,054.08
6,790.56
4,527.04
2,263.52
0.00
Pag 4,10.1
Rocky Mountain Power PAGE 4.11
Idaho Results of Operations December 2007
Remove Non-Recurring.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % AllOCATED REF#
Adjustment to Expense:
1) KATZ Patent ReselVe 903 (576,800)CN 4,06%(23,440)4,11.1
2) Capital Surcharge Clearing 922 199,282 SO 5.953%11,863 4.11,1
3) FERC Contingnt Fees 928 (2,353,550)SG 6,395%(150,503)4,11.1
4) Excise Tax Refund 921 179,692 SO 5,953%10,697 4.11.1
5) Clear FY06 Incent to Surcarge 922 652,960 SO 5,953%38,871 4.11.1
6) MCBIT Refund 903 (723,360)OR Sits 4.11,1
909 (80,530)OR Sits 4.11,1
7) liabilit Wrie Off 908 100,233 UT Situs 4,11.1
8) Refund Transmission Revenue 566 (100,000)SG 6,395%(6,395)4,11.1
90 800,000 CN 4.06%32,510 4,11.1
9) Geary Dike ReselVe 539 1,000,000 SG-P 6,395%63,947 4.11.1
10) Miscellaneous Write Off 421 (1,401,622)SO 5.953%(83,440)4,11.1
TOTAL Non-recurrng Adjustmnts (2,303,695)(105,888)
.
Description of Adjustmnt:
A variety of accunting entres were made to expense accnts during 2007 that are either one-time and non-recurrng in nature or relate to a prior
pe, These trnsactons are removed frm results of operations to normalize the test period results. A descrption of each item included above is
prvided on Pages 4,11,1 and 4,11,2.
.
. PacifiCorp
Semi.Annual . December 2007
Remove Non.Recurring Expense
~Postg Date ITeXt
1 06/27/2007 KATZ Reserve
08/2812007 Settlement Payment
2 05/31/2007 Cap Surcharge Clearing
3 0413012007 FERC Contingent Fees
3 03/31/2007 Contingent Fees - Mar 2007
3 03/3112007 Contingent Fees - Mar 2007
4 021281007 Excise Tax Refund
5 0112312007 Clr FY06 Incent to Surchr
6 09/3012007 MCBIT Refund
6 various MCBIT Interest and Other Costs
6 various MCBIT Settlement Informational Ads
7 091712007 Liabilty Wnte Off
8 0912712007 Refund Transmission Revenue.8 09/30/2007 Refund Transmission Revenue
9 1213112007 Geary Dike Reserve
10 0812112007 Retire MACE Softare
10 10/2312007 Retire Leasehold Improvements
.
4,11.1
I FERCAcctl Amount as Booked I Reference I
9031000 2,150,000 4.11.2
9031000 (1,573,200)4,11.2
9220000 (199,282)4.11.2
9283000 (130,272)4.11,2
9283000 1,317,268 4.11.2
9283000 1,166,553 4.11.2
9210000 (179,692)4.11,2
.9220000 (652,960)A.j 2
9032000 666,746 4.11.2
9032000 56,614 4.11.2
9090000 80,530 4,11.2
9086000 (100,233)4,11.2
5660000 100,000 4.11.2
9040000 (800,000)4,11,2
5390000 (1,000,000)4.11.2
4212000 455,404
4212000 946,218
2,303,695
Ref#4.11
4.11,2. PacifiCorp
Semi-Annual. December 2007
Remove Non-Recurring Expense
.
.
Certain accunting entries were made to expense accounts that are either one-time and non-recurring in nature or relate
to a prior period. These transactions are removed from results of operations to normalize the test period results.
1) Katz Patent Reserve: An entry was made in June 2007 to record the contingent liabilty associated with a pending
lawsuit for a patent infringement related to automated telephony (a patent owned by Katz,) The number is based on the
telephony usage over the past six years, In August 2007, the dispute was settled and the resulting payment was much
lowr than had been reserved and a corresponding entry was made (the Company reserved $2.1 millon and settled for
$576,800), These are related to a prior period and should be removed.
2) Cap Surcharge Clearing: Capital surcharge clearing entry for the Corporate business unit. The amount previously
capitalized was writen off to FERC accunt 922. This adjustment removes the credit from 2007 results,
3) FERC Contingent Fees: Estimate for the contingency changed frm prior month, as changes were identified in
megawatts for reporting purposes. The Company under-reported megawatts over the last 3 years and estimates that
FERC might require some payment to cover,
4) Excise Tax Refund: The Company received a $204k excise tax refund from the IRS related to a previous year. Of the
total, $179,692 was credited to expense in February 2007. This adjustment removes the credit.
5) Clear FY06 Incentive to Surcharge: Capital portion of incentive accrual originally booked to 148002 last year. It
should have been reversed during the year and booked to the capital surcharge bucket and wasn't. This entry reclasses
it out of 148002 and into the capital surcharge bucket to be allocated to capital projects. No financial statement impact -
reclass from ewlp to ewip,
6) MCBIT Refund: In September 2007 the Company reached agreement on a final refund amount for Multnomah County
Business Income Tax collected from customers since 1993. As a result of the settlement, the Company set aside $2.2
millon to cover the customer refund, attorneys fees, and other costs of the settlement. The Company made an entry to
increase a previously accred reserve. This adjustment reverses the impact of that entry on regulated results and
removes any other settlement expenses booked in 2007.
7) Liabilit Write Of: A liabilty on the books since 1995 was written off because it had exceded the statute of limitations.
A contractor had done some DSM work for the Company in the 90s. We had paid the contractor, but there was a small
balance in the liabilit that kept accruing interest. The contractor never biled and we wrote off the balance after ten
years.
8) Refund Transmission Revenue: The Company had a dispute with a transmission customer regarding unreserved use
charges over a period of several years. In 2006 the Company offered to refund $800,000 and established a reserve for
that amount. The issue subsequently went to FERC which ruled the Company only needed to refund $100,000, at which
time the company reversed the old reserve and established a payable for $100,000. This adjustment reverses the
impact of these entries in regulated results.
9) Geary Dike Reserve: The Geary Dike failed and flooded a golf course, farmland, and state highway on June 7, 2006.
The Company initially reserved $1 millon in June 2006, and in November 2007 an additional $1 milion was reserved for
additional liabilit facing the Company, The Company subsequently determined the event met the criteria for an injuries
and damages insurance claim. In December 2007, the $2 milion reserve was reversed and appropriate entries were
made corrsponding to the insurance claim. This adjustment removes the net impact of reversing the reserve in 2007.
10) Miscellaneous Write Of: In August 2007 the company determined the Mapping and Connectivity Enabler (MACE)
softare package was no longer used and was written off. The loss on disposition was recorded to FERC accunt 421
and this adjustment removes it from results. In October 2007 the company relinquished two-thirds of its lease for the
Sandy Training Center facilities, Leashold improvements previously made at the center were written off to FERC
Accunt 421 and this adjustment removes the write off from results.
Rocky Mountain Power PAGE 4,12
Idaho Results of Operations December 2007
Blue Sky .TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Customer Service 909 1 (4,512)CN 4.06%(183)
Customer Service 909 1 (5,617)CA Sis
Customer Service 909 1 (8,280)10 Situs (8,280)
Customer Service 909 1 (54,682)OR Situs
Customer Service 909 1 (189,264)UT Situs
Customer Service 909 1 (16,968)WA Situs
Customer Service 909 1 (13,60)WYE Sits
Administrative & General 921 1 (7)SO 5.953%(0)
Administrative & General 921 1 (610)CA Sits
Administrative & General 921 1 (1,264)10 Situs (1,264)
Administrative & General 921 1 5,130 OR Sits
Administrtive & General 921 1 (16,813)UT Situs
Administrative & General 921 1 (1,555)WA Sit
Administrative & General 921 1 (1,862)WYE Situs
Administrative & General 922 1 (154,422)SO 5,953%(9,193)
Administrative & General 923 1 (20,976)SO 5.953%(1,249)
Administrative & General 923 1 to,133)
UT Sis
( 25,441)(20,170)
.
.
Description of Adjustment:
This adjustment removes fr results above the line expenses assoated with the Blue Sky program.
Rocky Mountain Power PAGE 4.13
Idaho Results of Operations December 2007
K2 Risk Mgmt System.TOTAL IDAHO
ACCOUNT Is COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustmnt to Expense:
Amorization Expense 404IP 1 (131,919)SO 5,953%(7,853)4.13.1
Gain I Loss on Sales 421 1 (2,453,790)SO 5.953%(146,076)4.13,2
Offce Supplies 921 1 (774,818)SO 5.953%(46,126)4.13,2
Administrative Expense 922 1 (42,892)SO 5,953%
d2,553)
4.13.2
(3,403,419)(2 2,608)
Adjustment to Rate Base:
Elec Plant 303 (2,00,168)SO 5,953%(119,429)Below
Acm. Amrtzation 1111P 290,183 SO 5.953%17,275 Belo
(1,715,985)(102,154)
Adjustmnt Detail:
Dec 200
Gro Plant In-service 4,012,336 4.13,1
Acmulated Amorzation (580,366)4.13,1
Net Plant In-Ser 3,431,970
Dec 2007
Gros Plant In-srvic
4,13,1
Acmulated Amrtzalion
Net Plant In-Service
Average Dec 2007.Gross Plant In-Serice 2,006,168
Aculated Amortzation (290,183)
Net Plant In-Serice 1,715,985
Description of Adjustment:
This adjustmt removes the effec of the K2 Risk Management System from results of operations. This projec was capitalized during calendar year
200. However, the projec has ben written-off/retired during March 2007 as the project has ben deemed not used and useful.
.
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Rocky Mountain Power
PAGE 4.14
Idaho Results of Operations December 2007
Affliate Mgmt Fee Adj (MEHC).TOTAL IDAHO
ACCOUNT Iï COMPANY FACTOR FACTOR % ALLOCATED REF#
AdJUltment to Expense:
Management Fee 930 (1,649,914)SO 5.953%(98,221)
Adjustment Detail
MEHC Management Fee Limit per commitment 9
MEHC Management Fee Biled - CY 2007
Adjustment Required
7,300,000
8,949,914
(1,649,914)
.
Decription of Adjustment:
In Merger Commitment #9, the Company committed to hold customers harmless for costs that wer previously assigned to affliates relating to
management fees and set the total copany amount at $1,500,000, This commitment is offsettable to the extent PacfiCorp demonstrtes to the
Commission'S satisfacton that corporate alloctions from MEHC to PacifiCorp included in PacifiCorp's rates are less than $7,3 millon, This
adjustment limits corate alloctions from MEHC included in rates to the $7.3 milion limit.
.
Rocky Mountain Power PAGE 4.15
Idaho Results of Operations December 2007
DSM Amortization Removal.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustmnt to Expense:
Custoer Asistanc 908 (25,396,529)UT Situs 4,15.1
Customer Assistance 908 (4,317,262)WA Situs 4,15.1
Customer Asistance 908 (215,473)CA Situs 4.15,1
Customer Assistance 908 (2,048,020)10 Situs (2,048,020)4.15.1
(31,977 ,285)(2,048,020)
.
.
Decription of Adjustmnt:
Idaho allow for recery of OSM expenses through the system beefit charge (SaC) tariff rider. This adjustment removes Idaho DSM costs in order to
prvent a double recvery through the revenue requirement and the sac tariff rider.
. Rocky Mountain Power
Semi Annual Report - December 2007
DSM Amortization Removal Summary
.
.
GL Account FERC Account Factor
553402 9085000 UT
553403 9085000 WA
553404 9085000 CA
553405 9085000 ID
12 ME Dec 2007
25,396,529
4,317,262
215,473
2,048,020
31,977,285
4,15,1
Ref
4.15,2
4,15.3
4.15.4
4.15,5
T04.15
. Rocky Mountain Power
Semi Annual Report - December 2007
GL Account 553402
4.15.2
t,( (ount Edit Q.oto Etl'Llroriment :::'l:.tern !:elp,¡;-~_i'!'!~~~'~'" 'èf~%~ ;-f.~:í~ t' I ~~l~~':.Ji-",v _ _ ~à7",i;;k/&A~7,,'4 ~N~
GIL Account Balance Display
.
2,04:J,8S5.53
2,655,767,05
3,091,113.27
3,530,804.90
.:3~S73;3:37;e5
3,258,652,24
4,208,5~1 ,~2
4,389,464,89
5,06",838:78
5,843,348,32
6,Q56,384,1?
2,093,835.27
46,109,993,95
152;960.09
1,340,345.88
1,840,352,34
2,022,081.26
987,;364,57
1,384,086.53
l,353,4El9.55
2,341,903.07
3,8:37,003.88
4,234,937.66
29;521,28
589,418,58
20,71 :3,464,69
1,290,925,44
1,315,421,17
1,250,760.93
1,508,723.64
. '.~;8e5,973.38
1,874,565,71
2,El55,072.07
2,047,561,82
1,2:21,834.90
1,608,410.66
6,Cl2&,e&2.â5
1,504,416.69
25,396,529,26
1,290,925.44
2,606,346.61
3,85.7,107.54
5,365,831.18
. 8i251,8Q4.S6
10,126,370.27
12,981,442.34
15,029,004.16
16,256,839.0.6
17,865,249,72
23,891,112.57
25,396,529.26 To 4.15.1
25,396,529.26
25,396,529.26
25,396,529,26
25,396,529.26
25,396,529.26
.
. Rocky Mountain Power
Semi Annual Report - December 2007
GL Account 553403
4.15,3
t:ccourit S(Jlt Q.oto Eny'ironrnent :::\l'õ,tern Help"fY_~'I""i.t%'"r~;;'~~~iì-~:' '" ~,,¡iil ;~ ¡o ~jli ;,$,"1 '""b..~.æ,;i~~¡~~:AIi,~ ,~ 'N "a "/" C\" 8~f) šl1'-*'~ ID't'¡ "~t-:+~~_fr;i3",~',m:;'ml,,~ w, ~:~~..~ ,~ _ ¿çi4""r;~~'":* ~~~~~t~~~lf~~~+U)
GIL Account Balance Display
.
1,418,30t.00
1,375,122.81
1,637,925.50
1,554,144.61
1,063,3S6.(l0
977,305.00
1,013;005;00
1,180,048.00
1,147;538.00
1,053,349.00
998,927,00
1,018,258,00
10039,855.81
1,213,715.50
lj202,456~61
910,000.00
.d aoQ,OOO.OO
690,000,00
665,000.00
755,000.00
91Q,OOO.00
696,000.00
694,OpO.00
644,000.00
10,120,027.92
378,445.19
161,407.31
435,468.89
644,144.61
..2~3,~e6,00
287,305,00
349,005.00
425,048,00
33.7;539..00
357,349.00
304,927.00
374,258.00
4,317,262,00
.378,445.19
539,852.50
975,321,39
1,619,466.00
1,882,832.0.0
2,170,137,00
2,518,14:2,00
2,943,190.00
3,280,728:00
3,638,077.00
3,943,Op4.00;
4,317,262.00 To 4,15,1
4,317,262.00
4,317,262,00
4,317,262.00
4,317,262.00
4,317,262.00
.
14,437,289,92
. Rocky Mountain Power
Semi Annual Report - December 2007
GL Account 553404
4,15.4
8ccount I;dit 1:oto En1:llOnrnent E::.s.lern J:elp';:r't'_lw~-""æI\f~~_"' ~¡.:,.v~ ;:'4~~I: ~~l t.~!£!Jl~':,W l.l~l'''t ,:.~~Lfi;.!*K"' _ _ _ ~ ~ ¡j!:~T::):?'~~~~-i0 ~~~ e¥ ,;t
GIL Account Balance Display
.
35,501.00
48,385.61
6t,0413.93
67,175.08
1t3,155,92
69,817.27
79,822,26
103,647.12
113,71~.50
116,094.77
119,648.80
123,122.42
1,061,137.68
23,949.61
37,949.93
51,062.08
53,424.92
104,625.27
54,946.26
72,300.12
84,136,50
97,919.77
108,610,80
11t,277.42
45,461.84
1t,552.39
10,435.68
\g,98,..85
13,750.16
18,~30.65
14,871.01
. 7,522.14
19,510.62
15,799.73
7,483.97
8,~71.38
77,660.58
11,!i52.39
21,988.07
31,972:92
45,723,08
64,253.73
79,124.74
86,646,88
106,157.50
121,957.23
129,441.20
137,812.58
215,473.16 To 4.15,1
215,473.16
215,473.16
215,473.16
215,473.16
215,473.16
.
845,664,52 215,473,16
. Rocky Mountain Power
Semi Annual Report - December 2007
GL Account 553405
4.15.5
6ci: OUtlt Edit Qoto Erl11ionment t:'t:,tern J:elp"B_~":"""-"~~~~"-'ì-'~ '.""-, , ;; ;. .'''¡¡,'t'ië --~u.:.~, ''' . .'i""~':ì""¡ ~ ""J'~",W ~ ~~1. :.~i:..'~ lr", 1"~z,_?-~l ,.,'~ iS~f&.~~,"¡;j,'A . ,_i' 4- 'k'# ~=h",,,,,;sil;e ,_ ~ _ ~'i~¡¡."""_~,,..~~; ~ ~....q;'i~ ~,
GIL Account Balance Display
.134,983.61
126,772.02
..112,310.16
104,125.12
. . 140,4'29.a6
250,034.65
311,361.25
270,631.43
215,813.66
136,560.43
117,181,0!l
127,822.91
2.048,020.29
13;4,983.61
126,772.02
ll2;31 0.16
104,125,12
'14P\42a.9e.
250,034.65
3t1~36t,25
270,631.43
215,813.66
136,560.43
117.181.09
127,822.91
2,048,020.29
134,983.61
261,755.63
S"4.06~:79
478,190.91
618;614.1i7
868,649.52
1,180,010,77
1.450,642,20
1,666,455.86
1,803,016.29
1,!l20,197.38
2,048,020.29 To 4.15.1
2,048.020,29
2,048,020.29
2,048,02G.29
2,048,020.29
2,048,020,29
.
Rocky Mountain Power PAGE 4.16
Idaho Results of Operations December 2007
A&G Cost Commitment (MEHC).TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Customer Asistanc 930 3 (225,624)10 Situs (225,624)4.16.1
.
Description of Adjustment:
This adjustment reflecs the administrative and general expense savings due to the MEHC merger Idaho Merger Commitment 131, The savings will be
amortzed over 3 years starting January 1, 2008.
~
.
.
.
Rocky Mountain Power
Semi Annual Report - December 2007
A&G Cost Commitment
Description
Dec 2007 Actual Administrative and General Expense
Total Company
180,356,471
A&G Adjustments:
Miscellaneous General Expense
Wage & Benefit Adjustment
MEHC Transition Savings
Remove Non-recurring Entries
Blue Sky
K2 Risk Mgmt System
Affliate Mgrnt Fee Adj(MEHC)
Memberships and Subscriptions
Idaho Intervener Funding
Idaho Pension Expense Cash Basis
Captive Insurance
West Valley Lease
Total A&G adjustments
Adjusted A&G Expense
(275,000)
1,133.600
(3,895,019)
(1,321,615)
(232,514)
(817,710)
(1,649,914)
(385,961)
28,865
17,244.099
(241,500)
9,587,332
189,943,803
Total Normalized A&G Cost Commitment 239,707,711
Total normalized A&G Expense was below the A&G Cost Commitment as stipulated in
Idaho Merger Commitment 131. Therefore, no adjustment is necessary.
Benefits Previously Deferred
One year amortization expense
4.16.1
Ref. #
2.2 .
4.1
4.2-4,5
4.6
4.11
4.12
4,13
4.14
4,18
4,19
4.20
4.21
5.2
225,623 4.16.2
. Rocky Mountain Power
Semi Annual Report - December 2007
Deferral and Amortization of MEHC A&G Commitment
Amortize over 3 years beginning January 2008
Interest ~
Amortization 0,000%
Dec-07
Jan-08 18,802 0%
Feb-08 18,802 0%
Mar-Q8 18,802 0%
Apr-08 18,802 0%
May-08 18,802 0%
Jun-Q8 18,802 0%
Jul-08 18,802 0%
Aug-08 18,802 0%
Sep-Q8 18,802 0%
Oct-08 18,802 0%
Nov-OS 18,802 0%
Dec-08 18,802 0%
~One Year Amortization 225,623, Jan-09 18,802 0%
Feb-09 18,802 0%
Mar-09 18,802 0%
Apr-09 18,802 0%
May-09 18,802 0%
Jun-09 18,802 0%
Jul-09 18,802 0%Aug-09 18,802 0%
Sep-09 18,802 0%
Oct-09 18,802 0%Nov-09 18,802 0%
Dec-09 18,802 0%
Jan-10 18,802 0%
Feb-10 18,802 0%
Mar-10 18,802 0%
Apr-10 18,802 0%
May-10 18,802 0%
Jun-10 18,802 0%. Jul-10 18,802 0%
Aug-10 18,802 0%
Sep-10 18,802 0%
Oct-10 18,802 0%
Nov-10 18,802 0%
Dec-10 18,802 0%
,
Unamortized
Balance Ref#
(676,868)
(658,066)
(639,264)
(620,462)
(601,660)
(582,859)
(564,057)
(545,255)
(526,453)
(507,651)
(488,849)
(470,047)
(451,245)
4.16.1. ~
(432,443)
(413,642)
(394,840)
(376,038)
(357,236)
(338,434)
(319,632)
(300,830)
(282,028)
(263,226)
(244,425)
(225,623)
(206,821)
(188,019)
(169,217)
(150,415)
(131,613)
(112,811)
(94,009)
(75,208)
(56,406)
(37,604)
(18,802)
(0)
4.16.2
Rocky Mountain Power PAGE 4.17
Idaho Results of Operations December 2007
Prelim Coal Plant Exp.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
IPPU3 Development Cost Write-Off 557 (2,969,240)SG 6.395%(189,875)
Bridger U5 IGCC Deferrl Write-Off 557 (423,792)SG 6.395%(27,100)
Hunter 4 Write-Off 557 (102,964)SG 6.395%(6,58)
Total Adjustmnt to Expense (3,495,995)(223,560)4.17.1
.
Description of Adjustment:
The Company was planning to build 3 coal units, IPP unit 3, Bridger unit 5, and Hunter unit 4. The expenses the Company incurred for these abandoned
proecs were wrtten off to FERC 557. This adjustment removes these expenses from results.
.
~ocky Mountain Power
.Semi Annual Results. December 2007
Prelim Coal Plant Exp
4.17,1
IPPU3 Development Cost Write-Off
Impairment Loss
Impairment Loss
Impairment Loss
13,888
13,888
2,941,463
2,969,240
Bridger IGCC US Deferral Write-Off
Mise Project Expense Write-off
Mise Project Expense Write-off
Mise Project Expense Write-off
Mise Project Expense Write-off
184,314
175,244
102,938
(38,704)
423,792
&unter 4 Write.Of
Permitting Expense Write-Off 102,964
102,964
,
Rocky Mountain Power PAGE 4.18
Idaho Results of Operations December 2007
Memberships & Subscriptions.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Misclaneous General Expense 930 (385,961)50 5,953%(16,058) 4.18.1
.
Description of Adjustment:
This adjustment removes expenses in excess of Commission policy allowances as stated in Idaho Powets Order #29505. Natinal and regional trde
ornizations are recgnized at 75%, W5CC dues are included at 100% since it is a mandated membership. All other membership dues are
remoed,
.
.
.
.
PaeiliCorp
Semi-Annual Report. December 2007
Memberships and Subscnptions Adjustment Breakdown
Page 4.18,1
Account Description
Remove Tota Memberships and Subscriptions in Account 930.2930.2 SAP Extact
National and Regional Trade Membership Allowances
930.2 CONSORTIUM FOR ENERGY EFFICIENCY
930.2 EPRI RESEARCH INSTITUTE
930.2 IESNA
930.2 INRMOUNTAI ELECTICAL ASSOC
930.2 NATIONAL COAL TRASPORTATION ASSOC
930.2 National Electric Energy Testing Research and Applications Center
930.2 NATIONAL JOIN UTILITIES
930.2 Nextgen Energy Council
930.2 NORTH AMERICAN ELECTRIC RELIAILITY
930.2 Ox-Coal Combustion Advisory Group
930.2 UCA USERSGROUP
930.2 UTILIT WIND INTEREST GROUP INC
930.2 ASSOCIATED OREGON INDUSTRIES
930.2 ASSOCIATED TAXAYERS OF IDAHO INC
930,2 CALIFORNIA CLIMTE ACTION REGISTRY
930.2 IDAHO MINING ASSOCIATION
930,2 INRMOUNAI ELECTICAL ASSOC
930,2 MAUFACTRING 2 I COALmON
930.2 NW POWER & CONSERVANCY
930.2 OREGON BUSINESS ASSOCIATION
930-.2 OREGON BUSINESS COUNCIL
930.2 PACIFIC NORTHWEST UTIL TIES CONFERENCE COMMIlEE
930.2 PORTLD BUSINESS ALLIANCE
930.2 ROCKY MOUNAI ELECTICAL LEAGUE
930.2 UTAH FOUNDATION
930.2 UTAH MAUFACTRERS ASSOCIATION
930.2 UTAH TAXA YERS ASSOCIATION
930.2 WESTERN ENERGY INSTITUT
930.2 WYOMING T AXA YERS ASSOCIATION
930,2 YAKIM COUNTY DEVELOPMENT
930.2 Oter
Tota Memberships Allowances:
Add Back Ordered Memberships at 75%
Membership Fees (g 100%
930.2 Western Electrcity Coordinating Council
930.2 NORTHERN TIER TRSMISSION GROUP
Total Adjustment
Amount References
(3,866,256)4.18.7
12,000 4,18.6
1,252,995 4,18,6
500 4.18.6
7,500 4,18.6
1,250 4.18.6
105,000 4.18,6
10,125 4.18,6
25,000 4,18.6
100 4.18.7
25,000 4.18.7
10,000 4.18.7
5,000 4.18.7
54,787 4.18.2
850 4.18.2
20,000 4.18,2
6,000 4.18.3
7,500 4.18.3
5,000 4.18.4
21,000 4.\8.4
13,000 4.18.4
19,809 4.\8.4
52,302 4.18.4
39,050 4,18.4
18,000 4.18,5
22,500 4.18.6
6,000 4.18.6
20,00 4.18,6
40,000 4.18.6
7,754 4.18.6
5,000 4.18.6
116,655 4.18.4
1,929,677
1,447,258
1,854,300 4.18,6
178,737 4.18.4
T04,18(385,961)
Note: EEl membership fees ar excluded. As of Februar 6,2007 MidAmerican Holdings Company discontinued its membership with the Edison
Electrc Institue.
Rocky Mountain Power
PAGE 4.19
Idaho Results Of Operations December 2007
Idaho Intervenor FundingI TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Misc. General Expense 930 3 28,865 10 Situs 28,865 4.19.1
Adjustment to Rate Base:
Deferred Regulatory Expense
Deferred Regulatory Expense
182M
182M
1
3
(28,402)
35,160
6,759
10
10
Situs
Situs
(28,402) 4.19.1
35,160 4.19.1
6,759
Adjustment Detail:
Deber 2006 Balance
Dember 2007 Balance
December 2007 Average Balance
27,938
28,865
28,402
,
Description of Adjustment:
This adjustment amortizes the Idaho Intervenor funding regulatory asset over a period of one (1) year.
,
.
.
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Rocky Mountain Power
PAGE 4.20
Idaho Results of Operations December 2007
10 Pension Expense Cash Basist TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Pension expense 930 17,244,099 SO 5.976%1,030,486 4.20.1
Adjustment to Tax:
Schedule M Addtion SCHMDT (154,688)SO 5.976%(9.244)4.20.1
Deferred Income Tax Expense 41010 (1,013,498)SO 5.976%(60,565)4.20.1
Deferred Income Tax Expense 41110 955,173 SO 5.976%57,080 4.20.1
Defeed Income Tax Balance 190 (987,502)SO 5.976%(59,012)4.20.1
,
Description of Adjustment:
This adjustment replaces the actuarially determined pension expense for 12 months ended December 2007 with the actual amount funded (cash basis).
After conversion to cash basis, a Schedule M adjustment is no longer necessary, so it is removed from results.
,
.
.
,
Results of Operations - December 2007
Idaho General Rate Case
Convert Actuarial Pension Expense to Cash Basis
Cash Basis Pension Expense
Pension Funding CY 2008
Electric Portion
Non-Joint Venture Portion
Pension Funding to Electric Expense
Accrual Basis Pension Expense
Account 501100 Pension/Superannuation 12 mos ended 12/31/2007
Pro Forma Adjustment to 12/2008 Budget in WEBA Adjustment
Actuarial Pension Expense in Results
Total Difference
O&M portion
Adjustment to O&M
65,627,000
95.402%
62,609,218
96.225%
47,272,712
(11,958,208)
4.20,1
60,245,701
35,314,564
24,931,137
69.17%
17,244,099 Ref 4.20
IDAHO REVISED PROTOCOl
Pag 5.0 Tot
Net Po Cost Adjutmeti (Tal 5)
TOTAL
5.1 5.2 5.3 5.4 5.5 0.West Valley Lease James River
(MEHC)& Royal Ofset I
Totl Nonaled NPC T3Sludy Conclten LilMtn Gre Tags BPA Exane 0
1 Op Revs:
2 Ge Busins Revenue
3 Interartal
4 Spel Saf 49,541,526 49,541,526
5 Ot Ope Revenues 395,409 395,409
6 Tot Ope Revenues 49,93,936 49,541,52 395,409
7
8 Opti Exses:9 Steam Pro (112,610)(112,810)10 Nuc Pro11 Hyd Pro12 Ot Pow Sup 56,86,95 52,867,95 (1,113,06)(55,961)5,368,23
13 Tniio 342,146 342,146
14 Ditrbu15 Cusom Acc
16 Cusom 5e & Info
17 Sali16 Admlne & Geral (241,50)(241,50)
19 Tot O&M Exses 56,85,787 52,897,286 (1,35,561 (55,961)5,36,023
20 Da (86)(662)
21 Amat (12,705)(12,7051
22 Taxs Ot Th Inc
23 Inc Tax: Fedl (2,434,706)(1,121,194)329,191 132,110 16,697 (1,793,510)
24 Stae (33,831 (152,352)44,732 17,952 2,541 (243,7081
25 Da inc Taxs 145,221 145,221
26 Invim Tax Cre Adj.
27 Mi Reven & Exse
28 Tot Op EinSl:54,221,100 51,623,743 (848,786)150,062 (34,723)3,330,805
29
30 Ope Rev For Retum (4,284,1841 (2,08,217)848,786 245,34 34,723 (3,330,80)
31
32 Rat Base:33 EIe Pla In Ser (39,1171 (39,117)~34 Pl He for Fut Use ..35 Mise Oaem Debis r_
36 Ele PJ Acq Adj
':O
37 Nucir Fue38 Pre 0,)
39 Fue Sto e:
40 Mat & Sup41 Wor Cap42 Weatat Loa
43 Mis Rete Base
44 Tot EIa Pla:(39,117)(39,117)~C - ii"
45
I",J.
46 Daio:~0
47 Ace PlO For Dee 1,565 1,56
48 Ace Pl For Amo 22,99 2299
49 Ac De inc Tax (176,84)(176,84)
50 lJ ITC
51 Cusr Aå For Const
52 Custom SaM Desil
53 MIi Dedions
54
55 Tot Des:(152,08)(152,085)
56
57 Tot Rat Base:(191,202)(191,202)
58
59
60 Estated ROE im -1.754%-0.85%0.353%0.101%0.014%.1.367%0.00%
61
62
63
64 TAX CALCULATION:
65
66 Opting Revnu (6,90,485)(3,355,762)1,367,930 395,409 55,961 (5,368,023)
67 Ot Deio
68 Interst (AFUDC) 691ntit70 Scle "M Add (38,653)(32,653).71 SCIe"M" Dans
72 Inc Befor Tax (7,287,138)(3,35,762)965,277 395,409 55,961 (5,36,023)
73
74 Stae Inc Tax (33,83)(152,352)44,732 17,952 2,541 (243,708)
75
76 Taxbl inc (6,95,30)(3,203,411)940,545 377,458 53,421 (5,124,315)
77
78 Fadlnc Taxs (2,43,706)(1,121,194)329,191 132,110 18,697 (1,793,5101
Rocky Mountain Power PAGE 5.1
Idaho Results of Operations December 2001
NPC 13 Study,TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Sales for Resale
Existing Firm PPL 447NPC 3 727,646 SG 6.395%46,531
Existing Firm UPL 447NPC 3 (421,557)SG 6.395%(26,957)
Post-merger Firm 447NPC 3 760,386,762 SG 6.395%48,624,765
Non-firm 447NPC 3 13,621,686 SE 6,586%897,187
Total Revenue Adjustments 774,314,537 49,541,526 5,1.1
Adjustment to Expense:
Purchased Power
Existing Finn Demand PPL 555NPC 3 (54,793,059)SG 6,395%(3,503,874)
Existing Finn Demand UPL 555NPC 3 39,514,532 SG 6.395%2,526,852
Existing Firm Energy 555NPC 3 (18,379,213)SE 6.586%(1,210,540)
Post-merger Finn 555NPC 3 825,794,326 SG 6.395%52,807,410
Secondary~FGases-~- ~---555NPC 3 (45,241,618)SE 6.586%(2,979,823)
Seasonal Contracts 555NPC 3 9,404,790 SSGC 5.246%493,382
Other Generation 555NPC 3 1,959,613 SG 6,395%125,312
Total Purchased Power Adjustment 758,259,371 48,258,719 5.1.1
Wheeling
Existing Firm PPL 565NPC 3 (5,768,382)SG 6,395%(368,873)
Existing Finn UPL 565NPC 3 11,150 SG 6,395%713
Post-merger Firm 565NPC 3 12,874,774 SG 6.395%823,308INon-finn 565NPC 3 (1,715,669)SE 6.586%(113,002)
Total Wheeling Expense Adj 5,401,873 342,146 5.1.1
Fuel Consumed - Coal 501NPC 3 14,185,217 SE 6.586%934,304
Fuel Consumed - Gas 501NPC 3 (19,191,030)SE 6,586%(1,264,010)
Steam from Other Sources 503NPC 3 (1,723,839)SE 6.586%(113,540)
Natural Gas Consumed 547NPC 3 112,689,561 SE 6.586%7,422,257
Simple Cycle Combustion Turbines 547NPC 3 (41,501,189)SSECT 5,997%(2,488,831 )
Cholla I APS Exchange 501NPC 3 5,469,296 SSECH 7,143%390,676
Total Fuel Exp 69,928,016 4,880,856 5,1,1
Net Power Cost 59,274,723 3,940,195
Description of Adjustment:
The net power cost adjustment normali~es power costs by adjusting sales for resale, purchased power, wheeling and fuel in a manner
consistent with the contractual terms of sales and purchase agreements, and normal hydro and weather conditions for the twelve-month
period ending December 31,2007.
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.
1
.
1
. PacifiCorp
Idaho Results of Operations
Net Power Cost Adjustment
Amounts Removed from Accounts to make them consistent with GRID
Non.Net Power Costs
Sales for Resale (Account 447)
Transmission Services. revenues received not included in GRID
On System Wholesale sales - these are not included in GRID
Purchased Power (Account 555)
BPA regional adjustments - these are credits that are passed
to customers in the northwest and are not included in GRID
Fuel Expense (Accounts 501, 503 and 547)
Chona:
Chona fuel handling
Chona start-up diesel
Other non GRID Cholla
Other Plants:
. Fuel handling
Start up gas
Diesel
Residual disposal
Other non GRID
Total non-NPC costs to remove to match GRID
Other Adjustment to make accounts consistent with GRID
Adjustment 5.4 - Green Tags
~
Page 5,1,2
834.438
6,781,850
7,616,288
(22,499,508)
1,592,138
169,657
1,205
1,762,999
5,007,693
572,774
6,511,285
701,993
26,236
12,819,982
(15,532,814)
(849,640)
.Rocky Mountain Power
Semi Annual Results. December 2007
Net Power Cost Study
Seasonal Contracts
Page 5,1.3
Morgan Stanley p244840
Morgan Stanley p244841
UBS p268848
5,282,160
1,744,080
2,378,550
9,404,790
.
,
Page 5.1.4
PaciCorp Study Results.MERGED PEANERGY SPLIT
Period Ending (S)
Dec-B Mer preMerger PreMerger
01108-1218 ~Energy Non-Firm post-Mergr
SPECIAL SALES FOR RESALE
Pacifc Pre Merger 24,336,673 24,336,673
Post Merger 1,573,735,824 1,573,735,824
Utah Pre Merger 25,490,584 25,490,584
NonFirm Sub Total
TOTAL SPECIAL SALES 1,623,563,080 49,827,257 1,573,735,824
PURCHASED POWER & NET INTERCHANGE
BPA Peak Purhase 47,058,002 47,058,002
Pacific Capaty 1,356,360 600,000 756,360
Mid Columbia 52,528,561 15,758,568 36,769,993
Miscacific 7,304,379 1,514,656 5,789,722
a.F. ContrctPL 75,672,406 6,656,229 32,430,117 36,586,060
Pacific Sub Total 183,919,708 71,587,456 75,746,192 36,586,060
Gemstate 2,716,400 2,716,00
GSLM
OF ContrctPL 106,918,00 23,804,004 10,201,716 72,912,280
IPPLayoff 25,490,584 25,490,584
UP&Lto PP&L-Utah Sub Total 135,124,984 49,294,587 12,918,116 72,912,280
AMP Resorc (Cove Fort)
APSp167566
APS p172318
APSp205692
APS Supplemental 9,858,839 9,858,839
Aquila hydro hege
Avoided Cost Resourc
Blanding Purcase 19,779 19,n9
Tolling Agreement 95,756,475 95,756,475
Clark S&i Agrement (Net)
Combine Hils 4,96,467 4,96,467
Constellation p257677 7,837,752 7,837,752
Constellation p257678 2,578,848 2,578,848
Constellation p268849 4,919,400 4,919,400
Deseret Purcse 30,596,424 30,596,424
DukeHLH
Duke p99206
Geoia-Pacific Camas 7,754,963 7,754,963
Hermiston Purcase 95,655,202 95,655,202
Hurrcane Purchase 328,501 328,501
Idaho Powr RTSA Purcase 2,592,292 2,592,292
Kennectt Generation Incentie 8,219,132 8,219,132
MagCorp
Magor Reseives 1,755,360 1,755,360
Morgan Stanley p189046 10,718,400 10,718,400
Moran Stanley p196538
Morgan Stanley p206oo6
Moan Stanley p206008
Moan Stanley p244840 5,282,160 5,282,160,Morgan Stanley p244841 1,744,080 1,744,080
Morgan Stanley p272153-6-8
Moran Stanley p272154-7
Nebo Heat Rate Option 5,293,420 5,293,420
NuCor 4,610,400 4,610,400
P4 Proucon 14,968,800 14,968,800
Roc River 5,076,810 5,076,810
.
.
~
PiicifiCorp
Period Ending
Dec8
Roseburg Foret Prouc
Transta Purcse
TriState Purcase
UBS p223199
UBSp268848
UBS p268850
UBS Summer Purchase
Weyerhaeuser Resee
Wolverne Crek
Place Holder
BPA Conservation Rate Creit
DSM (Irrgation)
NCPA 309
PSCO Exche
Tralta p37134s37134
Short Term Firm Purchases
Study Results
MERGED PEAENERGY SPLIT
(S)
Merg
01/08-12/08
8,766,080
12,435,212
2,378,550
291,600
8,979,289
900,000
(1,032,845)
669,392,505
PreMerger~PreMerger
Energ Non-Finn
Page 5.1.5
Post.Merer
8,766,080
12,435,212
2,378,550
291,600
8,979,289
90,000
(1,032,845)
869,392,505
.
.
.
PacifiCorp
Period Ending
De08
New Firm Sub Total
Non Firm Sub Total
TOTAL PURCHASED PW & NET INT.
WHEELING & U. OF F. EXPENSE
Pacific Firm Wheeling and Use of Facilitie
Utah Firm Whling and Use of Facilities
Post Merger
Nonfirm Wheeling
TOTAL WHEELING & U. OF F. EXPENSE
THERMAL FUEL BURN EXPENSE
Carbn
Cholla
Colstrp
Craig
Currnt Crek
Dave Johnston
Gadsby
GadsbyCT
Hayden
Hermiston
Hunter
Huntington
Jim Bridger
Lake Side
Litte Mountain
Naughton
West Valley
Wyodak
TOTAL FUEL BURN EXPENSE
OTHER GENERATION EXPENSE
Blundell
Goonoe Wind
Wind Integration Charge
TOTAL OTHER GEN. EXPENSE
NET POWER COST
Study Results
MERGED PEAKINERGY SPLIT
($)
Merged
0110.12/08
1,222,643,895
PreMerger~PreMerger~Non.Firm
1,541,688,587 120,882,043 88,664,308
Page 5.1,6
Post.Merger
1,222,643,895
1,332,142,236
31,031,711 31,031,711
172,448 172,448
80,702,693 80,702,693
87,131 87,131
111,993,983 31,204,159 87,131 80,702,693
14,722,427 14,722,427
55,873,173 55,873,173
11,252,602 11,252,602
15,815,318 15,815,318
149,742,724 149,742,724
48,253,356 48,253,356
7,899,751 7,899,751
15,030,021 15,030,021
10,149,002 10,149,002
59,594,910 59,594,910
102,028,478 102,028,478
75,024,034 75,024,034
129,851,748 129,851,748
153,926,731 153,926,731
10,567,169 10,567,169
77,478,597 77,478,597
8,164,327 8,164,327
18,710,410 18,710,410
96,084,777 .96,084,777
3,121,240 3,121,240
1,959,613
5,080,853
1,959,613
5,080,853
999,285,120 102,258,946 88,664,308 969,252,762
=============== ============= =========== =========== ================(160,890,895)
=============== ============= =========== =========== ================
Pag 5.1.7
PiiIfCorp SA . CY20_2oo1 03 21
f)Ne powr Cost Anals,Pe Ending De 200 01JO121
(SI
SPECIAL SALES FOR RESALE
Bla His 11,33,872
Blancin
BPA Flad Sal
BPA winc 1,561.591
FlaadHue Sale 98,499
LADWP (IPP Laof 25,490.58
PSCO 81.721,077
San River Proje 13,06.785
SCE
Sierr Pac 2 33,881,08
SMUD 13,001,801
UAMPS 122383
UAMPS 14238 702,720
UMPAII 9,780,072
Sho Ten Fin Sals 1,012,40,927
Sysem Ba Sa 439,83,104
TOTAL SPECIAL SALES 1.623,56.08
PURCHASED POWER & NET INTERCHANGE
AMP Resorcs (Cove Foil
APS p18756
APS p172318
APSp205692
APS Suppmenal 9.858,839
Aqula hyro hedAvo Cost Res
BI Purcse 19,779
Toi Agre 95.756,475
Clerk 5&1 Agret (NelCom Hi 4.96,467,Contel p257877 7,837,752
Conellatio p257878 2,578,848
Coneltio p26849 4,919.40
Dese Purase 30,598,424
Doug PUD Satt 1,88,330
DukeHLHDup906Gete 2,718,40
~ac Camas 7,754,96
Gr Couty 10 aWf puas 6,80,379
Hellon Purese 95,855,202
Hune Purce 328,501
Idah Pow RTSA Purse 2,592.29
IPP Pur 25,490,58
Kem Geti Inc 8,219,132
MagCorMaor Ress 1,755,36
Moan Stanley p1890 10,718,40
Mar Stanley p19853
Mar Stanly p20800
Moran Stanly p28
Moran Stanley p2440 5,282,160
Moan Sla p244841 1,744,08
Mon Stanly p27215~
Moran Stanley p2721547
NebO Heat Rate Opt 5,29,420
NuCor 4,610,400
P4 prouction 14,96.80
PGECove 50,00
Roc Riv 5,078,810
Rosebrg Forell Pros 8,788,08
SmH Purcases east 539,803
SmaH Purcses well
TrasAna Purase
Trie Puase 12,43,212
UBS p223199
UBS p26888 2,378,55
UBS p26850
UBS Summe Purase,Weyeuser Resee 291,800
Woleri Cre 8,979,289
Pla Hoer
BPA Conservati Rate Cre
DSM (Irratio)
QFCalWomia 4,097,924
QF Idah 4,101,55
Page 5.1.
PIlCor SA . CY2O8_208 03 27
ø Net Pow Cos AnalySiIPe Ending De 200 01/08121
QF Ora 17,618,99
QF Ut 716,097
QF Washng 2,191,788
QFWy 667,30
BISl 26,524,30
Dos Conty Forst Pro QF 618,772
D.R. JosonEver Bloow QF 3,45,709
ExonMo QF 36,117,320
Kø QF 8,272,489
Mo Wind 1 QF 8,074,30
Mouai Wi 2 QF 3,559,395
Pi Ridge QFSclnd QF 1,80,759
Sipl Ptspltes 3,770,428
Spah For Wtn 2 QF 2,154,674
Sunysi 28,94,526
TeSOQFUS Meg QF 10,198,345W~QF 21,163,919
Can Entiie
Che - Roc Reac 3,921,09
Do . Wels 8,94,752
Grant OIiplme 12,210,978
Gr Reesobl (7,90,311)
Grant Mean Pr 20,60,08
Gr Sui~56,84
Gr . Prist RapGra . Wenm 12,514,788
APGIICoIm Cipa Exan
APS Exch
APS s286207861
Bla Hi CTi 1,35,36
BPA Ex
BPA FC " Stor Agrmet
BPA FC IV Storge Agr
BPA Pea 47,05,00,BPA So. Idl ExchanCow Sw
CPU Sha Cap
EWEB FC I Sto Agremet
Mor St 207862/NCPA 30PSCo Ex 90,00
PSCO FC II Stor AgrtRad EiSCL Si.te Lin Stor Agrt
Tralt p37134s37134 (1,03,145)
Tritae Ex
Sho Ten Fir Purses 55,272,853
System B8lng Pues 311,119,652
TOTAL PURCHASED PW & NE INT.1,541,68,587
WHEELING & U. OF F. EXENSEFir Whim 111,90,852
NoFir Wh 87,131
TOTAL WHEELING & U. OF F. EXENSE 111,99,983
COAL FUEL BURN EXPENSECar 14,722,427
ChoUa 55,873,173
Colstri 11,252,60
Craig 15,815,318
Dave Joniton 48,253,35
Ha 10,14g,00
Hun 102,028,478
Huntion 75,024,03
Jim Brier 129,851,748
Nauto 77,478,597
Wyk 18,710,410
TOTAL COAL FUEL BURN EXENSE 559,159,145
~GAS FUEL BURN EXPENSE
Cu Cre 149,742,724
Gaby 7,899,751
GaIbCT 15,03,021
Heto 59,59,910
Lae Sid 153,92,731
Pag 5.1.9
.P8c/fCot
o
Pe Ending De 20
Lit Motain
WesVaHey
SA. CY20_20 03 27
Ne Pow Cost AnaliS
01/08.121
10,567,169
8,164,327
TOTAL GAS FUEL BURN EXENSE 40,925,633
OTHER GENERATION EXPENSE
Blund
Foote Crek IGl Win
Goono Win
Lea Jur 1
Marng
Rol Hi. Wind
Seen Mi WiWi Integn Cha
3,121,240
1,959,613
TOTAL OTHER GEN. EXPENSE 5,08,653
=--============
NET POWR COST 99,265,120
.
~
Pag 5.1.10
PliltCOrp SA. CY2ool_2oo8 03 21
ø Net Powr Cos Ansi.Pe Ending De 200 01101.1211
===============
Net Pow CoatJet System Load 17.21
(MWI
Bri Los Plact
BPA Henton Losses 70,679
DSM COO Kepe
DSM (irrl (31
Maor Cuiilt (29,58)
Mosanto CurStati Stic 71,977
Tot Adjutmts to Loa 113,073
Sysem Loa 57,957,598
NET SYSTEM LOAD 58,070,670
SPECIAL SALES FOR RESALE
BIaHiI 363,694Bli
BPA Flatad Sal
BPAWin 39,494FliiHun Sal 13,140
LAOWP (IPP Lay 613,20
PSCO 926,621
Sai River Pro 219,60
SCE
Siena Pac 2 461,175
SMUD 351,40
UAMPS 12238
UAMPS s4236 17,56
UMPAII 224,328
Sho Tei Fin Sales 15,769,706.System Ba Sals 8,760,65
TOTAL SPECIAL SALES 25,760,98
==========-===
TOTAL REQUIREMENTS 83,831,65==----========
PURCHASED POWER & NET INTRCHANGE
AMP Resol(Cove ForI
APS p16756
APSp172318
APSp20592
APS Supmetal 245,45
Aqu hy heAvo Coat Res
Bla Puase 26
Tol Agi 1,142,80
Cla S&I Agr (Net)Com Hi 116,201
COIelltio p257677 81,60
COIelet p257678 16,60
Constelti p268S9 38,40
Dese Purse 787,925
Do PUD Setme 68,877
DukeHLHQup906Getae 37,448
Geia-Pac Camas 122,183
Grt Couty 1 ° aMW puas 87,634
Heison Purcase 1,85,603
Hun pur8le 4,38
Idah Pow RTSA Puese 39,670
IPP Pure 613,200
Ken Getio IncentiveMiior
MagCor Reses
Mon Stale p1890 246,40
Mor Sta p1968.Moen Stale p206Mor Stany p206
Mor Staney p244S40 62,40
Moran Stanley p244S41 20,80
Mo Sta p27215U
Morn Stanly p272154.7
Page 5.1.11
PiIfCorp SA . CY200_2oo8 03 27
0 Net Pow Cost Anlysis.Ped Ending De 200 0110.1211
Neb Heat Rate Op 76,53
NuCorP4 Pro
PGECov 12,024
RocRlver 143,089
Rose For Pr 153,792
Sm Pus east 8,267
SmaR Puass wetTrafta PurseTn-ta pure 199.833
UBSp23199UBSp28 19,200
UBSp26
UBS Sum Pusewøy_ ReservWol Crek 166,06
Pla Hol
QF Calora 35,50
QF Ida 77,028
QFOr 213,698
QF Utah 14,424
QF Wason 20,339
QFWy 11,394
Biomass 175,479
Dogl. Cou For Prs QF 13,38
D.R. .i
Eve BioPow QF 67,243
ExonMo QF 712,320
Kenne QF 193,248
Mouta Win 1 QF 125,661
Motain Wi 2 QF 67,736
Pio Rid QFScI QF 32,760
Sim Phoes 74,66
Spanih For Wi 2 QF 35,782
Susi 38,179.TesorQF
US Masim QF 175,68
weyrher QF 324,054
Cann Entt (64,307)
Chel . Roc Rea 325,50
Do' . WeH 361,981
Gr Diplt 443,432
Grnt ReasonabGr Me Pri 244,719
Gra Suru.35,173
Gra . Prist RapsGr . Wan 718,420
APGllCoIiø Capy Exe (267,9471
APS Exch 415
APS 120786p207861
Bla HilCTs
BPA Exnge
BPA FC II Sto Agrmet 258
BPA FC IV Storge Agrnt 2,635
BPA Pea °
BPA So. Ida Exchge 28,647
Cowit Swi 5,63
CPU Shapi Capa
EWEB FC I Ste Agrement 1,30
Mo Sta 207862/NCPA 30
PSCo Exchang
PSCO FC II Stor Agrme 272
Red Exch (4)
SCL State Lin Stor Agre 20,787
TraRa p371343Js37134
Tn-tate Exng
Sho Ter Fin Purcase 8,766,230
System Ba Purses 5,525,674.TOTAL PURCHASED PW & NET INT.25,273,233
COAL GENERATIONCar 1,104,09
Chona 2,837,234
CoIp 1,126,676
Page 5.1.12
Paltotp SA . CY2ool_20 03 27-"Net Pow Cost Analsis
Pe Endig De 200 01108.121
Cra 1,151,458
Dave Joston 5,93,491
Hayn 60,241
Huer 8,229,09
Hunton 6,63,645
Ji Bri 9,90,140
Nauto 5,414,815
Wyak 2,184,148
TOTAL COAL GENERATION 45,132,04
GAS GENERATION
Cun Cre 2,68,701Ga75,202
GaIbCT 142,912He1,85,60
La Si 2,84,34
Li Moai 86,091
Wea VaHe 72,05
TOTAL Gas FIRED GENERATION 7,767,90
HYDRO GENERATION
West Hy
3,861,891
EBS Hy 439,648
TOTAL SYSTEM HYDRO 4,301,539
OTHER GENERATIONBluR 184,326
Bluel Boom Cycle 86,158
Foo Cre I 103,423
Gte WI 1,328
Gø WI 184,423
Lea Ju 1 307,717
Mago 50,09tRol Hie WI 1,02
Sev Mil WI 1,43
,
Page 5.1.13
Pø/tCorp SA. CY20_200 03 27t0Net Pow Cos Ana
Ped Ending De 200 01101218
TOTAL OTHER 1,356,930
================
TOTAL RESOURCES 83,831,654
=================
"TE RACK"
043-3/
FUEL BURNED (MMBtu)Cai 12,795,05
Choa 30,512,993
Coltr 12,195,038
Cri 11,744,891
Dav Johon 65,819,223
Hay 8,48,182
Huter 87,125,387
Hunngon 66,195,031
Jim Bri 104,035,929
Nauon 56,515,298
Wy 25,783,96
Cum Crek 20,313,329
Gadsb 1,03,83
GadCT 1,99,829
Hemston 13,416,793
Lake Sid 20,277,83
Li Motain 1,02,199
West Valy 1,251,266
BURN RATE (MMBtuIl
Carb 11.590
Cho 10.750
Coltr 10.82
Crig 10.200
Da Jalnst 11.09,Hayen 10.630
Huner 10.590
Huntinon 9.970
Jim Bri 10.50
Nauon 10.44
Wy 11.80
Curr Crek 7.56
Gaby 13.810
GadsbyCT 13.970
Herton 7.230
Lak Sid 7.120
Ut Mountain 16.290
West VaHe 17.370
AVERAGE FUEL COST ($IMBtulCarb 1.150
Choa 1.830
Colltr 0.920
Craig 1.35
Dave Joston 0.730
Hayen 1.570
Huer 1.170
Huntin 1.130
Jim Brkge 1.250
Naughton 1.370
Wyak 0.730
Curr Crek 6.670
Gasby 6.830
GadsbyCT 6.830
Henniston 3.590
Lae Side 6.700
Lil Mountain 6.830
WestVallay 2.680
PEAK CAPACITY (NAMEPLA TEl
BludeB 23,Cai 172
ChOii 380
Cotrip 148
Craig 165
Deve Johston 762
Hayde 78
Page 5.1.14
.PKIICorp
o
Pe Ending De 200
HunterHuon
Jim BrirNautoWy
SA . CY200_200 03 27
Net Pow Cost Anasis
0110.121
1,123
892
1,13
700
280
Cuint Cre
Gasby
GasbCTHeronLae SI
Lil Moain
WesVely
552
22
123
248
572
15
205
CAPACIT FACTORBlU 0.91
Cart
ChoUa
CoIslnCra
Dave JohtonHa
HunterHunonJi Bri
Naughton
Wyak
0.73
0.85
0.87
0.79
0.89
0.89
0.83
0.85
0.80
0.88
0.90
Cumt Cre
Gaiby
0.57
0.04
.
~
Rocky Mountain Power PAGE 5.2
Idaho Results of Operations December 2007
West Valley Lease (MEHC) & Contract term,TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Expense
Generation Expense 548 3 (8,018,163)SSGCT 7.373%(591,218)
Rents (Other Generation)550 3 (6,224,389)SSGCT 7.373%(458,9'5)
Maintenance of Structures 552 3 (92,630)SSGCT 7.373%(6,830)
Maintenance of Gen & Electnc Plant 553 3 (577,662)SSGCT 7.373%(42,594)
Maint Misc Other Power Gen 554 3 (136,632)SSGCT 7.373%(10,075)
Other Expenses 557 3 (46,009)SSGCT 7.373%(3,392)
(15,095,485)(1,113,064)5.2.1
Depreciation Expense 4030P 3 (8,971)SSGCT 7.373%(662)5.2,1
Amortization Expense 4040P 3 (172,306)SSGCT 7.373%(12,705)5,2.1
Lease Reduction Amortization 930 3 (241,500)10 Situs (241,500)5.2,2
Adjustment to Rate Base:
Pnme Movers, Leasehold Improvements 343 3 (530,511 )SSGCT 7.373%(39,117)5.2,1
Accum Depreciation Reserve 1080P 3 21,230 SSGCT 7.373%1,565 5,2.1
Accum Amortization Reserve 1111P 3 311,848 SSGCT 7.373%22,994 5,2.1
t Adjustment to Tax:
ADIT 10 Lease 190 3 (176,644)10 Situs (176,644)
Deferred Tax Expense 41110 3 145,221 10 Situs 145,221
Schedule M Addition SCHMAT 3 (382,653)10 Situs (382,653)
Description of Adjustment:
The Company has informed PPM of its intent to terminate the West Valley lease on May 31, 2008. This adjustment removes seven
months of expense and investment from results to align with net power costs. This adjustment also includes amortization of the
deferred lease expense reduction for January 2008 - December 2008.
I
.
.
.
Rocky Mountain Power
Semi-Annual Report December 2007
West Valley Lease - Idaho
Page 5.2.1
Since the lease is expiring May 31,2008, we wil remove June 2007 - December 2007 from results
to reflect the future expense, This wil include the termination payment paid in June 2007,
Remove Leave In
Operation & Maintenance Account Total 2007 June - Dec Jan -May
GENERATION EXP 548 8,999,447 (8,018,163)981,284
RENTS (OTHER GEN)550 10,977,691 (6,224,389)4,753,302
MAINT OF STRUCTURE 552 92,698 (92,630)68
MNT GEN & ELEC PL T 553 624,790 (577,662)47,128
MNT MSC OTH PWR GN 554 136,817 (136,632)185
OTHER EXPENSES 557 82,718 (46,009)36,710
Total June - Dec O&M Expense 20,914,161 (15,095,485)5,818,676
Depreciation & Amortization
Depreciation Expense 4030P 14,531 (8,971)5,560
Amorization Expense 4040P 293,921 (172,306)121,615
Rate Base -112 YE
EPIS 343 1,061,022 (530,511)530,511
Accm Depreciation Reserve 1080P (42,461)21,230 (21,230)
Accm Amortization Reserve 1110P (623,695)311,848 (311,848)
Rocky Mountain Power Page 5,2.2
Idaho General Rate Case Settlement
West Valley Lease Reduction,CY 2008 Amortization (241,500) 930 situs - no ECO
DEFERRAL
Beginning Interest~Ending
Balance Deferral Idaho Portion.8.8278%Balance
311/2006 125,100 9,463 9,463
4/30/2006 9,463 417,000 31,542 70 41,074
5/31/2006 41,074 417,000 31.542 302 72,919
6/3012006 72,919 417,000 31,542 536 104,997
7/3112006 104,997 417,000 31,542 772 137,312
8/31/2006 137,312 417,000 31,542 1,010 169,864
9/30/2006 169,864 417,000 31,542 1,250 202,656
10131/2006 202,656 417,000 31,542 1,491 235,689
11130/2006 235,689 417,000 31,542 1,734 268,965
12/3112006 268,965 417,000 31,542 1,979 302,486
1/31/2007 302,486 417,000 31,542 2,225 336,253
212812007 336,253 417,000 31,542 2,474 370,269
311/2007 370,269 417,000 31,542 2,724 404,535
413012007 404,535 417,000 31,542 2,976 439,053
5/1/2007 439,053 417,000 31,542 3,230 473,825
6130/2007 473,825 417,000 31,542 3,486 508,853
713112007 508,853 417,00 31,542 3,743 54,139
8/31/2007 544,139 417,000 31,542 4,003 579,684
913012007 579,684 417,000 31,542 4,264 615,491
1013112007 615,491 417,000 31,542 4.528 651,561
11/30/2007 651,561 417,000 31,542 4,793 687,896
12/3112007 687,896 417,000 31,542 5,061 724,499
.Per the transaction agreement, costs are allocated to Idaho based on SSGCT at 3/31/2006
AMORTIZATION
Beginning Idaho Ending
Balance Amortization Balance,1/31/2008 724,499 (20,125)704,374
2129/2008 704,374 (20,125)684,249
31112008 684,249 (20,125)664,124
4/30/2008 664,124 (20,125)643,999
5131/2008 643,999 (20,125)623,874
61012008 623,874 (20,125)603,749
7/3112008 603,749 (20,125)583,624
813112008 583,624 (20,125)563,499
913012008 563,499 (20,125)543,374
10/31/2008 543,374 (20,125)523,249
1113012008 523,249 (20,125)503,124
12131/2008 503,124 (20,125)482,999
1/3112009 482,999 (20,125)462,874
212812009 462,874 (20,125)442,749
3131/2009 442,749 (20,125)422,624
4/30/2009 422,624 (20,125)402,499
5/31/2009 402,499 (20,125)382,374
6/3012009 382,374 (20,125)362,249
7/31/2009 362,249 (20,125)342,124
8131/2009 342,124 (20,125)321,999
9/30/2009 321,999 (20,125)301,874
10/31/2009 301,874 (20,125)281,750
11/30/2009 281,750 (20,125)261,625
12131/2009 261,625 (20,125)241,500
1/3112010 241,500 (20.125)221,375
2128/2010 221,375 (20,125)201,250
313112010 201,250 (20,125)181,125
4/30/2010 181,125 (20,125)161,000
5/31/2010 161,000 (20,125)140,875
6130/2010 140,875 (20,125)120,750
7/31/2010 120,750 (20,125)100,625
8131/2010 100,625 (20,125)80,500,9/30/2010 80,500 (20,125)60,375
10/31/2010 60,375 (20,125)40,250
1113012010 40,250 (20,125)20,125
1213112010 20,125 (20,125)0
Rocky Mountain Power PAGE 5.3
Idaho Results of Operations December 2001
James River Royalty Offset I Little Mtn.TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Oter Electc Revenue 456 3 6,565,987 SG 6.395%419,878 Below
Other Electric Revenue 456 3 (382,636)SG 6.395%(24,469)Below
6,183,351 395,409
Adlustment Detail:
James River Offset
Capital Recovery $
Major Maintenance Allowance
Total Offset
12 MOS ENDED
12/31/2008
6,085,678
480,309
6,565.987
Little Mountain Revenue Forecast
Forecasted Steam sales. 12 months ended 1213112008
Less: Steam sales in unadjusted results
Total Difference
3,939.693
4,322,329
(382,636)
.
Description of Adjustment:.
This adjustment credits Other Electric Revenues for the James River Royalty Offset as agreed in the January 13, 1993 agreement. Since
the cost of James River power is included in the net power cost adjustment, we need to add a credit for capital cost recovery and
maintenance cost recovery,
This adjustment also accounts for an increase in the Little Mountain Steam sales which is attributable to matching revenue with the
assumptions used in the Net Power Cost study,
.
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Rocky Mountain Power PAGE 5.4
Idaho Results of Operations December 2007
Green Tags,TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Revenue:
Green Tag Purchases 555NPC (849,640)SE 6.586%(55,961)5.4.1
,
Description of Adjustment:
This adjustment removes the cost of green tags purchased as part of the Blue Sky program,
,
t PacifiCorp
Green Tag Power Purchases
These accounts record Green Tag purchases which must be removed from results.
January - December 2007
Account
546536
1,014,376
,
,
Account
546538
(164,736)
Total
849,640
Ref 5.4
Page 5.4.1
Rocky Mountain Power
PAGE 5,5
Idaho Results of Operations December 2007
SPA Exchange.TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Purchase Power Expense 555 1 12,992,463 OR Situs
Purchased Power Expense 555 1 4,139,022 WA Situs
Purchase Power Expense 555 1 5,368,023 10 Situs 5,368,023
22,499,508 5,368,023 5.5,1
.
Description of Adjustment:
The Company receives a monthly BPA purchase power credit frm BPA. This credit is treated as a 100% pass~through to eligible customers.
Both a revenue credit and a purchase power expense credit is posted to unadjusted results. Both of these transactons are to be removed
frm results. This adjustment reverses the BPA purchase power expense credit recorded. The BPA revenue credit is removed from results in
revenue adjustment 3,2, BPA discontinued the credit in May 2007, The pass-through of the credits were discontinued via the following
comission orders:
Idaho: Docket #PAC-E-07-10 Order # 30329
Washington: Docket #UE-071 0016 Order #01
Oregon: Advice 07-013
-
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Pag 6.0 Tot
0ø & Amotio (Tab 6)
TOTAL.6.1 6.2 6.3 6.4 6.5 0
Deio &De &Amolzti Arn Hy New De Rates Ne De Rete.
Tot Nomlled Ex Rese oesiin9 Expase AccmDe 0
1 0p Revs:
2 Ge Busiss Revnus
3 Intrttal4 Spa Sals5 Ot Op Reven
6 Tot Opti Revues
7
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8 Op Exs:(j)
9 St Proon10 Nu Pro11 Hy Pr12 Ot Po Sup
13 Trall14 DI15 Cu Acc16 CUlom se & Inf
17 Sas18 Adme & Ge
19 Tot O& Exses20 Deio (1,90,50)1,773,43 228,598 (3,907,535)21 Ar 44,46 44,46
22 Tax. Ot Th Inc
23 1_ Tax: Fedral (371,95)(67,378)(5,64)241,06
24 Sle (50,54)(82,531 (7671 32,757
25 De Ince Taxes 778,611 (86,755)86,367
26 Invtm Tax CreR Adj.
27 Mi Reven & Expse
28 Tot Openg Exes:(1,50,927)1,127,988 135,432 (2,768,347)
28
30 0p Rev For Retur 1,50,927 (1,127,981 (135,4321 2,788,347
31
32 Re Base:33 EI Plnt In ser.34 Pla Hel for Futur Use35 Mi De De
36 Ele Pla Acq Adj
37 Nucar FUl
38 Pint
38 FUl Stoc40 Maer & Sup41 Wo Capal
42 weti loas
43 Mi Rat Base
44 Tot EI Pl
45
46 De,:
47 Acc PlO For De 952,751 (88,717)(114,299)1,95,788
46 Ac Pl For Am (22,232)(2,23)
49 Acc De inc Tax (62,221 43,378 (669,603)
50 Unart ITC
51 CUlom Aav For Cot
52 Cust sei Desit53 Mi Deios
54
55 Tot De.:30,293 (90,949)(70,921)(669,603)1,953,768
56
57 Tot Rat Base:304,293 (90,949)(70,921)(669,603)1,953,788
58
5960 Estted ROE im 0.60 -0.46%0.23%-0.05%1.155%-o.05O 0.00%
61
62
63
64 TAX CACULATION:
6566 Opng Reve 1,861,03 (1,817,89)(228,598)3,907,53
67 () Deios
68 Intst (AFUOC)
69 Intert .70 SCule"M" Addit (2,974,317)211,706 (3,186,023)
71 SCle"M" Ded
72 1- Ba Tax (1,113,2791 (1,817,8991 (16,892)721,512
7374 Steelnc Tax (50,54)(82,53)(767)32,757
7576 Tax Inc (1,06,736)(1,735,36)(16,125)68,756
77
78 Fedra inc Tax.(371,9581 (607,378)(5,64)241,06
Rocky Mountain Power PAGE 6,1
Idaho Results of Operations December 2007.Depreciation & Amortization Expense
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense
Steam Production 403SP 2 1,212,087 SG 6.395%77,510
Steam Production 403SP 2 43,246 SSGCH 5.833%2,523
Hydro Production 403HP 2 87,968 SG-P 6.395%5,625
Other Production 4030P 2 12,296,487 SG 6.395%786,328
Transmission 403TP 2 1,219,816 SG 6,395%78,00
Distribution - Oregon 403364 2 111,624 OR Situs
Distribution - Utah 403364 2 343,617 UT Situs
Distribution - Idaho 403364 2 75,873 10 Situs 75,873
Distribution - Wyoming 403364 2 130,487 WYE Situs
General Plant. Oregon 403GP 2 189 OR Situs
General Plant - Utah 403GP 2 2,125 UT Situs
General Plant 403GP 2 128,305 SO 5.953%7,638
General Plant 403GP 2 13,992 SG 6,395%895
Mining Plant 403MP 2 39,573 SE 6.586%2,606
Intangible Plant 404IP 2 68,677 .SO 5.953ev ..4,088..
15,774,066 1,041,091 6.1,1
Steam Production 403SP 3 603,739 SG 6.395%38,608
Steam Production 403SP 3 1,948,618 SSGCH 5,833%113,671
Hydro Production 403HP 3 368,038 SG-P 6.395%23,535
Hydro Production 403HP 3 201,836 SG-U 6,395%12,907
Other Production 4030P 3 7,035,281 SG 6.395%449,888.Transmission 403TP 3 1,261,481 SG 6.395%80,668
Distribution - California 403364 3 84,764 CA Situs
Distribution - Oregon 403364 3 147,817 OR Situs
Distribution - Utah 403364 3 419,702 UT Situs
Distnbution - Wyoming 403364 3 81,660 WYE Situs
General Plant 403GP 3 288,166 SO 5,953%17,155
Intangible Plant 4041P 3 631,389 SG.p 6.395%40,376
13,072,492 776,808 6,1,1
Description of Adjustment:
This adjustment enters into the test period results depreciation and amortization expense for the major plant additions added to rate base in
adjustment 8.6.
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1
Rocky Mountain Power PAGE 6.2.Idaho Results of Operations December 2007
Depreciation & Amortization Reserve
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Reserve
Steam Production 108SP 2 (60,043)SG 6.395%(38,755)
Steam Production 108SP 2 (21,623)SSGCH 5.833%(1,261)
Hydro Production 108HP 2 (43,984)SG-P 6.395%(2,813)
Other Production 1080P 2 (6,148,243)SG 6.395%(393,164)
Transmission 108TP 2 (609,908)SG 6.395%(39,002)
Distribution. Oreon 108364 2 (55,812)OR Situs
Distribution - Utah 108364 2 (171,809)UT Situs
Distribution - Idaho 108364 2 (37,937)10 Situs (37,937)
Distrbution - Wyoming 108364 2 (65,243)WYE Situs
General Plant - Oregon 108GP 2 (94)OR Situs
General Plant. Utah 108GP 2 (1,063)UT Situs
General Plant 108GP 2 (64,153)SO 5,953%(3,819)
General Plant 108GP 2 (6,996)SG 6,395%(447)
Mining Plant 108MP 2 (19,786)SE 6.586%(1,303)
Intangible Plant 1111P 2 (34,339)SO 5.953%(2,044)
(7,887,033)(520,546)6,2.1
Steam Production 108SP 3 (301,870)SG 6,395%(19,304)
Steam Production 108SP 3 (974,309)SSGCH 5.833%(56,836)
Hydro Production 108HP 3 (184,019)SG-P 6.395%(11,768)
Hydro Prouction 108HP 3 (100,918)SG-U 6.395%(6,453).Oter Production 1080P 3 (3,517,641 )SG 6,395%(224,94)
Transmission 108TP 3 (630,741)SG 6,395%(40,334)
Distribution - Califomia 108364 3 (42,382)CA Situs
Distribution - Oreon 108364 3 (73,908)OR Situs
Distribution. Utah 108364 3 (209,851)UT Situs
Distribution. Wyoming 108364 3 (40,830)WYE Situs
General Plant 108GP 3 (144,083)SO 5.953%(8,577)
Intangible Plant 1111P 3 (315,695)SG-P 6,395%(20,188)
(6,536,246)(388,404) 6.2.1
Description of Adjustment:
This adjustment enters into the test period results depreciation and amortization reserve for the major plant additions added to rate base in
adjustment 8.6.
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1
Rocky Mountain Power
PAGE 6,3.Idaho Results of Operations December 2007
Hydro Decomissioning
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Depreciation Expense 403HP 3 2.062,764 SG 6.3947%131,908
Depreciation Expense 403HP 3 1,512,015 SG 6.3947%96,689
3,574,779 228,598 6.3.1
Adjustment to Tax:
SCHM Addition Temporary SCHMAT 3 3,574,779 SCHMDEXP 5,9276%211,899 6,3.2
DITExpense 41010 3 (1,356,664)SG 6.3947%(86,755)6.3,2
Deferred Income Tax Balance 282 3 678,332 SG 6.3947%43,378 6.3.2
Adjustment to Rate Base:
Depreciation Reserve 108HP 3 (1,031,382)SG 6,3947%(65,954)
Depreciation Reserve 108HP 3 (756,007)SG 6,3947%(48,345)
(1,787,390)(114,299)Below
Adjustment Detail
Depreciation Expense. West Side
Depreciation Expense - East Side
Total Depreciation Expense
2,062,764
1,512,015
3,574,779 6.3.1
.Depreciation Reserve. West Side
Depreciation Reserve. East Side
(1,031,382)
(756,007)
(1,787,390)
Description of Adjustment:
Based on the Company's latest depreciation study an additional $19.4 milion is required for
the decommissioning of various hydro
facilties, This adjustment includes an annual level of expense in results as agreed to in the depreciation study.
,
~ Rocky Mountain Power
Semi Annual Report - December 2007
Hydro Decommissioning Reserve
Description
Decommissioning Reserve
Amortization Period
Annual Accrual
West Side Resources
East Side Resources
West Side Annual Accrual
East Side Annual Accrual
Total Annual Accrual
-
,
6.3.1
Amount
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5.43
3,574,779
57.7%
42.3%
2,062,764
1,512,015
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6.
1
Rocky Mountain Power PAGE 6.4.Idaho Results of Operations December 2007
New Depr Rates Expense
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Depreciation Expense 403SP 2 (16,359,113)SG 6.3947%(1,04,123)
Depreciation Expense 403SP 2 (3,370,978)SSGCH 5.8334%(196,643)
Depreciation Expense 403SP 2 (13,747,134)SG 6.3947%(879,094)
Depreciation Expense 403SP 2 (13,712,328)SG 6.3947%(876.868)
Depreciation Expense 403HP 2 (720,834)SG-P 6.3947%(46,095)
Depreciation Expense 403HP 2 167,874 SG-U 6.3947%10,735
Depreiation Expense 403HP 2 83,585 SG-U 6.3947%5,345
Depreciation Expense 403HP 2 (987,633)SG-P 6,3947%(63,157)
Depreciation Expense 4030P 2 (1,839,081 )SG 6.3947%(117,604)
Depreciation Expense 4030P 2 (572,511)SSGCT 7,3735%(42,214)
Depreciation Expense 4030P 2 86,672 SG 6.3947%5,542
Depreciation Expense 403TP 2 (1,294,599)SG 6.3947%(82,786)
Depreciation Expense 403TP 2 (728,778)SG 6.3947%.(46,603)
Depreciation Expense 403TP 2 (663,275)SG 6.3947%(42,415)
Depreciation Expense 403364 2 1,547,669 CA Situs
Depreciation Expense 403364 2 (313,647)10 Situs (313,647)
Depreciation Expense 403364 2 (43,700)OR Situs
Depreciation Expense 40336 2 (5,343)UT Situs
Deprecation Expense 403364 2 588,475 WA Situs
Depreciation Expense 403364 2 159,929 WYE Situs
Depreciation Expense 403364 2 144,753 WY Situs.Depreciation Expense 403GP 2 (595)SE 6.5865%(39)
Deprecation Expense 403GP 2 (371,128)SG 6,3947%(23,733)
Depreciation Expense 403GP 2 (14,955)SSGCH 5,8334%(872)
Depreciation Expense 403GP 2 (515)SSGCT 7.3735%(38)
Depreation Expense 403GP 2 (881,433)SO 5.9531%(52,472)
Depreciation Expense 403GP 2 (69,522)CN 4.0638%(2,825)
Depreciation Expense 403GP 2 2,059 CA Situs
Depreciation Expense 403GP 2 (89,186)10 Situs (89,186)
Depreciation Expense 403GP 2 (525,353)OR Situs
Depreciation Expense 403GP 2 (278,979)UT Situs
Depreciation Expense 403GP 2 (6,404)WA Situs
Depreciation Expense 403GP 2 95,384 WYE Situs
Depreciation Expense 403GP 2 28,099 WY Situs
Depreciation Expense 403GP 2 (35,984)SG 6.3947%(2,301)
Depreciation Expense 403GP 2 (69,438)SG 6.3947%(4,440)
(53,797,950)(3,907,535)6,5.1
Schedule M Additions SCHMAT 2 (53,797,950)SCHMDEXP 5,9222%(3,186,023)6,5.1
Deferred Income Tax Expense 41010 2 20,416,860 DITEXP 4,2385%865,367 6.5,1
Deferred Income Tax Balance 282 2 (10,208,430)DITBAL 6,5593%(669,603)6.5,1
Description of Adjustment:
This adjustment normalizes CY 2007 depreciation expense to reflect the impact of the new depreciation rates which were effctive
January 1, 2008 in Docket No, PAC-E-07-14.
,
Rocky Mountain Power PAGE 6.5.Idaho Results of Operations December 2007
New Depr Rates Accum Depr
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Accumulated Depreciation:
Accumulated Depreciation Balance 108SP 2 8,179,557 SG 6.3947%523,061
Accumulated Depreciation Balance 108SP 2 1,685,489 SSGCH 5,8334%98,322
Accumulated Depreciation Balance 108SP 2 6,873,567 SG 6,3947%439,547
Accumulated Depreciation Balance 108SP 2 6,856,164 SG 6,3947%438,434
Accumulated Depreciation Balance 108HP 2 360,417 SG-P 6,3947%23,048
Accumulated Depreciation Balance 108HP 2 (83,937)SG.U 6,3947%(5,368)
Accumulated Depreciation Balance 108HP 2 (41,792)SG-P 6,3947%(2,673)
Accumulated Depreciation Balance 108HP 2 493,817 SG-U 6.3947%31,578
Accmulated Depreciation Balance 1080P 2 919,540 SG 6,3947%58,802
Accumulated Depreciation Balance 1080P 2 286,255 SSGCT 7,3735%21,107
Accumulated Depreciation Balance 1080P 2 (43,336)SG 6.3947%(2,771)
Accumulated Depreciation Balance 108TP 2 647,300 SG 6,3947%41,393
Accumulated Depreciation Balance 108TP 2 364,389 SG 6.3947%23,302
Accumulated Depreciation Balance 108TP 2 331,638 SG 6.3947%21,207
Accumulated Depreciation Balance 108364 2 (773,834)CA Situs
Accumulated Depreciation Balance 108364 2 156,824 ID Situs 156,824
Accmulated Depreciation Balance 108364 2 21,850 OR Situs
Accmulated Depreciation Balance 108364 2 2,672 UT Situs
Accumulated Depreciation Balance 108364 2 (294,238)WA Situs
Accumulated Depreciation Balance 108364 2 (79,96)WYE Situs
Accmulated Depreciation Balance 108364 2 (72,377)WY Situs.Accumulated Depreciation Balance 108GP 2 298 SE 6,5865%20
Accumulated Depreciation Balance 108GP 2 185,564 SG 6.3947%11,866
Accumulated Depreciation Balance 108GP 2 7,478 SSGCH 5,8334%436
Accumulated Depreciation Balance 108GP 2 258 SSGCT 7.3735%19
Accumulated Depreciation Balance 108GP 2 440,716 SO 5.9531%26,236
Accmulated Depreciation Balance 108GP 2 34,761 CN 4,0638%1,413
Accumulated Depreciation Balance 108GP 2 (1,030)CA Situs
Accumulated Depreciation Balance 108GP 2 44,593 10 Situs 44,593
Accumulated Depreciation Balance 108GP 2 262,677 OR Situs
Accumulated Depreciation Balance 108GP 2 139,490 UT Situs
Accumulated Depreciation Balance 108GP 2 3,202 WA Situs
Accumulated Depreciation Balance 108GP 2 (47,692)WYE Situs
Accumulated Depreciation Balance 108GP 2 (14,050)WY Situs
Accmulated Depreciation Balance 108GP 2 17,992 SG 6,3947%1,151
Accmulated Depreciation Balance 108GP 2 34,719 SG 6,3947%2,220
26,898,975 1,953,768 6.5,1
Description of Adjustment:
This adjusts depreciation reserve to reflect the impact of the new depreciation rates which were effective January 1, 2008 in Docket
No. PAC-E-07-14.
,
.
.
.
Rocky Mountain Power
Result of Operations. Dec 2007
New Depreciation Rates
Function
DSTP
DSTP
DSTP
DSTP
DSTP
DSTP
DSTP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
GNLP
HYOP
HYOP
HYOP
HYOP
OTHP
OTHP
OTHP
STMP
STMP
STMP
STMP
TRNP
TRNP
TRNP
Factor
CA
10
OR
UT
WA
WYP
WYU
CA
CN
DGP
OGU
10
OR
SE'
SG
SO
SSGCH
SSGCT
UT
WA
WYP
WYU
DGP
OGU
SG-P
SG-U
OGU
SG
SSGCT
DGP
OGU
SG
SSGCH
DGP
OGU
SG
SCHMAT SCHMOEXF
41010 OITEXP282 OITBA
CY2007DEPE
5,735,838
6,371,036
43,733,138
49,765,782
10,504,848
10,864,501
2,089,952
247,225
1,364,927
469,209
807,216
866,780
4,387,151
37,603
4,911,245
11,641,227
170,708
16,958
3,989,429
1,364,236
1,716,773
348,623
4,979,312
1,187,400
5,276,568
1,477,963
39,783
29,280,267
3,161,554
37,507,935
40,335,873
60,606,591
9,113,517
12,270,765
13,361,646
31,738,237
417,781,814
2008 Rate Prior Rate Rate % Change DEPE Adjustment Adjusted DEPE3,796% 2.990% 26.982% 1,547,669 7,283,5062.569% 2,702% -4,923% (313,647) 6,057,3892.867% 2.870% -0.100% (43,700) 43,689,4382,513% 2,513% -0,011% (5,343) 49,760,4393.125% 2.959% 5.602% 588,475 11,093,3232.823% 2.782% 1.472% 159,929 11,024,4303,061% 2.863% 6.926% 144,753 2,234,7062.323% 2,304% 0.833% 2,059 249,2846,648% 6.999% -5.020% (69,522) 1,315,4053.184% 4.099% -7,669% (35,984) 433,2253,483% 3.811% -8.602% (69,438) 731,778
2.421% 2.699% -10.289% (89,186) 777,5942.819% 3.203% -11.975% (525,353) 3,861,7973,464% 3,520% -1.583% (595) 37,0083,256% 3,522% -7,557% (371,128) 4,540,1177,074% 7,446% -4.996% (881,433) 16,759,7943,549% 3,889% -8.761% (14,955) 155,753
4,281% 4.415% -3,037% (515) 16,4432.302% 2.475% -8.993% (278,979) 3,710,4503.495% 3,511% -0.463% (6,404) 1,377,8323.869% 3.666% 5.556% 95,384 1,812,1572.987% 2.765% 8.060% 28,099 376,7221.727% 2.155% -19,835% (987,633) 3,991,6792,245% 2.097% 7,039% 83,585 1,270,9842.200% 2,548% -13.661% (720,834) 4,555,7342.774% 2.491% 11.358% 167,874 1,645,83710.241% 3,222% 217.863% 86,672 126,4542.634% 2.810% -8.281% (1,839,081) 27,441,1863.320% 4.054% -18.109% (572,511) 2,589,0441.957% 3.089% -36,651% (13,747,134) 23,760,8011.987% 3.010% -33.995% (13,712,328) 26,623,5452,353% 3,223% -26,992% (16,359,113) 44,247,4781.511% 2.397% -36,989% (3,370,978) 5,742,5391.929% 2.051% -5.939% (728,778) 11,541,9871.898% 1.997% -4,96% (663,275) 12,698,3702.063% 2.151% -4,079% (1,294,599) 30,443,637
(53,797,950) 363,983,864
Refer Page 6.4
BeEnd Average
(53,797,950) Refer Page 6.4
20,416,860 Refer Page 6.4
(10,208,430) Refer Page 6,4
6.5,1
Accum. Depreciation
(773,834)
156,824
21,850
2,672
(294,238)
(79,964)
(72,377)
(1,030)
34,761
17,992
34,719
44,593
262,677
298
185,56
44,716
7,478
258
139,490
3,202
(47,692)
(14,050)
493,817
(41,792)
360,417
(83,937)
(43,336)
919,540
286,255
6,73567
6,856,164
8,179,557
1,685,489
364,389
331,638
647,300
26,898,975
Refer Page 6.5
IDA REVSED PROTOC Pag 7.0 Totl
Tax ~stits (Tab 71
TOTAL
7.1 7.2 7.3 7.4 7.5 0 0.Prrt Tax Ren Ene IDSi.teTax
Tota Noralizd Intst Tru Up Exnse TaxCrlt seten 10 Slate ITC 0 0
1 Op Reves:
2 Ge BusiSl Revenus
3 Interir1ta
4 SpeciS...
5 Oter Opng Revenues
6 Tot Opng Revnus
7
6 Op Exse"9 Stem Pro10 Nuc Pr11 Hy Pro12 Ol Po Supp
13 TralI14 Dl15 Cuat Ac16 Cuto Sei & inf17 $a
18 Adtie & Genel
19 Tot O&M Exs20 De21 Am
22 Taxes Ot Th inc 630,882 63,88
23 In Tii Fed (2,745,1751 (1,04,581 (210,7841 (1,493,801 1'
24 St (224,4331 (141,398)(28,8421 (54,393)0
25 De In T_6,04 6,042
26 Inest Tax Cre Ad.
27 Mis Revue & Exnl
26 Tot Opting Ex:(2,332,885)(1,181,983)391,456 (1,548,200)6,042
29
30 Op Rev For Ret 2,332,68 1,181,98 (391,456)1,54,200 (6,042)
31
32 RItBa..:33 EIe Plan In Sei
34 Pl Held fo Fut Use35 Mis De Debi.38 Ele Pl Ac Ad
37 Nuc Fue
38 Prtl
38 Fue St
40 MI & Supps41 Wo Ca
42 We.-ti Lo",
43 Mie Rite Base
44 Tot EIe P111
45
48 Des:47 Ac Pr ForDe
48 Ac Pr For Am
49 Ac De In Tax 10,569 10,569
50 Unamed ITC (62,6331 (62,6331
51 Cus Al For Co52 Cutor Se Deil53 Milleol Des
54
55 Tota De (52,08)10,569 (62,63)
58
57 Tot Rite Bas:(52,08)10,589 (62,63)
58
59
60 Estimatad ROE ii 0.95%0.48%-4.161%0.63%-4.003%0.002%0.00 0.00
61
62
63
84 TAX CAULATIO:
6588 Opting Revnu (63,8621 (63,882)
87 Ot Dens
68 Int.t (AFUOC)
69 Intrest 3,114,498 3,114,498
70 SCle "M" Aditi71 Schle "M DeI
72 inc Be Tax (3,745,3801 (3,114,498)(63,8621
73.74 S_lnc T_(224,433)(141,398)(28,8421 (54,3931
75
78 Tax In (3,520,947)(2,973,1001 (602,240)54,393
n
78 Fedra inc Tax. Ciitad (1,232,3311 (1,04,58)(210,784)19,03
78 Adtits to Calclated Tax:
60 Wyng Win Tax Credit (1,512,84)(1,512,841
81 Fed In Taxs (2,745,175)(1,04,585)(210,784)(1,493,801
Rocky Mountain Power PAGE 7.1
Idaho Results of Operations December 2007
Interest True Up.TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Other Interest Expense - Type 1 427 1 1,222,065 10 Situs 1,222,065 Below
Other Interest Expense - Type 2 427 2 1,000,835 10 Situs 1,00,835 Below
Other Interest Expense - Type 3 427 3 891,599 10 Situs 891,599 Below
3,114,498 3,114,498 2.18
Adjustment Detail:
Type 1
Jurisdiction Specific Adjusted Rate Base 497,157,066 1.0
Weighted Cost of Debt:3.132%2.1
Trued-up Interest Expense 15,573,346 1,0
Actual Interest Expense 14,351,281 2,18
Total Interest True-up Adjustment 1,222,065 1.0
Type 2
Jurisdiction Specific Adjusted Rate Base 529,107,298 1,0
Weighted Cost of Debt:3,132%2.1
Trued-up Interest Expense 16,574,180 1.0
Type 1 Interest Expense 15,573,346 1,0
Total Interest True-up Adjustment 1,000,835 1.0
.Type 3
Jurisdiction Specific Adjusted Rate Base 557,570,329 2.2
Weighted Cost of Debt:3,132%2,1
Trued-up Interest Expense 17,465,179 2.18
Typ 2 Interest Expense 16,574,180 1,0
Total Interest True-up Adjustment 891,599 1,0
Description of Adjustment:
This adjustment synchronizes interest expense with the jurisdictional allocated rate base by multiplying the rate base by the
Company's weighted cost of debt.
.
Rocky Mountain Power PAGE 7.2.Idaho Results of Operations December 2007
Propert Tax Expense
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Taxes Oter Than Income 408 3 10,597,574 GPS 5,9531%630,882 7,2.1
.
.
Description of Adjustment:
This adjustment normalizes the difference between actual accrued propert tax expense and forecasted propert tax expense
resulting from estimated capital additions.
-
,
,
Rocky Mountain Power
Semi-Annual Report - December 2007
Property Tax Adjustment Summary
7.2.1
FERC Account
408.15
GIL Account
579000
Co. Code
1000
Amount
69,102,426
Total Accrued Propert Tax - 12 Months End. December 2007
. Total Estimated Property Tax Expense - 12 Months End. Dec. 2008
Difference (To Page 7.2)
Total Ref.
69,102,426 B5
69,102,426
79,700,000
10,597,574
Rocky Mountain Power
PAGE 7,3.Idaho Results of Operations December 2007
Renewable Energy Tax Credit
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
FED Renewable Energy Tax Credit 40910 1 (2,068,461 )SG 6.3947%(132,273)
FED Renewable Energy Tax Credit 40910 2 (6,154,337)SG 6.3947%(393,554)
FED Renewable Energy Tax Credit 40910 3 (15,434,830)SG 6,3947%(987,017)
(23,657,628)(1,512,844)7.3.1
UT Renewable Energy Systems Tax Credit 40911 3 (308,545)SG 6.3947%(19,731)7,3,1
OR Business Energy Tax Credit 40911 3 (542,047)SG 6.3947%(34,663)7.3.1
(24,508,221 )(1,567,237)
.
~
Description of Adjustment:
This adjustment normalizes federall state renewable energy income tax credits and state investment tax credits the Company is
entitled to take as a result of placing qualified generating plants into service. The federal renewable energy tax credit is based on
the generation of the plant, and the credit can be taken for ten years on qualifying propert. The Utah State renewable energy tax
credit is based on the generation of the plant, and the credit can be taken for four years on qualifying propert. The Oregon BETC
credit is based on investment of plant, and the credit is taken over a 5 year period on qualifying propert.
.
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Rocky Mountain Power
PAGE 7.4.Idaho Results of Operations December 2007
10 State Tax Settlement
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Income Tax Expense 41010 1 6,042 ID Situs 6,042 7,4.1
Adjustment to Rate Base:
Accum Deferred Income Tax Balance 190 1 10,569 ID Situs 10,569 7.4,1
.
.
Description of Adjustment:
In FY2003, PacifiCorp made state income tax settlement payments totaling $634,571. Idaho's portion of these costs are based on an
average of Idaho's historicallBT factor (1994 to 1998) and amortized over a 5 year period. This adjustment adds Idaho's portion of
the settlement balance along with the amortization expense to the results of operations.
.7.4.1
PacifiCorp
Semi-Annual Report - December 2007
Idaho State Tax Settlement Amortization
Tax Payment 352,379
Interest Payment 310,145
Tax Refund (27,953)
Total State Tax Amount:634,571
ID Avg. IBT:4.760%From 7.4.2
Idaho Portion of State RAR Payments 30,206 To Below
ID
Amortization Rollng 12 Average ID Ending
Period Amount Month Exp.Balance Balance To Page.Mar-04 30,206
Sep-04 3,021 27,185
Mar-05 3,021 27,185 24,164
Sep-05 3,021 24,164 21,143
Dec-05 1,510 21,899 19,633
Mar-06 1,511 21,143 18,122
Jun-06 1,511 18,877 16,611
Sep-06 1,511 18,122 15,100
Dec-06 1,510 6,043 16,612 13,590
Jun-07 3,021 6,042 13,590 10,569
Dec-07 3,021 6,042 10,569 7,548 7.4
Jun-08 3,021 6,042 7,548 4,527
Dec-08 3,021 6,042 4,527 1,506
Mar-09 1,506 2,264
Jun-09 1,506 753
,
.7.4.2
PacifiCorp
Semi-Annual Report - December 2007
Idaho State Tax Settlement Amortization
Idaho Historical IBT Factors
Year
1994
1995
1996
1997
1998
IBT Factor (lD)
4.800%
4.100%
3.700%
4.600%
6.600%
Avg.IBT 4.760% To Page 7.4.1
.
.
Rocky Mountain Power PAGE 7,5.Idaho Results of Operations December 2007
10 State ITC
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Idaho -ITC 255 1 (2,389,971 )1ST 2,6539%(63,427)7,5,1
.
.
Description of Adjustment:
This adjustment normalizes Idaho State investment tax credit the Company has taken as a result of placing propert into service. The
tax credit is based on the plant placed in service, and the credit is usually utilzed in a subsequent penod depending on the availabilty
of Idaho state taxable income. Since PacifiCorp is a 46(f)(1) Company, the ITC unamortized balance is what is reflected in results of
operations as a rate base reduction.
.7.5.1
PacifiCorp
Semi-Annual Report - December 2007
Idaho - ITC
Description
Beginning Balance
Ending Balance
Amount To Page
(2,350,201)
(2,429,740)
(2,389,971) 7.5
.
.
IDAHO REVISED PROTOCOl
Pag 8.0 Tot
Mis RlI Ba.. Adj (Tab 8)
TOTAL
8.1 8.2 8.3 8.4 8.5 8.6.Env Cusom
Upe Cash Tra Min Ret Ji Br Min Seltmet Advans for Pro Fai Maj
Tota Norad Wo Cap Ba..RateBa..(PERCO)Adj COIlN Pla Add
1 Opng Rev.:2 Gø BU8 Revs3 Intpa
4 Spsl Sa15 Ot Op Rev_
6 TotOpe Revl1
7
""Ä_$
8 Op Ei:ej)
9 Stem Pro10 Nu.- Pro11 Hy Pro (10,049)
12 Ot Pow Sup13 Tiw14 Dl15 CUI Accin
16 Custom se & Inf17 Sl18 Adm & Ge
19 Tot O&M Ei.(10,049120 De (35,187)21 Amo 104,20
22 Taxs Ot Th Inc23 Inc T_: Fed (1,179,087)
----~-- "_. -------(1,208,063)
24 St (160,218)(164,156)
25 De Inc Tax..92,537 9809
26 Inest Tax Cre Adj.27 Mi Rev & Exns 1,177
28 Tot Op Exn...:(35,624)(390,129)
29
30 Op Rev For Ret:351624 390,129
31
32 Rate Base:
33 EIe Plan In SeM 67,316,927 418,987 11,671,752 55,977,443
34 Pl He lo Fut Un (45,401).35 Mis De De 182,54
36 Ele Pla Acq Adj
37 Nuc Fue36 Pre
39 Fue Sto 1,05,514
40 Mstersl & 5u.41 Wo Cap (54,0101 798,79842 we Lo
43 Mis Rate Base
44 Tot EIe Pl 67,557,575 798,798 418,987 11,671,752 55,977,443
45
46 De:47 Acc Pi For De 253,40
46 Acc PlO For Am 89,702
49 Acc De Inc Tax (89,775)(759,92)
50 Unaed ITC
51 CUlto Adv For Con (239,120)(2,120)
52 CUltom se DepoRs53 Mi De (95,997)(95,997)
54
55 Tota De:(1,748,785)(958,997)(239,120)(759,922)
56
57 Totl Ret Bas:65,80,789 798,798 418,987 11,871,752 (95,997)(239,120)55,217,522
58
59
60 Estted ROE inpa .1.36%-0.02 -0.011%-0.293%0.025%0.00%.1.131%
61
82
63
64 TAX CALCULATION:
8566 Opeti R8Y (60,145)67 Ot Deio
66 Intarst (AFUOC)
69 Int70 Schle "M Add 1,878,109 1,708,351.71 Schle "M" De 5,347,00 5,324,118
72 Inc Be Tax (3,529,038)(3,615,785)
7374 Stl in T_(160,218)(164,156)
7576 Tax Inc (3,36,820)(3,451,60)
77
78 Fedral inc Tax.(1,179,087)(1,20,06)
IDAHO REVISED PROTOCOl
Pag 8.0.1 Tot
Mi Rat Ba Adjnts (Tal
TOTAL.8.7 8.8 8.9 8.10 8.11 8.12 0
Misnes Poal Hy Amrin For Up Beav Cov Hy
Rate Base Remval Hy Remval Hy Sal Remal FERC 105 (PHFU) 0
1 Ope Revs:
2 Ge Bus Revenes3 Inteipartntal4 Spe Sals5 Ot Ope Revs
8 Tot Opera Reves
7
8 Opeing Exnss:9 Ste Pro10 Nuc Pro11 Hy Pro (4,26)(215)(5,531)(39)
12 Ot Pow Supp
13 Tnisi14 Di
15 Custom Accti18 Cusom se & Inf
17 Sal18 Admlntn & Ge
19 Tot O&M Exs (4,26)(215)(5,531)(39)
20 Deti (13,99)(17,597)(3,58)(12)21 Ai 104,205
22 T_ Ot Th inc23 Inc Tax.: Fød 20,357 5,951 2,651 17
24 SlIe 2,768 80 36 2
25 De inc Tax",(55,54)
26 Invest Tax Crø Ad.
27 Mis Reven & Exse 1,177
28 Tot Optin Exs:53,513 (11,052)(4,923)(32)
29
30 Op Rev For Ret:(53,513)11,052 4,92 32
31
32 Rat Base:
33 EIec Planlln Sei (58,812)(46,798)(107,208)(7,43).34 Pl Hel fo Fut Use
(458,401)
35 Mi Oaen De 182,54
36 Ele Pl Acq Adj
37 Nucar Fuel
38 Prepants
39 Fue Stoc 1,05,514
40 MlI & Su41 Wor Cap (1,33,80)42 Weaio Loa
43 MI Rats Bas
44 ToIaI EIe Plan (282,292)(407,267)(46,798)(107,208)(7,438)(45,401)
45
46 Dads:
47 Acc PlO For De 210,66 46,372 53,849 (57,482)
48 Acc PlO For Am 74,918 14,785
49 Acc Oa Inc Tax (134,213)36
50 Unamo ITC
51 Custo AdV For Conll52 Cust se DaRs53 Mls Das
54
55 ToIaI De:151,369 61,157 54,209 (57,482)
68
57 Tota Rats Base:(282,292)(255,897)14,359 (52,99)(84,9201 (45,401)
58
5860 Ested ROE Im 0.007%-0.015%0.00%0.00%0.00%0.012%0.00
61
82
63
84 TAX CALCULATION:
65
68 Openg Reven (85,94)17,812 7,93 51
67 Ot De
68 Int_st (AFUDCI
69 Interl70 Set"M" Addit 169,757,71 SCIe"M Ded 22,88
72 in Be Tax 60,928 17,812 7,935 51
73
74 Sils inc Taxes 2,768 80 36 2
7576 Tax inc 58,162 17,00 7,574 49
77
78 Fedlnc Taxes 20,357 5,951 2,651 17
Rocky Mountain Power PAGE 8.1
Idaho Results of Operations December 2007.Update Cash Working Capital
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Cash Working Capital CWC 1 59,070 10 Situs 59,070
Cash Working Capital CWC 2 (4,338)10 Situs (4,338)
Cash Working Capital CWC 3 744,06 10 Situs 744,064
798,796 798,796
Adjustment Detail:
Type1 Type 2 Typ 3
O&M Expense 180,956,032 181,308,362 233,767,680 1,0
Taxes Other Than Income Tax 4,657,065 4,657,065 5,287,947 1.0
Federal Income Tax 3,626,500 2,995,372 3,161,690 1.0
State Income Tax 558,818 526,536 626,275 1.0
Total 189,798,16 189,487,335 242,643,592
Divded by Days in Year 365 365 365
Average Daily Cost of Service 519,996 519,143 665,325
Net Lag Days 5.09 5.09 5.09
Cash Working Capital 2,646,778 2,642,440 3,386,504
Unadjusted Cash Working Capital 2,587,708 2,646,778 2,642,440
Cash Working Capital Adjustment 59,070 (4,338)744,064.
Description of Adjustment:
This adjustment is necessary to true-up the cash working capital for the normalizing adjustments made in this filing. Cash working capital is
calculated by taking total operation and maintenance expense allocated to the jurisdiction (excluding depreciation and amortization) and adding
it's share of allocated taxes, including state and federal income taxes and taxes other than income. This total is divided by the number of days in
the year to determine the Company's adjusted daily cost of service, The daily cost of service is multiplied by net lag days to produce the adjusted
cash working capital balance.
.
Rocky Mountain Power
PAGE 8.2,Idaho Results of Operations December 2007
Trapper Mine Rate Base
TOTAL IDAHO
ACCOUNT~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Other Tangible Property 399 1 6,632,627 SE 6.586%436,856 8.2,1
399 2 (172,795)SE 6.586%(11,381)8.2,1
399 3 (98,495)SE 6.586%(6,487)8.2.1
6,361,337 418,987
Adjustment Detail
December 2006 Balance
December 2007 Balance
Average Balance
6,805,422
6,59,832
6,632,627
Adjustment to Dec. 07 Year End Balance (172,795)
December 2007 Balance
December 2008 Balance
Average Balance
6,459,832
6,262,842
6,361,337
Adjustment to Dec. 07/Dec. 08 Average Balance (98,495)
t
Description of Adjustment:
PacifiCorp owns a 21.40% interest in the Trapper Mine, which provides coal to the Craig generating plant. The normalized coal cost of Trapper
includes all operating and maintenance costs but does not include a return on investment. This adjustment adds the Company's portion of the
Trapper Mine plant investment to rate base. This investment is accounted for on the Company's books in Accunt 123.1 . Investment in
Subsidiary Company. However, Account 123 is not normally a rate base account. This adjustment reflects net plant rather than the actual
balance in Accunt 123 to recognize the depreciation of the investment over time.
,
,Page 8.2.1
PACIFICORP
Trapper Balance Sheet
Inclusion of Trapper Mine Rate Base
DESCRIPTON Dec-06 Dec-07 Dec-08
Inventories 3,482,665 4,244,472 4,700,000 4,472,236
Prepaid Expenses 386,284 475,507 415,000 445,254
Propert, Plant, and Equipment
Lands and Leases 9,531,921 9,531,921 9,531,921 9,531,921
Development Costs 2,834,815 2,834,815 2,834,815 2,834,815
Equipment and Facilities 77,334,007 79,814,423 83,609,524 81,711,974
Total Propert, Plant, and Equipment 89,700,743 92,181,159 - ~5,976~260 94~078,710-
Accumulated Depreciation (73,21 1,829)(76,788,786)(80,530,154)(78,659,470)
Total Property, Plant, and Equipment 16,488,914 15,392,373 15,446,106 15,419,240
Restricted Funds: Self-bonding for Black Lung 534,084 528,323 522,689 525,506
Restricted Funds: Funds deposited with Smith-0 0 0 0
Barey required for new mining permit.,Total Restricted Funds 534,084 528,323 522,689 525,506
Deferred GE Royalty Amount 10,909,091 9,545,455 8,181,823 8,863,639
,
TOTAL RATE BASE 31,801,038 30,186,130 29,265,618 29,725,874
PacifiCorp's Share of Trapper is 21.4%6,805,422 6,459,832 6,262,842 6,361,337 to Page 8.2
Rocky Mountain Power PAGE 8.3.Idaho Results of Operations December 2007
Jim Bridger Mine Rate Base
TOTAL IDAHO
ACCOUNT!m COMPANY FACTOR FACTOR % ALLOCATED BÉ
Adjustment to Expense:
Mining Propert 399 1 127,322,438 SE 6,586%8,386,46 Below
Mining Propert 399 2 37,651,750 SE 6,586%2,479,919 Below
Mining Propert 399 3 12,233,992 SE 6.586%805,787 Below
177,208,180 11,671,752
Adjustment Detail
December 2006 Balance 89,670,687 8.3,1
December 2007 Balance 164,974,188 8,3,1
December 2006-2007 Avg Balance 127,322,438
Decmber 2007 Annualization 37,651,750
December 2007 Balance 164,974,188 8,3,1
Proforma Adjustment 12,233,992.December 2007-2008 Avg Balance 1n,208,180
December 2007 Balance 164,974,188 8,3,1
December 2008 Balance 189,442,172 8.3.1
December 2007-2008 Avg Balance 1n,208,180
Description of Adjustment:
PacifiCorp owns a two-thirds interest in the Bridger Coal Company (BCC), which supplies coal to the Jim Bridger generating plant. The
Company's investment in BCC is recorded on the books of Pacific Minerals, INC (PMI), a wholly-owned subsidiary. Because of this ownership
arrangement, the coal mine investment is not included in Account 101 -Electric Plant in Service. The normalized costs for BCC provide no return
on investment. The return on investment for BCC is removed in the fuels credit which the Company has included as an offset to fuel prices
leaving no return in results. This adjustment is necssary to properly reflect the BCC plant investment in the 12.month period,
.
.PacifiCorp
Semi-Annual Report - December 2007 S.3.1
Bridger Mine Rate Base
(OOO's)
Description Dec-06 PacifiCorp's Ref.Portion
1 Structure, Equipment, Mine Development 66,67%
2 Materials & Supplies 66.67%
4 Pit Inventory 66.67%
5 Prepayments 66.67%
6 Reclamation Liabilty 66,67%
7 Accumulated Depreciation 66,67%
8 Bonus Bid I Lease Pa able 66,67%
TOTAL RATE BASE To 8,3
Description Dec-07 PacifiCorp's RefPortion
1 Structure, Equipment, Mine Development 66,67%
2 Matenals & Supplies 66.67%
4 Pit Inventory 66.67%
5 Prepayments 66,67%
6 Reclamation Liabilty 66.67%
7 Accumulated Depreciation 66.67%
8 Bonus Bid I Lease Pa able 66.67%.TOTAL RATE BASE To 8.3
Description Dec-oS PacifiCorp's PacifiCorp's RefPortionShare
1 Structure, Equipment, Mine Development 385,160 66.67%256,773
2 Matenals & Supplies 11,264 66.67%7,509
4 Pit Inventory 43,408 66.67%28,939
5 Prepayments 791 66.67%527
6 Reclamation Liabilty 66.67%
7 Accumulated Depreciation 66.67%
8 Bonus Bid I Lease Pa able 66.67%
TOTAL RATE BASE To 8,3
.
Rocky Mountain Power PAGE 8,4.Idaho Results of Operations December 2007
Environmental Settlement (PERCO) Adj
TOTAL IDAHO
ACCOUNT~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Unspent Environmental Proceds 25399 (16,109.252)SO 5.953%(958,997)8,4.2
.
Description of Adjustment:
PacifiCorp received an insurance settlement of $38 millon for environmental clean-up projects. These funds were transferred to a subsidiary
celled PacifCorp Environmental Remediation Company (PERCO), This adjustment reduces utilty rate base by the amount of unspent cash
proceeds on regulated project from the insurance settlement.
.
.
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8
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Rocky Mountain Power PAGE 8.5.Idaho Results of Operations December 2007
Customer Advances for Construction
TOTAL IDAHO
ACCOUNT~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment Rate Base:
Customer Advance 252 1 160.506 CN 4.064%6,523
Customer Advance 252 1 (62,170)10 Situs (62,170)
Customer Advance 252 1 38,551 OR Situs
Customer Advance 252 1 2,406,618 UT Situs
Customer Advance 252 1 1,634,898 WYE Situs
Customer Advance 252 1 953,149 WY Situs
Customer Advance 252 1 (2,167,460)WY-AII Situs
Customer Advance 252 1 66,501 NUTIL 0.000%
Customer Advance 252 1 (30,045)CA Situs
Customer Advance 252 1 (131,442)WA Situs
Customer Advance 252 1 (2,869,104)SG 6,395%(183,472)
0 (239,120)8.5.1
t
Description of Adjustment:
Customer advances for construction are booked into account 252. When the entries are recorded they are not booked by jurisdiction to reflect
the proper alloction, This adjustment corrects the allocation of customer advances for construction.
I
~Semi-Annual Report - December 2007
Customer Advances for Construction
Beginning I Ending Average Basis:
Account Booked Allocation252CN (160,506)2521DU (26.046)2520R (651,061)252UT (8,701,806)252WYP (1,634,898)252WYU (953.149)
252WY-AII
252NUTIL
252CA
252WA
252SG
Total
748
(16,120)
(1,771,936)
(13,914,775)
,
I
Correct Allocation
(88,211)
(612,510)
(6,295,188)
(2,167,460)
66,501
(29,298)
(147,562)
(4,641,041 )
(13,914,775)
Page 8.5.1
Adjustment
160,506
(62,170)
38,551
2,406,618
1,634,898
953,149
(2,167,460)
66,501
(30.045)
(131,442)
(2,869,104)
o
~
8.6.1
~""R_."''''
I Addition Summary
Jan07 to DeC07 Plant Adds JanOS to Dec08 Plant Adds Total Plant Adds
Descn tlon Factor Plant Additions Months Included in Ad'Plant Additions Months Included in Ad"Included In Ad"
Steam Producton Plant:
Various SG 60,538,818 6 30,269,409 35,228,463 6 17,614,232 47,883,641
Various SSGCH 5,725,924 6 2,862,962 26.792,881 6 13,396,440 16,259,403
Blundell Bottoming Cyce SG 22,165,654 6 11,082,827 6 11,082,827
Cholla 4 Environmental SSGCH 6 170,848,643 8 113,899,095 113,899,095
Blundll U3 Expansion Development SG 8 9,191,622 6 4,595,811 4,595,811
U4 Clean Air. NOx SG 6 6,895,580 6 3,447,790 3,447,790
Cho Com:Well Field Land & New Wells SSGCH 6 3,414,352 6 1.707.176 1.707,176
Totl Steam Plant 88,430,395 44,215,198 252,371,541 154,660,544 198,875,742
Hydro prouction Plant:Varius SG-P 7,996,952 8 3,998,476 33,457,354 6 16,728,6n 20,727,153
Vàrs SG-U 6 14,551,073 6 7,275,537 7,275,537
Varis SG 6 6
Totl Hydro Plant 7,996,952 3.998,476 48,008,427 24,004,214 28,002,690
--_..._-~-_._.-._-.-.__....._- .
Otr Prouction Plant:
Hermiston: U2 CT Rotor & Comprssor SG 4,041,743 6 2,020,872 6 2,020,872
Mareo II Wind Exnsion (70.2 MW)SG 6 138,796,074 5 57,831,697 57,831,697
Gonoe Hills Wind Projec (94 MW)SG 6 195,719,408 7 114,169,655 114,169,655
Marego Wind Projec (14Q. MW)SG 238,339,163 6 119,169,581 6 119,169,581
Lake Sid Capil Build SG 323,067,334 6 161,533,667 6 161,533,667
Varous SG 14.189,084 6 7.094,542 5,551,818 6 2.n5.909 9.870,451
Total Oter prouction Plant 579,637,324 289,818,662 34,067,300 174,777,261 46,595,923
Transmission Plant:
Varius SG 118.242,450 6 59,121,225 119,408,985 6 59.704,493 118,825,718
r"--'"SG 6 2,872,318 6 1,436,159 1,436,159
.ansmission Plant 118,242,450 59,121,225 122,281,303 61,140,652 120,261 ,817
Dis on Plant:
CaHfomia CA 6 4,465,375 6 2,232,688 2,232,688
Oron OR 7,787,769 6 3,893,885 10,312,861 6 5,156,430 9,050,315
Wasington WA 6 6
Utah UT 27,349,828 6 13,674,914 33.405,714 6 16,702,857 JO,3n.n1
Idaho 10 5,907,426 6 2,953,713 6 2,953,713
Wyming WYE 9,244.772 6 4.622,386 5.785,462 6 2.892,731 7,515,117
Totl Distribution Plant 50,289,796 25,144,898 53,969,412 26,984,706 52,129,604
General Plant:
CaHfoia CA 6 6
Oregon OR 13,401 6 6,701 6 6,701
Washington WA 6 6
Utah UT 184,634 6 92,317 6 92,317
Idaho 10 6 6
Wyming WYE 6 6
General SO 3,627,438 6 1,813,719 8,147,025 6 4,073,513 5,887,232
General SG 859,476 6 429.738 6 429.738
Totl General Plant 4,684,949 2,342,474 8,147,025 4,073,513 6,415,987
Mining Plant:
CoalMlne SE 2,197,236 6 1,098,618 6 1,098,618
Total Mining Plant 2.197,236 1,098,618 1,098,618
Intangible Plant:
Jeeral SO 1,632,839 6 816,419 6 816,419
3enerai SG 6 6
-Iydo Relicnsing SG.p 6 42,427,815 6 21,213,908 21,213,908
Totl Intangible Plant 1,632,839 816,419 42,427,815 21.213,908 22.030,327
rotl Electric Plant In Service 853,111,942 426,555,971 867,272,824 48,854,797 893,410,768
Ref#8.6.3 Ref# 8.6 Ref# 8.6.5 Ref# 8.6
,
8.6.2
t PaclfIorp
Semi Annual Report - Dec 2007
Major Plant Addition Detail- Jan2oo7 to DecD07
Jan07 to Dec07 Plant
Project Description Account Factor In-Service Date Additions
Steam Production
Huntington Plant: GEN RESOURCE DEY. CAl PROJEC'314 SG 2007 14,974,621
Dave Johnston: U2 - TURBINE - GENERATOR MAOR 314 SG 2007 2,387,418
Hunter: 303 FGD Towr Linins 314 SG 2007 3,671,295
Hunter: 303 Turbine HP Nozle Box 314 SG 2007 3,508,25
Hunter: 303 Reheater Replacemets 314 SG 2007 5,000,809
Hunter: 303 Main Contrls System Upgrade 314 SG 2007 8,604,348
Hunter U3 NOX 314 SG 2007 7,886,766
Jim Briger U3 NOX 314 SG 2007 4,996,137
Blundell Bottoming Cycle 314 SG 2007 22,165,654
ChoUa Comm: Well Field Int Water 314 SSGCH 2007 5,725,924
Hunter: 303 Turbne L-D Bucket Replacements 314 SG 2007 2,810,728
Hunter: 303 Bottom As Repairs 314 SG 2007 2,477,562
Jim Bndger: U3 Reheater Replacement 314 SG 2007 4,214,708
Steam Production Total 88,430,395
Hydro Prouction
-._.._~...-
North Umpqua Implementation 332 SG-P 2007 5,607,113
Iron Gate Tunnel 332 SG-P 2007 2,389,839
Hydro Production Total
7,996,952
Other Production
Heriston: U2 CT Rotor & Compressor Rp 344 SG 2007 4,041,743
Currnt Crek. CT1A&B HGP Capitalized Spare Parts 344 SG 2007 9,312,798
Lake Side Capital Build 34 SG 2007 323,067,334
Lake Side. 225 Capitalized Spare Parts 344 SG 2007 4,876,286
Marengo Wind Proec (140.4 MW)344 SG 2007 238,339,163IOter Production Total
579,637,324
Transmission
Redmond Sub Reloction for ODOT 355 SG 2007 2,287,336
Marquam 115kv Lin Relo fo N Macad Dev 355 SG 2007 2,447,961
Bond St Sub Construct New 69-12.5 Sub 355 SG 2007 85,214
Latham Install 230- 5kV 25MVA Sub 355 SG 2007 175,465
Porter Rocwell New 138-12,5kV Sub 355 SG 2007 139,04
70t South #1 New 138-12.5kV 30MVA Sub 355 SG 2007 1,886,125
Cache Valley Add. Brldgerland Sw St Ph 1 355 SG 2007 15,784,698
Summit-Vineyard Transmission Project 355 SG 2007 36,727,723
Camp Willams-Mona 345 kV No 4 Line 355 SG 2007 23,711,958
Summit-Vineyard (Lake Side) Internect 355 SG 2007 9,411,023
Marengo Windfarm-Install Switch Station 355 SG 2007 5,191,958
Craven Crk 230kV Svc Entrp Pd Pioneer 355 SG 2007 3,863,486
Quail Crek Sub Conv to 69kV Inst Tmsfm 355 SG 2007 2,014,721
Blundell Bottoming Cycle 355 SG 2007 1,071,505
Chappel Crk Provide Sve to Jonah Field 355 SG 2007 5,696,239
Marengo Wind Projec (140.4 MW)355 SG 2007 7,747,993
Transmission Total 118,242,450
I
8.6.3
.Jan07 to Dec07 Plant
Project Description Account Factor In-Service Date Additions
Distribution
Redmond Sub Reloction fo ODOT 364 OR 2007 3,069,835
Bond St Sub Construct New 69-12.5 Sub 364 OR 2007 4,717,934
Walnut Grove Build New 138-12.5kV Sub 364 UT 207 3,562,430
Latham Install 230-34 5kV 25WA Sub 364 WYE 2007 6,301,312
Porter Rockwell New 138-12.5kV Sub 364 UT 2007 3,661,783
70th South #1 New 138-12.5kV 30MVA Sub 36 UT 2007 320,737
Cache Valley Add. Brigerand Sw St Ph 1 364 UT 2007 386,941
Summit.Vineyard (Lake Side) Intercnnec 364 UT 2007 91,337
Latham 9H562 Double Eagle 12 5MW.34 5kV 364 WYE 2007 2,943,460
Cinder Butte Instl New 161-12.5 Di5t Sub 364 10 2007 5,907,426
Wasatch Frot Auomate Meter Reading 364 UT 207 13,207,811
Quail Creek Sub Conv to 69kV Inst Tmsfm 364 UT 2007 31,319
BDO/Builif 138-12.5kV Sub & Line 30WA 36 UT 2007 3,750,195
Fifth West Inst 2nd 138-12,5kV Tmsf-Fdr 364 UT 2007 2,337,276
Distribution Total
50,289,796
General
Redmond Sub Reloction for ODOT 394 OR 2007 13,401
Porer Rockwll New 138-12.5kV Sub 394 UT 2007 1,970
Cache Valley Add. Bridgerland Sw St Ph 1 394 UT 2007 182,664
Summit-Vineyard Transmission Projec 394 SG 2007 209,303
Camp Williams-Mona 345 kV No 4 Line 394 SG 2007 3,774
Summit-Vineyard (Lake Side) Intercnnect 394 SG 2007 52,785
Marengo Windrm-Install Switch Station 394 SG 2007 164,521
IP Telephony Projec 394 SO 2007 3,627,438
North Umpqua Implementation 394 SG 2007 8,782
Lake Side Capital Build 394 SG 2007 420,312
General Total 4,684,949
.Mining
IP Telephony Project 399 SE 2007 49,706
DEER CREEK-RILDA CANYON STORAGE FACILITY 399 SE 2007 2,147,530
Mining Total 2,197,236
Intangible
DEER CREEK-RILDA CANYON STORAGE FACILITY 303 SO 2007 1,445,156
Lake Side Capital Build 303 SO 2007 187,683
Intangible Total 1,632,839
853,111,942
Ref#8.6.1
,
8.6.4
,Pacmcorp
Semi Annual Report - Dec 2007
Major Plan( Adition Detail - Jan2008 to Dec2008
JanOS to DecOS Plant
Project Description Account Factor In-Service Date Additions
Steam Production
Choll Com:Well Field Land & New Wells 314 SSGCH De7 3,414,352
Choll Com: 135 Car Rail Siding 314 SSGCH Jan-08 2,021,993
Cholla: CHOLU4 CAl Environmental Projecs 314 SSGCH May-0 170,848,643
Carb Plant: U2 GENERATOR ROTOR REPLACEMENT 314 SG Jun-8 2,319,410
Jim Bndger: U4 SHPP Replace Lower Bends 314 SG Jun-Ø8 2,657,491
Jim Bndger: U4 Excition Control Replacement 314 SG Jun-08 2,654,158
CHOLUO Coal Unloading&Handling 314 SSGCH Jun-8 6,848,967
Carbn Plant: U2 ECONOMIZER REPLACEMENT 314 SG Jun-0 3,042,678
Jim Bner: Rewnd Unit 4 Main Genertor Stator 314 SG Jun-08 3,332,242
Jim Bndger: U4 Reheater Replacement 314 SG Jun-8 8,850,938
Cholla Unit 4: TURBINE COMPONENT REPL,314 SSGCH Jun-Ø8 5,174,067
Cholla 4: Finishing Reheater Replacmen 314 SSGCH Jun-8 3,776,669
CHOLU4 GSU Transformer Rep/acemnt 314 SSGCH Jul-08 2,771,501
Cholla 4: Ecomize Replacement 314 SSGCH Jul-Ø8 3,863,361
Dave Johston: U1 - SSH Pendant Replace 314 SG De08 2,80,525
Dave Johnston: U1 - WW Inlet Header Tube Stub Replaceme 314 SG De8 2,264,649
Cholla Co:BOTTOM ASH Sluice underground 314 SSGCH Dee-8 2,336,323
Dave Johnston: U1 - Turbine/Genrator Insption 314 SG Dec08 3,401,127
Dave Johnston: U2 Turbine-enerator Refurbishment 314 SG Dec08 3,901,245
Jim Bndger: U4 Clean Air - NOx 314 SG Dec-08 6,895,580
Bludell U3 Exnsion Development 314 SG De8 9,191,622
Stem Production Total 252,371,541
Hydro Production
Cutler 2 Runner 332 SG-U Jan-08 4,959,135
Cop 2 Elecrical Overhaul 332 SG-P Jan-Ø8 8,187,687IINU 4.1.1f Soda Sprgs Tailrace Barrier 332 SG-P Jun-Ø8 7,659,248
INU 4.3.28 Fis Crk Intake Screens 332 SG-P Jun-Ø8 3,710,370
INU 14.2 Fish Crek Canal Shutoff & Drai 332 SG-P Jun-08 2,161,519
INU 14.2 CW2 Canal Shutoff & Drain 332 SG-P Oel-Ø8 4,924,163
Cuter 1 Overhaul 332 SG-U De8 9,591,938
ILR 10.2 Swift Land Fund 332 SG-P De8 3,852,199
ILR 10.1 Yale Land Fund 332 SG-P Dec-08 2,962,168
Hydro Production Total 48,008,427
Oter Production
LAE SIDE POWER OUTPUT IMPROVEMENT 34 SG Apr-08 5,551,818
Gonoe Hills Wind Projec (94 MW)344 SG Jun-08 195,719,408
Marengo II Wind Expansion (70.2 MW)34 SG Aug-08 138,796,074
Other Production Total 34,067,300
Transmission
Oakley.Kamas New 46kV Line 355 SG Jan-08 2,872,318
Copc 11230/115 kV trnsformer, 250 MVA 355 SG Mar-08 5,871,271
Craner Flat - Install Vanable Var Device 355 SG Apr-08 13,917,099
McClelland Emigration Tap 1.4 Mi OH Ln McClelland CB 355 SG May-08 2,787,663
Amps Phase Shifter Proje 355 SG Jun-8 3,807,948
Line 1 Converson Projec, Convert Line 1 to 115 kV 355 SG Jun-08 15,716,954
Chappel Crk Provide Svc to Jonah Field 355 SG Jun-8 11,928,155
Mona 200 MVA capacitor 355 SG Jul-Ø8 2,106,662
Transmission Relay Repl Zone 3 Setting 355 SG Aug8 2,416,790
Seven Mile Hill Wind geeration 355 SG Sep-08 4,533,633
Shute Crek To Mona System Upgrade 355 SG Sep-08 2,731,008
Glenroc wind generation 355 SG Oel-08 8,232,639
Wine Country Substation: New 230-115 kV Substation 355 SG Oel-08 6,512,379
Upper Gren River Basin projec 355 SG Oc-08 12,817,194
Copc II Sub Repl Existing 115-9kV Tmsfmr 355 SG Dec-08 4,700,030
Chappel Crk 230KV Ciniarex Energy Co 20 MW Service 355 SG Dec08 11,411,417
Logan Canyon-Nibley - rebuild 7 miles for 138 kV DCkt 355 SG Dec08 7,016,622
Jim Bndger: Repl RAS A&B Scheme Project 355 SG De8 2,901,523ITransmission Total 122,281,303
8.6.5
.Jan08 to Dec08 Plant
Project Description Account Factor In-Service Date Additions
Distribution
Campbell Sub Incrase Capacity 364 OR Feb-08 2,977,743
Cozdale Build New 138-12.5kV Sub 364 UT Ap.08 4,157,050
BOO/Build 138-12.5kV Sub & Line 30MVA 364 UT Apr-08 2,180,823
Elk Hom Instl 115-12.5kV Two Fdr Sub 364 WYE May-08 5,785,462
Yew Ave 115-12.5 kV sub and tap line 364 OR May-08 7,335,117
Herrman. Install New Sub & Transmission frm Oquirr 364 UT May-08 11,962,424
Commerce Substation. New 138 kV Sub 364 UT May-08 5,358,425
Northeast - Inst 2nd 46-12 kV XFMR & Conv 4kV to 12 kV 364 UT May-08 3,383,056
Wee Substation - Convert to 115 kV and Incrase Capacity 364 CA Jun-08 4,465,375
Snydille -Install 2nd 138-12.5 kV 30 MVA 364 UT Oc-08 4,076,584
System Reinforcment - Substation Propert Acuisition - UT 364 UT oe-08 2,287,352
Distribution Total 53,969,412
General
Sperum 394 SO Jun-8 3,128,397
Customer IVR Replacement & AAR Upgrade 394 SO Jun-OS 5,018,628
General Total 8,147,025
Intangible
LI Rogue Relicensing-Hydro South 302 SG-P Jun-08 6,613,013
Yale Relicensing Superior 302 SG-P Sep-8 14,280,091
Merwin Relicensing Superior 302 SG-P Sep-OS 11,052,169
Swift Relicensing Superior 302 SG.p Sep-08 10,482,542
Intangible Total 42,427,815
l'867,272,824
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Rocky Mountain Power PAGE 8.7
Idaho Results of Operations December 2007.Miscellaneous Rate Base
TOTAL IDAHO
ACCOUNT~COMPANY FACTOR FACTOR % ALLOCATEQ REF#
Adjustment to Rate Base:
1) Cash OWC131 1 (22,999,471 )SNP 5.821%(1,338,806)8,7.1
2) Fuel Stock 151 3 13,668,410 SE 6.586%900,265 8.7,1
2) Fuel Stock 151 3 2,586,196 SSECH 6,042%156,249 8,7.1
.
Description of Adjustment:
1 . In order to avoid earning a return by including cash in rate base, the Company is removing the balance from rate base via this adjustment.
2 _ The cost of the Company's coal plant fuel stock is increasing due to increases in the cost of coal and the number of tons stored at each
site, This adjustment reflects the increase in the fuel stock balance into results.
.
8.7.1
.Rocky Mountain Power
Semi Annual Report - December 2007
Removal of Cash Balance
Account
131
Factor
SNP
Jan 2007 to Dec 2007
12 Mo. Avg Balance Ref
22,999,471 To 8.7
.
.
8.7,2
. Rocky Mountain Power
Semi Annual Report - December 2007
Coal Fuel Stock Balances
.
Rocky Mountain Power PAGE 8,8
Idaho Results of Operations December 2007.Powerdale Hydro Removal
TOTAL IDAHO
ACCOUNTIm COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Electric Plant In Service
Intangible Plant 302 1 (2.239,229)SG-P 6.395%(143.193)
Hydro Plant 332 1 (6,984,158)SG-P 6,395%(446,619)
(9,223,387)(589,812)8,8,1
Accumulated Reserve
Amortization Reserve 1111P 1,171,549 SG-P 6,395%74,918
Hydro Depreciation Reserve 108HP 3,294,339 SG-P 6,395%210,66
4,465,887 285,582 8.8.1
Adjustment to Expense:
Intangible Plant Amortization 401P (248,803)SG-P 6.395%(15,910)
Hydro Plant Depreciation 403HP (218,893)SG-P 6,395%(13,998)
(467,696)(29,908)8.8.2
Hydro Operation and Maintenance 539 (66,672)SG-P 6.395%(4,263)8.8.2
Adjustment to Unrecovered Plant:
Unrecovered Plant Amortization 407 1 (780,128)SG 6.395%(49,887)8,8.3
Unrecovered Plant Amortization 404IP 3 2,654,642 SG-P 6.395%1 ()9,757 8.8.3
Powerdale Unrecovered Plant Reg Asset 182M 3 2,654,642 SG-P 6,395%169,757 8.8,3
.SChedule M Addition SCHMAT 3 2,654,642 SG 6.395%169,757
Deferred Income Tax Expense 41110 3 (1,007,463)SG 6,395%(64,425)
Deferred Income Tax Balance 283 3 (2,014,926)SG 6,395%(128,849)
Decommissioning Reg Asset:
Decommissioning Amortization 4041P 3 3,824 SG.p 6,395%245 8,8.4
Demmissioning Reg Asset 182M 3 199,973 SG-P 6.395%12.788 8.8.4
Schedule M Deducton SCHMDT 3 357,886 SG 6.395%22,866
Deferred Income Tax Expense 41010 3 138,723 SG 6.395%8,871
Deferred Income Tax Balance 283 3 (83,873)SG 6.395%(5,363)
Description of Adjustment:
This adjustment reflects the treatment approved by the Commission to account for the decommissioning of the Powerdale hydroelectric
plant due to damage caused by a flood in November 2006. Dunng 2007, the net book value (including an offset for insurance proceeds) of
the assets to be retired was transfered to the unrecered plant regulatory asset. In addition, fuure decommissioning costs will be
deferred as they are spent and amortized over ten years, beginning in the subsequent year after they are spent.
.
8,8.1
. PacifiCorp
December 2007 Semi Annual Report
Powerdale Removal
Description Account Factor Dec-06 Dec-07 Avg Balance Ref
Electric Plant in Service
Intangible Plant 302 SG-P 4,478,459 2,239,229
Hydro Plant 330 SG-P 398 199
Hydro Plant 331 SG-P 741,467 370,733
Hydro Plant 332 SG.p 11,645,042 5,822,521
Hydro Plant 333 SG-P 1,093,464 546,732
Hydro Plant 334 SG-P 427,523 213,762
Hydro Plant 335 SG.p 16,288 8,144
Hydro Plant 336 SG.p 44,133 22,067
18,446,774 9,223,387 To 8.8
Accumulated Reserve
Intangible Plant 1111P SG-P (2,343,098)(1,171,549)
Hydro Plant 108HP SG.p (288)(144)
Hydro Plant 108HP SG-P (329,021)(164,511)
Hydro Plant 108HP SG-P (5,661,869)(2,830,934)
Hydro Plant 108HP SG-P (433,743)(216,872)
Hydro Plant 108HP SG-P (139,097)(69,549)
Hydro Plant 108HP SG.p (4,952)(2,476).Hydro Plant 108HP SG-P (19,707)(9,854)
(8,931,775)(4,465,887) To 8.8
.
8,8.2
. PacifiCorp
December 2007 Semi Annual Report
Powercale Removal
12ME
Description Account Factor Dec 2007 Expense Ongoing Expense Expense to Remove Ref
Depreciation Expense
Intangible Plant 4041P SG-P 248,803 0 248,803
Hydro Plant 403HP SG-P 5 0 5
Hydro Plant 403HP SG-P 10,774 0 10,774
Hydro Plant 403HP SG-P 181,341 0 181,341
Hydro Plant 403HP SG.p 19,372 0 19,372
Hydro Plant 403HP SG.p 6,286 0 6,286
Hydro Plant 403HP SG-P 401 0 401
Hydro Plant 403HP SG-P 714 0 714
467,696 467,696 To 8.8
Operation & Maintenance
OPER SUPERV & ENG
HYDRO/OTH REC FAC
MSC HYD PWR GEN EX
MNT DAMS & WTR SYS
ACCESS ELEC EQUIP
MAl NT HYDRO-OTHER
535 SG-P
537 SG-P
539 SG-P
543 SG-P
54 SG-P
545 SG-P 72,000
7,569
10,284
31,048
722
1,592
15,457
66,672 To 8.8
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Rocky Mountain Power PAGE 8.9.Idaho Results of Operations December 2007
American Fork Hydro Removal
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Hydro Plant 332 1 (500,614)SG-U 6.395%(32,013)8.9,1
Intangible Plant 302 1 (231,200)SG-U 6.395%(14,785)8,9,1
Distribution Plant 364 1 (3,410)UT Situs 8.9.1
(735,224)(46,798)
Hydro Plant Accum Depr 108HP 1 725,162 SG-U 6.395%46,372 8,9,1
Intangible Plant Amortization 1111P 1 231,200 SG-U 6.395%14,785 8.9.1
Distribution Plant Accum Depr 108364 1 2,110 UT Situs 8.9,1
958,472 61,157
Adjustment to Expense:
Misc, Hydro Expenses 539 (3,364)SG.U 6.395%(215)8.9,1
Adjustment to Depreciation Expense:
Depreciation - Hydro Plant 403HP 1 (275,182)SG.U 6.395%(17,597)8,9.1
Depreciation - Dist Plant 403364 1 (120)UT Situs 8,9,1
(275,302)(17,597)
.
Description of Adjustment:
The American Fork hydro electric plant was retired as of September 2007. This adjustment removes the American Fork assets from
December 2007 results and also removes the associated expenses - depreciation, O&M, etc.
.
.Rocky Mountain Power Page 8.9.1
Semi-Annual December 2007
American Fork Hydro Removal
Balance Balance Beg/End
Rate Base (Assets Retired)Factor Dec 06 Dec 07 Average
Hydro Plant SG-U 1,001,227 500,614
Intangible Plant SG-U 462,400 231,200
Distribution Plant UT 6,821 3,410
1,470,448 735,224 pg.8.9
Hydro Plant Accum Depr*SG-U (1,450,324)(725,162)
Intangible Plant Amortization SG-U (462,400)(231,200)
Distribution Plant Accum Depr UT (4,219)(2,110)
(1,916,943)(958,472)pg.8.9
O&M
Misc. Hydro Expenses 539 SG-U 3,364 pg.8,9
Depreciation
Depreciation - Hydro Plant 403HP SG-U 275,182.Depreciation - Dist Plant 403364 UT 120
275,302 pg,8.9
*Reclamation balance accrued included in accumulated depreciation reserve.
.
Rocky Mountain Power
PAGE 8.10.Idaho Results of Operations December 2007
Upper Beaver Hydro Sale
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Reseroirs, Dams & Waterways 332 1 (1,285,080)SG-U 6.395%(82,178)8.10,1
Station Equipment 353 1 (342,578)SG 6.395%(21,907)8,10.1
TranspOrtation Equipment 392 1 (48,847)SG 6.395%(3,124)8.10,1
Hydraulic Plant Accum Depr 108HP 1 661,117 SG-U 6.395%42,277 8.10.1
Transmission Plant Accum Depr 108TP 1 155,257 SG 6.395%9,928 8.10.1
General Plant Accum Depr 108GP 1 25,708 SG 6.395%1,64 8.10,1
(834,423)(53,359)
Adjustment to O&M Expense:
MSC HYD PWR GEN EX 539 1 (96,583)SG-U 6.395%(6,176)8.10.1
MAINT OF STRUCTURE 540 1 (90)SG-U 6.395%(6)8,10,1
MNT DAMS & WTR SYS 542 1 (847)SG-U 6.395%(41)8.10,1
MNT DAMS & WTR SYS 543 1 10,824 SG-U 6.395%692 8,10.1
MAINT HYDRO-OTHER 54 1 (1)SG-U 6.395%(0)8.10.1
(86,497)(5,531)
Adjustment to Depreciation Expense:
Hydro Depreciation 403HP (42,557)SG-U 6.395%(2,721)8.10.1
Transmission Deprecation 403TP (8,687)SG 6,395%(556)8,10,1
General Plant Depreciation 403GP (4,739)SG 6.395%(303)8,10.1
(55,982)(3,580).Recognition of Loss
Loss on sale of propert 421 18,398 SG 6.395%1,177 8.10.1
Adjustment to Taxes
Acumulated Deferred Taxes 282 5,626 SG 6.395%360 8,10,1
Descnptlon of Adjustment:
PacifiCorp entered into an agreement to sell the Upper Beaver hydro electnc facilties to Beaver City. The sale closed on September 14,
2007,
This adjustment removes the Upper Beaver assets that were sold as well as removes the associated expenses such as depreciation, O&M,
etc.
.
.PacifiCorp Page 8.10.1
Semi Annual. Dec 2007
Upper Beaver Hydro Facilties Sale
Balance Balance
Rate Base (Assets Retired)12/31/06 12/31/2007 Average
Transportation Equipment 97,694 48,847 pg 8,10
Reservoirs, Dams & Waterways 2,570,160 1,285,080 pg 8,10
Station Equipment 685,155 342,578 pg 8,10
Electric Plant in Service 3,353,009 1,676,505
General Plant Accum Depr (51,417)(25,708)pg 8.10
Hydraulic Plant Accum Depr (1,322,234)(661,117)pg 8.10
Transmission Plant Accum Depr (310,513)(155,257)pg 8,10
Accumulated Depreciation (1,684,163)(842,082)
1,668,846 834,423
Operations & Maintenance
MSC HYD PWR GEN EX 539 96,583
MAINT OF STRUCTURE 540 90
MNT DAMS & WTR SYS 542 647
MNT DAMS & WTR SYS 543 (10,824),MAINT HYDRO-OTHER 544 1
Total Operations & Maintenance 86,497 pg 8.10
Depreciation
Hydro 42,557
Substation 8,687
General Plant 4,739
Depreciation Expense 55,982 pg 8.10
Loss on Sale 18,398 pg 8,10
Balance Average
Accumulated Deferred Taxes 11,252 5,626 pg 8,10
,
Rocky Mountain Power PAGE 8,11.Idaho Results of Operations December 2007
Cove Hydro Removal
TOTAL IDAHO
ACCOUNT~COMPANY FACTOR FACTOR % ALLOCATED BI
Adjustment to Rate Base:
Reservoirs, Dams & Waterways 332 2 (116,320)SG-U 6,395%(7,438)8.11.1
Hydraulic Plant Accm Depr 108HP 2 (898,896)SG-U 6.395%(57,482)8.11,1
(1,015,216)(64,920)
Adjustment to Expense:
Misc. Hydro Expenses 539 2 (609)SG-U 6.395%(39) 8,11.1
Adjustment to Depreciation:
Hydro Depreciation 403HP 2 (195)SG-U 6.395%(12) 8,11,1
.
Descnption of Adjustment:
The Cove hydro electric plant was removed from service in the fall of 2006, Most of the assets were retired and a few were transferred to other
loctions for use as capitalized spare parts, By December 2006, most assets that were going to be retired were, in fact, retired. A few other
assets were not retired until January 2007.
This adjustment removes the Cove assets from CY 2007 results and also removes the associated O&M and depreciation expense.
.
.
.
e
PacifiCorp
Results of Operations December 2007
Cove Hydro Removal
Rate Base (Assets Retired)
Electric Plant in Service
Accumulated Depreciation
O&M
MSC HYD PWR GEN EX
MNT DAMS & WTR SYS
Depreciation
Depreciation Expense
Balance Balance
Dec 06 Dec 07
232,641
1,797,792
2,030,433
539
543
Beg/End
Average
116,320
898,896
1,015,216
Page 8.11.1
pg.8,11
pg.8.11
389
221
609 pg.8.11
195 pg.8.11
Rocky Mountain Power PAGE 8,12.Idaho Results of Operations December 2007
FERC 105 (PHFU)
TOTAL IDAHO
ACCOUNT 1m COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Remove PHFU 105 (6,677,614)SG 6,395%(427,016)
Remove PHFU 105 (476,507)SE 6,586%(31,385)
Remove PHFU 105 (1.375,461)UT Situs
(8.529,582)(458,401)8,12.1
.
~rzt(
fW-~V'd-
Description of Adjustment:
This adjustment removes all Plant Held for Future Use (PHFU) assets from FERC account 105. The Company is making this adjustment in
compliance with Title 16 of Public Utilty Regulation. chapter 5 "Powers and Duties of PUb.IiÍ'Utilties Commission" section 61-5~, ~~&1ì' ~~ .f nJI1I-- it ~r-e ~ /rt .çVt~
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Rocky Mountain Power
RESULTS OF OPERATIONS
Page 9.1
USER SPECIFIC INFORMATION
RECEiVED
IDAHO
DECEMBER 2007
STATE:
PERIOD:
30 AMID: 21
1 D;ß;í.I~'i:f':\ r:J;i
JAM Semi Dec07 Ul1LrTlÉS ""ê UC
Revenue Requirement Department . 0 iSS10N
41231008
4:55:10 PM
FILE:
PREPARED BY:
DATE:
TIME:
TYPE OF RATE BASE:
ALLOCATION METHOD:
Beginning/Ending
ROLLED-IN
FERC JURISDICTION:Separate Jurisdiction
80R 12CP:12 Coincidental Peaks
DEMAD %
ENERGY %
75% Demand
25% Energy
TAX INFORMATION
TAX RATE ASSUMPTIONS:
FEDERAL RATE
STATE EFFECTIVE RATE
TAX GROSS UP FACTOR
FEDERAL/STATE COMBINED RATE
TAX RATE
35,00%
4,54%
1,614
37,95%
CAPITAL STRUCTURE INFORMA nON
CAPITAL
STRUCTURE
EMBEDDED
COST
WEIGHTED
COST
DEBT
PREFERRED
COMMON
50,20%
0.40%
49.40%
100.00%
6.24%
5.41%
10.25%
3.132%
0.022%
5.064%
8.218%
OTHER INFORMATION
ROLLED-IN Page 9.2
Beginning/Ending
RESULTS OF OPERATIONS SUMMARY.UNADJUSTED RESULTS IDAHO
Description of Account Summary:Ref TOTAL OTHER IDAHO ADJUSTMENTS ADJ TOTAL
1 Operating Revenues
2 General Business Revenues 2.3 3,228,941,107 3,04,741,273 184,199,833 18,744,967 200,944,800
3 Interepartental 2.3 °0 0 0 °
4 Speal Sales 2.3 856,864,831 802,583,701 54,281,130 49,541,526 103,822,657
5 Oter Operating Revenues 2.4 156,475,422 149,159,906 7,315,516 1,845,368 9,160,884
8 Total Operating Revenues 2.4 4,242,281,360 3,996,484,880 245.796,480 68,131,861 313,928,341
7
8 Operating Expenses:
9 Steam Proucton 2.5 854,983,104 799,185,610 55,797,494 40,494 55,837,968
10 Nucear Proucton 2.6 °°°°°
11 Hyro Prouction 2.7 34,359,368 32,162,175 2,197,193 70,752 2,267,944
12 Oter Powr Suppl 2.9 1,199,378,442 1,125,713,174 73,665,269 58,890,614 132,555,883
13 Transission 2,10 154,194,872 144,331,053 9,863,819 341,625 10,205,444
14 Distrbun 2.12 221,340,872 210,736,037 10,60,835 94,535 10,699,370
15 Custr Accunting 2,12 95,457,786 91,184,366 4,273,420 62,155 4,335,575
16 Customer Serice & Infor 2.13 46,969,452 43,100,792 3,868,660 (2,049,531)1,819,129
17 Sales 2.13 0 °°°°
18 Administrtie & General 2.14 180,356,471 170,496,997 9,859,474 739,075 10,598,549
19
20 ____IotaLQ&~i:Mes-2.14 2,78I,Q'O,36ll__ _2,61e,91Q,205 . _"'?Q.130, 162_58,189,719 228,319,881
21
22 Dereation 2.16 417,781,814 393,017,301 24,764,513 (1,943,523)22,820,990
23 Amorzation 2,17 64,157,451 60,972,063 3,185,388 262,170 3,447,558
24 Taxes Oter Than Income 2.17 101,472,747 96,808,521 4,66,227 631,660 5,296,086
25 Ince Taxes. Federal 2.20 148,444,598 142,371,127 6,073,469 (1,022,103)5,051,365
26 Ince Taxes. State 2.20 23,999,463 23,032,482 96,981 9,703 976,684
27 Incoe Taxes. Def Net 2.19 79,827,843 76,907,819 2,920,024 1,492,958 4,412,982
28 Investment Tax Creit Adj.2.17 (5,854,860)(5,109,951)(744,909)°(744,909)
29 Mise Revenue & Expense 2.4 (11,343,723)(10,617,311)(726,412)583,834 (162,578)
30.31 Totl Operating Expenses 2,20 3,605,525,699 3,394,292,256 211,233,443 58,184,618 269,418,060
32
33 Opeting Revenue for Retum 636,755,661 602,192,624 34,563,037 9,947,243 44,510,281
34
35 Rate Base:
36 Elecc Plant in Service 2.30 15,787,758,656 14,846,44,228 941,314,428 67,90,196 1,009,218,624
37 Plant Held fo Future Use 2.31 8,529,582 8,071,181 458,401 (458,401)°
38 Mise Deferr Debits 2.33 120,693,483 116,887,611 3,805,872 375,451 4,181,323
39 Elec Plant Acq Adj 2.31 74,565,289 69,797,032 4,768,257 °4,768,257
40 Nucar Fuel 2.31 °°°°°
41 Prepayments 2.32 37,262,181 35,012,163 2,250,018 °2,250,018
42 Fuel Stok 2.32 88,485,802 82,657,717 5,828,085 1,070,604 6,898,689
43 Material & Supplies 2.32 139,617,944 130,923,450 8,694,494 °8,694,494
44 Woring Capital 2.33 82,619,346 78,411,385 4,207,961 (533,489)3,674,472
45 Weatherization Loans 2.31 11,821,982 5,690,076 6,131,90 °6,131,906
46 Miscellaneos Rate Base 2.34 5,994,104 5,529,710 464,394 °464,394
47
48 Totl Elecc Plant 16,357,348,368 15,379,424,552 971,923,816 68,358,360 1,048,282,171
49
50 Rate Base Deductons:
51 Accm Prov For Depr 2.38 (6,053,908,945)(5,678,454,912)(375,454,033)1,208,642 (374,245,391)
52 Accm Prov For Amort 2.39 (391,421,787)(369,726,948)(21,694,838)104,710 (21,590,128)
53 Accm Def Income Taxes 2.35 (1,274,447,966)(1,191,984,410)(82,463,556)(973,262)(83,436,818)
54 Unamortzed ITC 2.35 (11,355,352)(11,301,125)(54,227)(96,296)(150,523)
55 Customer Adv for Const 2.34 (13,914,715)(13,788,896)(145,880)(239,120)(384,999)
56 Custoer Seice Deposits 2.34 °°°°°
57 Mise. Rate Base Deductons 2.34 (76,494,100)(72,047,657)(4,446,444)(3,311,355)(7,757,799)
58
59 Totl Rate Base Deductions (7,821,542,925)(7,337,283,948)(484,258,978)(3,306,680)(487,585,658)
60
61 Total Rate Base 8,535,805,443 8,042,140,604 493,664,839 65,051,680 558,716,519
62
63 Return on Rate Base 7.460%7.001%7.967%
64
65 Retum on Equit 8.716%7.788%9,742%
.=Net Power Costs 940,860,037 62,209,011 65,926,202
100 Basis Points in Equity:
68 Revenue Requirement Impact 67,957,387 3,930,288 4,448,194
69 Rate Base Decrease (530,146,303)(32,536,376)(32,622,801)
ROLLED-IN Page 9.3
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
e70
Sates to Ultimate Customers
71 440 Residential Sales
72 0 S 1,263,790,934 1,214,263,337 49,527,597 7,884,534 57,412,131
73
74 B1 1,263,790,934 1,214.263,337 49,527,597 7,884.534 57,412,131
75
76 442 Comm~al & Indus~al Satesn0 S 1,928,738,024 1,794,308,878 134,429,145 8,659,446 143,088,592
78 P SE
79 PT SG
80
81
82 B1 1,928,738,024 1,794,308,878 134,429,145 8,659,446 143,088,592
83
84 44 Public Street & Highway lighting
85 °S 18,902,690 18,659,599 243,091 200,986 444,On
86 °SO
87 B1 18,902,690 18,659,599 243,091 200,986 44,071
86
89 445 Othr Sales to Public Authority
90 °S 17,509,459'17,509,459
91
92 B1 17,509,459 17,509,459
93
94 448 Interdepartental
95 DPW S
96 GP SO
97 B1
98
99 Total Sates to Ultmate Customers 81 3,228,941,107 3,04,741,273 184,199,833 16,744,967 200,944,800
100
101
102
103 447 Sales fo Resale-Non NPC
104 WSF S 7,616,288 7,616,288.05 7,616,288 7,616,288
106
07 447NPC Sales fo Resale-NPC
108 WSF SG 862,870,229 807,691,912 55,178,318 48,64,339 103,822,657
109 WSF SE (13,621,686)(12,724,499)(897,187)897,187
110 WSF SG
111 849,248,543 794,967,413 54,281,130 49,541,526 103,822.657
112
113 Total Sales tor Rèsale B1 856,864,831 802,583,701 54,281,130 49,541,526 103,822,657
114
115 449 Proision tor Rate Refund
116 WSF S 3 3
117 WSF SG
118
119
120 B1 3 3
121
122 Totl Sales frm Electrcit 81 4,085,805,940 3,847,324,977 238,480,964 66,286,493 304,767,457
123 450 Forited Disconts & Interest
124 CUST S 6,784,670 6,416,032 368,639 368,639
125 CUST SO
126 B1 6,784,670 6,416,032 368.639 368,639
127
128 451 Mise Elecc Revenue
129 CUST S 7,204,337 7,062,014 142,323 142,323
130 GP SG
131 GP SO 10,908 10,258 650 650
132 B1 7.215,245 7,072,272 142,973 142,973
133
134 453 Watr Sales
135 P SG 107,480 100,607 6,873 6,873
136 B1 107,480 100,607 6,873 6,873
137
138 454 Rent of Elecc Propert
139 DPW S 12,809,490 12,473,816 335,675 335,675.40 T SG 5,274,071 4,936,813 337,264 337,264
141 GP SO 677,192 636,816 40,376 40,376
42 B1 18,760,759 18,047,445 713,314 713,314
143
144
ROLLED-IN Page 9.4
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.45
146 456 Otr EIe Revenue
47 DMSC S 28,947,692 28,946,013 1,679 1,679
148 CUST CN
149 OTHSE SE 15,573,968 14,548,195 1,025,774 61,176 1,066,949
150 OTHSO SO 244,061 22,510 14,552 14,552
151 OTHSGR SG 78,841,54 73,799,831 5,041,713 1,784,192 6,825,905
152
153
154 81 123,607,265 117,523,548 6,083,717 1,845,368 7,929,085
155
156 Totl Oter Electric Revenues B1 156,475,419 149,159,903 7,315,516 1,845,368 9,160,884
157
158 Totl Electrc Operating Revenues Bl 4,242,281,360 3,996,484,880 245,796,480 68,131,861 313,928,341
159
180 Summary of Revenues by Factr
161 S 3,292,303,586 3,107,255,438 185,048,148 16,744,967 201,793,115
182 CN
163 SE 1,952,282 1,823,696 128,586 958,363 1,08,949
164 SO 932,162 876,583 55,578 55,578
165 SG 947,093,330 666,529,163 60,584,167 50,428,531 110,992,698
166 DGP
167
168 Total Elec Oprating Revenues -4,242,281,360 3,996,484,880 245,796,480 68,131,861 313,928,341
169 Miscllaneos Revenues
170 41160 Gain on Sale of Utility Plant. CR
171 DPW 5
172 T SG
173 G SO
174 T SG
175 P SG
176 81
177
178 41170 Loss on Sale of Utilty Plant
.::DPW S
T SG
81 81
182
183 4118 Gain fr Emission Allownces
184 P 5
185 P SE (14,663,498)(13,697,692)(965,806)792,529 (17,277)
186 81 (14,663,498)(13,697,692)(965,806)792,529 (173,277
187
188 41181 Gai frm Dispositon of NOX Credits
189 P SE
190 81
191
192 4194 Impact Housing Interest Income
193 P SG
194 81
195
196 421 (Gain) / Loss on Sale of Utilty Plant
197 DPW S (706,221)(706,221)
198 T SG
199 T SG
200 PTD CN
201 PTD SO 4,175,984 3,926,999 248,985 (229,871)19,114
202 P SG (149,988)(140,396)(9,591)1,177 (8,415)
203 81 3,319,775 3,080,382 239,394 (228,695)10,699
204
205 Totl Miscellaneous Revenues (11,343,723)(10,617,311)(726,412)563,834 (162,578)
206 Miscellaneous Expeses
207 4311 Interest on Customer Depsits
208 CUST 5
209 81
210 Total Miscellaneous Expenses
211
212 Net Mise Revenue and Expense 81 (11,343,723)(10,617,311)(726,12)563,834 (162,578)
213.
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ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
214 500 Operatin Supervision & Engineering.15 P SNPPS 20,195,720 18,90,256 1,291,464 122,363 1,413,827
16 P SNPPS 1,310,396 1,226,600 83,796 83,796
217 B2 21,506,117 20,130,856 1,375,260 122,363 1,497,624
218
219 501 Fue Related-Non NPC
220 P SE 12,819,982 11,975,599 84,383 1,144 845,527
221 P SE
222 P SE
223 P SE
224 P SE 1,762,999 1,846,880 116,119 116,119
225 B2 14,582,982 13,622,479 960,503 1,144 961,648
226
227 501NPC Fuel Related-NPC
228 P SE 516,191,536 482,192,770 33,998,767 30,527 34,029,294
229 P SE
230 P SE
231 P SE
232 P SE 50,403,877 47,084,044 3,319,833 3,319,833
233 B2 566,595,413 529,276,814 37,318,600 30,527 37,349,127
234
235 Total Fuel Related 581,178,395 542,899,292 38,279,102 31,671 38,310,773
236
237 502 Steam Expenses
238 P SNPPS 31,714,301 29,686,254 2,028,047 2,028,047-
239 P SNPPS 2,053,090 1,921,800 131,290 131,290
240 B2 33,767,391 31,608,054 2,159,337 2,159,337
241
242 503 Steam Fro O1r Sources-Non.NPC
243 P SE
244 B2
245
246 503NPC Steam From Other Sourcs.NPC
247 P SE 4,845,079 4,525,960 319,119 (113,540)205,579
248 B2 4,845,079 4,525,980 319,119 (113,540)205,579.49
50 505 Elecc Exnses
51 P SNPPS 2,687,282 2,515,437 171,845 171,845
252 P SNPPS 1,320,614 1,236,164 84,450 84,450
253 B2 4,007,896 3,751,601 256,295 256,295
254
255 506 Misc. Steam Expense
256 P SNPPS 40,241,240 37,667,916 2,573,323 2,573,323
257 P SE
258 P SNPPS 1,603,350 1,500,820 102,530 102,530
259 B2 41,844,590 39,168,736 2,675,853 2,675,853
260
261 507 Rents
262 P SNPPS 743,038 695,522 47,515 47,515
263 P SNPPS 116,165 108,737 7,428 7,428
264 82 859,203 804,259 54,944 54,944
265
266 510 Maint Supervision & Engineering
267 P SNPPS 4,413,141 4,130,932 282,209 282,209
268 P SNPPS 1,786,86 1,672,601 114,265 114,265
269 B2 6,200,007 5,803,533 396,474 396,474
270
271
272
273 511 Maintenance of Strctures
274 P SNPPS 21,651,422 20,266,869 1,384,552 1,384,552
275 P SNPPS 862,871 807,692 55,178 55,178
276 82 22,514,293 21,074,562 1,439,731 1,439,731
277
278 512 Maintenanc of Boiler Plant
279 P SNPPS 90,472,543 84,687,058 5,785,485 5,785,485
280 P SNPPS 3,997,588 3,741,934 255,634 255,634
281 82 94,470,112 88,428,993 6,041,119 6,041,119
282
283 513 Maintenance of Electc Plant
.::P SNPPS 31,041,437 29,056,417 1,985,020 1,985,020
P SNPPS 797,219 746,239 50,980 50,980
86 B2 31,838,656 29,802,656 2,036,000 2,036,000
287
288 514 Maintenance of Misc. Steam Plant
289 P SNPPS 9,395,338 8,794,530 60,808 600,88
290 P SNPPS 2,556,029 2,392,578 163,451 163,451
291 B2 11,951,367 11,187,108 764,259 764,259
292
293 Totl Steam Power Generation B2 854,983,104 799,185,610 55,797,494 40,494 55,837,988
ROLLED.IN Page 9.6
Begnning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL_94 517 Operation Super & Engineering
95 P SNPPN
296 82
297
298 518 Nudear Fuel Exnse
299 P SE
300
301 82
302
303 519 Cooants and Water
304 P SNPPN
305 82
306
307 520 Steam Exnses
308 P SNPPN
309 82
310
311
312
313 523 EléC Expenses
314 P SNPPN
315 82
316
317 524 Mise Nuclear Expenses
318 p SNPPN
319 82
320
321 528 Maintenance Super & Engineering
322 P SNPPN
323 82
324
325 529 Maintenance of Strctures
326 P SNPPN
327 82
328.29 530 Maintenanc of Reactor Plant
30 P SNPPN
31 82
332
333 531 Maintenance of Elecic Plant
334 P SNPPN
335 82
336
337 532 Maintenance of Mise Nuclear
336 P SNPPN
339 82
340
341 Total Nuclear Power Generaon B2
342
343 535 Opetion Super & Engineering
34 P DGP
345 P SNPPH 4,922,053 4,607,301 314,753 16,853 331,606
346 P SNPPH 3,506,438 3,282,211 224,228 224,228
347
348 82 8,428,491 7,889,511 538,980 16,853 555,833
349
350 536 Water For Powr
351 P DGP
352 P SNPPH 146,556 137,184 9,372 9,372
353 P SNPPH 70,232 65,741 4,491 4,491
354
355 82 216,788 202,925 13,863 13,863
356
.
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
357 537 Hyraulic Expenses.58 P DGP
59 P SNPPH 4,299,292 4,024,364 274,929 274,929
360 P SNPPH 406,674 380,668 26,006 26,006
361
362 B2 4,705,966 4,405,032 300,934 300,934
363
364 538 Elecc Expenses
365 P DGP
366 P SNPPH
367 P SNPPH
368
369 B2
370
371 539 Mise Hyro Exnses
372 P DGP
373 P SNPPH 8,629,629 8,On,787 551,842 53,254 605,096
374 P SNPPH 6,507,896 6,091,733 416,163 416,163
375
376
377 B2 15,137,525 14,169,520 968,006 53,254 1,021,259
378
379 540 Rents (Hydro Generation)
380 P DGP
381 P SNPPH ..34;192----.---2;00-2,t87-(6)----2;181--
382 P SNPPH 11,233 10,515 718 718
38338 B2 45,426 42,521 2,905 (6)2,899
385
386 541 Maint Supervision & Engineenng
387 P DGP
388 P SNPPH
389 P SNPPH
390
391 B2.92
393 542 Maintenance of Strctres
94 P DGP
395 P SNPPH 696,136 838,831 57,306 (41)57,264
396 P SNPPH 124,785 116,805 7,980 7,980
397
398 B2 1,020,921 955,636 65,285 (41)65,244
399
400
401
402
403 543 Maintenanc of Dams & Waterways
404 P DGP
405 P SNPPH 730,036 663,352 46,684 692 47,376
406 P SNPPH 287,859 269,451 18,408 18,408
407
408 B2 1,017,895 952,803 65,092 692 65,784
409
410 54 Maintenance of Elenc Plant
411 P DGP
412 P SNPPH 1,129,866 1,057,614 72,252 (0)72,252
413 P SNPPH 548,628 513,545 35,083 35,083
414
415 B2 1,678,495 1,571,159 107,335 (0)107,335
416
417 545 Maintenance of Misc. Hydro Plant
418 P DGP
419 P SNPPH 1,330,440 1,245,362 85,078 85,078
420 P SNPPH m,420 727,706 49,714 49,714
421
422 B2 2,107,860 1,973,068 134,792 134,792
423
424 Totl Hydraulic Power Generation B2 34,359,368 32,162,175 2,197,193 70,752 2,267,944
.
ROLLED-IN Page 9.8
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.25
, 26 546 Operation Super & Engineenng
427 P SNPPO 729,753 683,87 46,666 (254)46,412
428 P SNPPO
429 82 729,753 683,87 46,666 (254)46,412
430
431 547 Fuel-Non.NPC
432 P SE
433 P SE
434 82
435
436 547NPC Fuel-NPC
437 P SE 261,141,972 243,941,952 17,200,020 4,688,796 21,888,817
438 P SE 84,695,537 60,434,389 4,261,148 4,261,148
439 82 325,837,509 304,376,341 21,461,168 4,688,796 26,149,964
440
441 548 Generaion Expense
442 P SNPPO 11,819,366 11,063,548 755,818 (505,575)250,243
443 P SNPPO 10,636,272 9,956,110 680,162 680,162
444 82 22,455,638 21,019,658 1,435,980 (505,575)930,405
445
446 549 Miscllaneous Oter
447 P SNPPO 5,931,468 5,552,164 379,302 5n,080 956,382
448 P SNPPO
449 82 5,931,466 5,552,164 379,302 577,080 956,382
450
451
452
453
454 550 Rents
455 P SNPPO 968,996 923,880 63,116 (398,034)(334,918)
458 P SNPPO 10,9n,690 10,275,695 701,995 701,995
457 82 11,96,686 11,199,576 765,111 (398,034)367,077
458
459 551 Maint Supervision & Engineenng.60 P SNPPO
61 82
462
463 552 Maintenance of Strctures
464 P SNPPO 339,854 318,121 21,733 (5,923)15,809
465 P SNPPO 276,119 258,462 17,657 17,657
468 82 615,974 576,584 39,390 (5,923)33,466
467
468 553 Maint of Generation & Elecnc Plant
469 P SNPPO 3,359,178 3,144,367 214,811 (36,940)1n,871
470 P SNPPO 1,271,491 1,190,182 81,309 81,309
471 82 4,630,669 4,334,549 296,119 (36,940)259,179
472
473 554 Maintenance of Misc. Other
474 P SNPPO 113,448 106,194 7,255 (8,737)(1,483)
475 P SNPPO 282,834 264,561 18,074 18,074
476 82 396,083 370,754 25,328 (8,737)16,591
477
478 Totl Oter Power Generation B2 372,561,778 34,112,714 24,449,064 4,310,413 28,759,477
479
480
481 555 Purcased Powr-Non NPC
482 DMSC S (22,499,508)(17,131,485)(5,368,023)5,368,023
483 (22,499,508)(17,131,485)(5,368,023)5,368,023
484
485 555NPC Purcased Power-NPC
486 P SG 633,103,690 592,618,348 40,485,342 52,557,112 93,042,454
487 P SE 153,134,779 143,048,613 10,086,166 (4,246,324)5,839,842
488 Seasonal Co P SG
489 DGP
490 786,238,469 735,666,960 50,571,509 48,310,788 98,882,296
491
492 Totl Purcased Powr 82 763,738,961 718,535,475 45,203,486 53,678,811 98,882,296
493
.::558 Sytem Control & Load Dispatch
P SG 2,535,081 2,372,969 162,112 162,112
96
, 497 82 2,535,081 2,372,969 162,112 162,112
498
499
ROLLED-IN Page 9.9
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL~oo
01 557 Ot Expenses
502 P S (183,792)(150,819)(32,973)1,191,104 1,158,130
503 P SG 59,521,272 55,715,041 3,806,231 (289,713)3,516,518
504 P SGCT 1,122,425 1,050,366 72,059 72,059
505 P SE
506 P SG 82,718 77,429 5,290 5,29
507 P TROJP
508
509 B2 60,542,623 56,692,016 3,850,607 901,390 4,751,997
510
511 Embeded Cost Diffrentials
512 Company Ow Hy P DGP
513 Company Owed Hyd P SG
514 Mid-C Contct P Me
515 Mi Contrct P SG
516 Existing OF Contrct P S
517 Exl5ting OF Contract P SG
518
519
520
521 T~I ~er Power Supply B2 826,816,664 m,600,460 49,216,204 54,580,201 103,796,405
522
523 T~I Prouction Expense B2 2,088,720,914 1,957,060,959 131,659,955 59,001,860 190,661,815
524
525
526 Summary of Prouctn Expense by Factor
527 S (22,683,300)(17,282,304)(5,400,996)6,559,127 1,158,130
528 SG 695,242,761 650,783,786 44,458,975 52,267,398 96,726,374
529 SE 1,06,995,761 994,850,205 70,145,556 360,603 70,50,159
530 SNPPH 34,359,368 32,182,175 2,197,193 70,752 2,267,94
531 TROJP
532 SGCT 1,122,425 1,050,366 72,059 72,059
533 DGP
534 DEU.35 DEP
36 SNPPS 268,959,631 251,760,358 17,199,272 122,363 17,321,635
537 SNPPO 46,724,269 43,736,373 2,987,896 (378,363)2,609,513
538 DGU
539 Me
54 SSGCT
541 SSECT
542 SSGC
543 SSGCH
54 SSECH .
545 Total Proucon Expense by Factor 82 2,068,720,914 1,957,060,959 131,659,955 59,001,860 190,661,815
54 560 Opration Supervision & Engineering
547 T SNPT 8,207,350 7,682,512 524,839 5,873 530,712
548
549 82 8,207,350 7,682,512 524,839 5,873 530,712
550
551 561 Loa Dispatcing
552 T SNPT 7,888,745 7,384,280 504,465 504,465
553
554 B2 7,888,745 7,384,280 504,465 504,465
555 562 Statin Expense
556 T SNPT 1,00,028 941,695 64,333 64,333
557
558 82 1,00,028 941,695 64,333 64,333
55956 563 Overhead Line Expnse
561 T SNPT 125,807 117,762 8,045 8,045
562
563 82 125,807 117,762 8,045 6,045
56
565 56 Underground Line Expense
56 T SNPT
567
568 B2
.'"
ROLLED-IN Page 9.10
BelnnlnglEndlng
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DeSCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.70 565 Transmission of Electicity by Others
71 T SG
572 T SE
573
574
575 565NPC Transmission of Elecicity by Others-NPC
576 T SG 104,789,310 98,088,305 6,701,005 455,148 7,156,154
5n T SE 1,802,800 1,684,059 118,741 (113,002)5,739
578 106,592,110 99,772,365 6,819,746 .342,146 7,161,892
579
580 Total Transmission of Eleccity by Others 82 106,592,110 99,772,365 6,819,746 342,146 7,161,892
581
582 566 Mis. Transmission Expense
583 T SNPT 2,751,804 2,575,833 175,971 (6,395)169,578
584
585 82 2,751,804 2,575,833 175,971 (6,395)169,576
58
587 567 Rents. Transmission
588 T SNPT 1,358,267 1,269,538 86,730 86,730
589
590 82 1,356,267 1,269,538 86,730 86,730
591
592 568 Maint Supervision & Engineering
593 T SNPT 56,234 52,638 3,596 3,596
594
595 82 56,234 52,638 3,596 3,596
596
597 569 Maintenance of Strctures
598 T SNPT 3,233,567 3,026,789 206,778 206,778
599
600 82 3,233,567 3,026,789 206,778 206,778
601
602 570 Maintenance of Station Equipment
603 T SNPT 9,272,545 8,679,590 592,955 592,955
604~05 82 9,272,545 8,679,590 592,955 592,955
06
07 571 Maintenance of Overhead Lines
608 T SNPT 13,323,841 12,471,816 852,025 852,025
609
610 82 13,323,841 12,471,816 852,025 852,025
611
612 572 Maintenance of Underground Lines
613 T SNPT
614
615 82
616
617 573 Maint of Misc. Transmission Plant
618 T SNPT 380,572 356,235 24,337 24,337
619
620 82 380,572 356,235 24,337 24,337
621
622 Total Transmission Expense 82 154,194,872 144,331,053 9,863,819 341,625 10,205,44
623
624 Summary of Transmission Expense by Factor
625 SE 1,802,800 1,684,059 118,741 (113,002)5,739
626 SG 104,789,310 98,088,305 6,701,005 455,148 7,156,154
627 SNPT 47,602,762 44,558,688 3,04,073 522)3,043,552
628 Total Transmission Exense by Factor 1 4,194,872 14 , 31,053 9, 63,819 1, 25 0,20 , 44
629 580 Operation Supervision & Engineering
630 DPW S 197,509 236,002 (38,492)16 (38,476)
631 DPW SNPD 19,530,509 18,629,976 900,533 (5,743)894,790
632 82 19,728,019 16,865,978 862,041 (5,726)856,314
63363 581 Lod Disptching
635 DPW S
636 DPW SNPD 12,661,549 12,077,737 583,812 9,021 592,832
637 82 12,661,549 12,077,737 583,812 9,021 592,832
638
639 582 Statin ExpenseerDPW S 3,361,261 3,187,322 173,939 1,861 175,799
41 OPW SNPD 14,696 14,018 678 11 689
642 82 3,375,957 3,201,340 174,616 1,872 176,488
. 643
ROLLED-IN Page 9.11
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
eF 583 Overhd Line Expenses
DPW S 6,970,600 6,802,998 167,601 2,64 170,247
46 DPW SNPD 642,038 612,435 29,604 379 29,983
647 82 7,612,638 7,415,433 197,205 3,025 200,229
648
649 564 Undergrond Line Expense
650 DPW S 230,535 230,535
651 DPW SNPD
652 82 230,535 230,535
653
654 585 Strt lighting & Signal Systems
655 DPW S
65 DPW SNPD 248,162 236,720 11,443 255 11,697
657 82 248,162 236,720 11,443 255 11,697
658
659 586 Mer Exnss
660 DPW S 4,625,918 4,360,927 264,990 4,134 269,124
661 DPW SNPD 1,169,500 1,115,576 53,925 799 54,724
662 82 5,795,418 5,476,503 318,915 4,933 323,648
66366 587 Customer Installation Expenses
665 DPW S 9,337,558 8,702,201 635,356 10,072 645,429
66 DPW SNPD
667 82 9,337,558 8,702,201 635,356 10,072 645,429
668
669 588 Misc. Distrbution Expenses
670 DPW S 2,742,204 2,535,001 207,204 1,723 208,927
671 DPW SNPD 6,356,655 6,063,556 293,099 14,629 307,729
672 82 9,098,860 8,598,557 500,303 16,352 516,655
673
674 589 Rents
675 DPW S 3,921,526 3,872,496 49,029 56 49,086
676 DPW SNPD 368,405 351,418 16,987 16,987
6n 82 4,289,931 4,223,915 66,016 56 86,072
678~79 590 Maint Supervision & Engineering
80 DPW S 543,076 520,148 22,928 353 23,281
81 DPW SNPD 5,959,341 5,664,562 274,779 5,042 279,821
682 82 6,502,417 6,204,710 297,707 5,395 303,102
683
664 591 Maintenance of Strres
685 DPW S 1,248,687 1,158,681 90,006 90,00
686 DPW SNPD 134,105 127,922 6,183 6,183
687 82 1,382,792 1,266,602 96,189 96,189
688
689 592 Maintenanc of Station Equipment
690 DPW S 9,975,463 9,621,688 353,n5 4,367 358,142
691 DPW SNPD 1,768,399 1,686,860 81,539 1,872 83,411
692 82 11,743,862 11,308,548 435,314 6,239 441,553
693 593 Maintenance of Overhead lines
694 DPW S 89,826,662 64,865,111 4,961,551 26,667 4,988,217
695 DPW SNPD 1,680,189 1,602,717 n,472 (897)76,575
696 82 91,506,851 86,467,828 5,039,022 25,769 5,064,792
697
698 594 Maintenance of Underground Lines
699 DPW S 22,772,712 22,023,721 748,990 8,492 757,482
700 DPW SNPD 28,951 27,616 1,335 17 1,352
701 82 22,801,663 22,051,337 750,325 8,509 758,834
702
703 595 Maintenance of Line Transformers
704 DPW S 60,688 60,688
705 DPW SNPD 66,276 652,724 31,551 233 31,785
706 82 744,964 713,412 31,551 233 31,785
707
708 596 Maint of Street Lighting & Signal Sys.
709 DPW S 4,335,96 4,170,152 165,812 2,440 168,252
710 DPW SNPD
711 82 4,335,964 4,170,152 165,812 2,440 168,252
712.
ROLLED-IN Page 9,12
Beginninginding
FERC BUS UNADJUSTED RESULTS IDAHO
AceT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL_13 597 Maintenance of Meters
14 DPW S 3,956,999 3,672,402 284,598 4,509 289,107
15 DPW SNPD 1,519,486 1,449,424 70,062 526 70,588
716 B2 5,476,485 5,121,826 354,660 5,035 359,695
717
718 598 Maint of Mise. Distrbution Plant
719 DPW S 3,487,765 3,448,380 39,384 200 39,584
720 DPW SNPD 979,485 934,322 45,163 854 46,017
721 B2 4,467,250 4,382.702 84,547 1,054 85,602
722
723 Totl Distribution Expense B2 221,340,872 210,736,037 10,604,835 94,535 10,699,370
724
725
726 Summary of Distributio Expense by Factor
727 S 187,595,125 159,468,455 8,128,871 67,537 8,194,207
728 SNPD 53,745,747 51,267,583 2,478,164 26,998 2,505,162
729
730 Total Distrbution Expense by Factor 221,340,872 210,738,037 10,604,835 94,535 10,699,370
731
732 901 Supervision
733 CUST S 282,967 252,2n 10,889 189 10,859
734 CUST CN 2,493,732 2,392,393 101,339 1,125 102,464
735 B2 2,756,699 2,64,670 112,029 1,295 113,323
738
737 902 Meer Reading Expense
738 CUST S 27,323,838 25,747,110 1,576,728 19,283 1,596,010
739 CUST CN 844,132 809,829 34,303 331 34,834
740 B2 28,167,970 26,556,939 1,611,031 19,613 1,630,645
741
742 903 Customer Recipts & Collecons
743 CUST S 6,419,019 6,191,137 227,882 3,519 231,401
744 CUST CN 49,188,818 47,189,905 1,998,914 5,104 2,004,017
745 B2 55,607,837 53,381,042 2,226,795 8,623 2,235,418
748
747 90 Unclecble Accunts.48 CUST S 9,363,544 9,022,016 341,528 341,528
49 P SG
50 CUST CN (812,507)(79,489)(33,018)32,510 (508)
751 B2 8,551,037 8,242,527 308,510 32,510 341,020
752
753 905 Mis Customer Accunts Exnse
754 CUST S 3,768 3,768
755 CUST CN 370,476 355,420 15,055 114 15,169
756 B2 374,243 359,188 15,055 114 15,169
757
758 Totl Customer Accounts Expense B2 95,457,786 91,184,366 4,273,420 62,155 4,335,575
759
760 Summary of Customer Accs Exp by Facor
761 S 43,373,135 41,216,309 2,156,827 22,971 2,179,798
762 CN 52,084,650 49,968,057 2,116,593 39,184 2,155,n7
763 SG ..
764 Totl Customer Accnts Expense by Factor 95,457,786 91,184,366 4,273,420 62,155 4,335,575
765
766 907 Supervision
767 CUST S
768 CUST CN 423,544 406,332 17,212 208 17,420
769 B2 423,544 406,332 17,212 208 17,420
no
n1 908 Customer Assistance
n2 CUST S 38,718,172 35,171,471 3,546,701 (2,042,021 )1,504,680
n3 CUST CN 4,038,065 3,873,968 164,097 1,813 165,910
774
775
776 B2 42,756,237 39,045,439 3,710,798 (2,040,208)1,670,590
n7
.
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Beginning/Ending
FERC BUS UNAJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
778 909 Informatnal & Instrctonal Adv.79 CUST S 629,957 818,253 11,705 (8,280)3,424
80 CUST eN 3,154,588 3,026,394 128,195 (1,251)126,944
781 82 3,784,546 3,644,646 139,899 (9,531)130,368
782
783 910 Mise. Customer Servce
784 CUST S 2,00 1,376 624 624
785 CUST CN 3,126 2,999 127 127
786
787 82 5,126 4,375 751 751
788
789 Total Customer Service Expense B2 46,969,452 43,100,792 3,868,660 (2,049,531)1,819,129
790
791
792 Summaiy of Customer Service Ex by Factor
793 S 39,350,128 35,791,099 3,559,029 (2,050,301)1,506,728
794 CN 7,619,324 7,309,693 30,631 770 310,401
795
796 Total Customer Service Expense by Factor 82 46,969,452 43,100,792 3,868,660 (2,049.531)1,819,129
797
7911
799 911 Supervsion
800 CUST S
801 CUST CN
802 82
803
804 912 Demonstration & Selling Expense
805 CUST S
806 CUST CN
807 82
808
809 913 Adsing Exnse
810 CUST S
811 CUST CN
812 82
ei13 916 Misc. Sales Expense14
815 CUST S
816 CUST CN
817 82
818
819 Total Sales Expense 82
820
821
822 Totl Sales Expense by Factr
823 S
824 CN
825 Totl Sales Expense by Factor
826
827 Totl Customer Service Exp Including Salel 82 46,969,452 43,100,792 3,868,660 (2,049,531)1,819,129
828 920 Administrtive & General Salaries
829 PTO S 351,795 351,795
830 CUST CN
831 PTO SO 82,949,771 78,004,052 4,945,719 (190,210)4,755,509
832 82 83,301,566 78,355,847 4,945,719 (190,210)4,755,509
833
834 921 Of Supplies & expenses
835 PTO 5 (937,484)(938,909)1,425 (1,264)161
836 CUST CN
837 PTO SO 12,717,213 11,958,974 758,239 (38,027)720,212
838 82 11,779,729 11,020,065 759,664 (39,291)720,374
839
840 922 A&G Expeses Transferr
841 PTO S
842 CUST CN
843 PTO SO (20,697,805)(19,463,738)(1,234,066)37,437 (1,196,629)
844 82 120,697,805)(19,463,738)(1,234,066)37,437 (1,196,629)
845.
ROLLED-N Page 9,14
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
e:r 923 Outside 5ervices
84~
PTO S 40,783 40,783
CU5T CN
849 PTO 50 9,759,438 9,177,548 581,887 (6,188)575,722
850 B2 9,800,219 9,218,331 581,887 (8,188)575,722
851
852 924 Propert Insurance
853 PTO 50 24,518,013 23,054,294 1,481,720 1,461,720
854 B2 24,518,013 23,054.294 1,481,720 1,461,720
855
856 925 Injunes & Damages
857 PTO SO 11,291,287 10,818,088 873,221 873,221
858 B2 11,291,287 10,618,066 673,221 873,221
859
860 926 Emple Pensis & Benefits
861 LABOR S
862 CU5T CN
863 LABOR 50
884 B2
865
866 927 Francise Requirements
887 OM5C S
868 OM5C SO
869 B2
870
871 928 Regulatory Commission Expense
872 DM5C 5 8,088,821 7,780,056 328,784 328,784
873 CU5T CN
874 OM5C 50 407 383 24 24
875 FERC 5G 1,922,411 1,799,478 122,933 (150,503)(27,570)
878 B2 10,011,639 9,559,918 451,722 (150,503)301,218
877
878 929 DupliCte Chargs
879 LA80R 5
880 LABOR SO
15,845,340)
(5,496,823)(348,517)(79)(349,258).881 82 5,845,340)(5,496,823)(348,517)(739)(349,258)
882
883 930 Mise General Expenses
884 PTO S 12,190,297 12,189,873 624 171,936 172,560
885 CUST CN 5,724 5,491 233 233
886 LABOR 50 13,372,148 12,574,859 797,288 912,433 1,709,721
887 B2 25,568,189 24,770,024 798,145 1,084,389 1,862,514
888
889 931 Rents
890 PTO 5 902,697 902,897
891 PTO 50 5,389,807 5,088,450 321,357 321,357
892 B2 8,292,504 5,971,147 321,357 321,357
893
894 935 Maintenance of General Plant
895 G 5 42,149 42,149
896 CU5T CN
897 G 50 24,296,341 22,847,718 1,448,822 4,178 1,452,800
898 B2 24,338,489 22,889,887 1,448,822 4,178 1,452,800
89990 Totl Administrive & General Expense B2 180,356,471 170,496,997 9,859,474 739,075 10,598,549
901
902 Summary of A&G Expense by Factr
903 5 20,679,057 20,348,243 330,814 170,672 501,485
904 50 157,749,278 148,343,784 9,405,494 718,907 10,124,401
905 5G 1,922,411 1,799,478 122,933 (150,503)(27,570)
906 CN 5,724 5,491 233 233
907 Total A&G Exnse by Facor 180,358,47 170,498,997 9,859,474 739,075 10,598,549
908
909 Total O&M Expense B2 2,787,040,368 2,616,910,205 17,130,162 58,189,719 228,319,881
.
ROLLED.IN Page 9.15
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.910 403SP Steam Depreciation
911 P SG 37,507,935 35,109,400 2,398,535 2,398,535
912 P SG 40,335,873 37,756,498 2,579,375 2,579,375
913 P SG 60,60,591 56,730,956 3,875,635 (2,n4,158)1,101,477
914 P SG 9,113,517 8,530,731 582,766 582,786
915 83 147,563,915 138,127,585 9,436,330 (2,774,158)6,662,173
916
917 403NP Nuclear Depreation
918 P SG
919 83
920
921 403HP Hy Depreation
922 P SG 4,979,312 4,660,898 318,414 318,414
923 P SG 1,187,400 1,111,469 75,931 75,931
924 P SG 5,278,568 4,939,145 337,423 143,165 480,587
925 P SG 1,477,963 1,383,451 94,512 94,512
926 83 12,921,243 12,094,963 826,280 143,165 969,445
927
928 4030P Oter Prouction Depreciation
929 P SG 39,783 37,239 2,54 2,544
930 P SG 29,280,267 27,407,870 1,872,397 1,088,970 2,959,368
931 P SG 3,161,554 2,959,381 202,173 202,173
932 P 5G
933 83 32,481,604 30,404,490 2,077,115 1,086,970 3,164,085
934
935 403TP Transmission Depreation
936 T 5G 12,270,765 11,486,082 784,684 784,684
937 T 5G 13,361,846 12,507,203 854,443 854,443
938 T 5G 31,738,237 29,708,659 2,029,578 (13,687)2,015,891
939 83 57,370,848 53,701,943 3,68,704 (13,687)3,655,017
940
941
942
943 403 Distributon Deprecation94360li & LI RIg DPW 5 274,805 257,336 17,469 17,469.945 361 Sti DPW 5 933,033 918,355 14,678 14,678
946 362 _Eqnl DPW 5 14,029,409 13,654,655 374,754 374,754
947 363 St-. Eq DPW S 142,101 142,101
948 36 Po. & Tow DPW S 34,352,246 32,283,440 2,068,806 (237,774)1,831,032
949 365 OH Co DPW S 18,530,644 15,848,682 881,962 881,962
950 38 UGCo DPW 5 6,473,439 6,319,003 154,436 154,436
951 367 UG Co DPW 5 13,788,826 13,327,754 461,073 461,073
952 368 Li TraM DPW S 23,342,420 21,974,708 1,367,712 1,367,712
953 369 5a.DPW S 9,972,443 9,438,963 533,480 533,480
954 370 -DPW 5 6,471,780 6,014,806 456,974 456,974
955 371 IlCUI Plm DPW S 379,042 371,772 7,270 7,270
956 372 lIPrrt DPW 5 1,293 1,166 127 127
957 373 Stee Ug DPW S 2,373,614 2,341,318 32,296 32,296
958 83 129,065,095 122,694,059 6,371,036 (237,774)6,133,262
959
960 403GP General Depreation
961 G-ITU5 S 12,940,217 12,073,436 866,780 (89,186)777,594
962 G.DGP SG 469,209 439,204 30,005 30,005
963 G-DGU 5G 807,216 755,597 51,619 51,619
96 P 5E 37,603 35,126 2,477 (39)2,438
965 CUST CN 1,384,927 1,328,847 56,280 (2,825)53,55
966 G-SG SG 4,911,245 4,597,183 314,061 (30,872)283,190
967 PTD 50 17,641,227 16,589,403 1,051,824 (27,722)1,024,101
968 G-5G 5G 16,958 15,874 1,084 1,084
969 G-SG SG 170,708 159,792 10,916 10,916
970 83 38,379,310 35,994,262 2,385,047 (150,645)2,234,403
971
972 403GVO Genral Vehicles
973 G-5G 5G
974 83
975
976 403MP Mining Depreciation
977 P SE 2,608 2,606
978 83 2,606 2,606
979.
ROLLED-IN Page 9.16
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO AOJUSTMENT ADJTOTAL.980 403EP Experimental Plant Deprecation
981 P SG
982 P SG
983 83
98 4031 ARO Deprecation
985 P S
986 83
987
988
989 Totl Depreciation Expense B3 417,781,814 393,017,301 24,764,513 (1,943,523)22,820,990
990
991 Summary S 142,005,312 134,767,495 7,237,817 (326,960)6,910,856
992 DGP
993 DGU
994 SG 256,712,746 240,296,630 16,416,116 (1,588,582)14,827,533
995 SO 17,641,227 16,589,403 1,051,824 (27,722)1,024,101
996 CN 1,384,927 1,328,647 56,280 (2,825)53,455
997 SE 37,603 35,126 2,477 2,567 5,044
998 SSGCH
999 SSGCT ...
1000 Tot Depreation Expnse By Fact 417,781,814 393,017,301 24,764,13 (1.943,523)22,820,990
1001
1002 404GP Amort of L T Plant. Capital Lease Gen
1003 I-ITS 5 967,674 967,674
100 I-SG SG
1005 PTD SO 1,708,800 1,606,916 101,884 101,88
1006 I-DGU SG
1007 CUST CN 232,427 222,982 9,445 9,445
1008 I.DGP SG
1009 B4 2,908,901 2,797,572 111,329 111,329
1010
1011 404SP Am of L T Plant. Cap Lease Steam
1012 P SG
1013 P SG
1014 B4.015
016 4041P Amort of L T Plant. Intangible Plant
1017 I-ITUS S 38,191 17,790 20,401 20,401
1018 P SE 3,711 3,46 244 244
1019 I-G SG 6,479,693 6,065,334 414,360 326,846 741,206
1020 PTD SO 28,791,417 27,074,785 1,716,632 (3,771)1,712,862
1021 CUST CN 4,849,670 4,652,591 197,079 197,079
1022 I-SG SG 2,057,084 1,925,539 131,545 131,545
1023 I-G SG 309,688 289,884 19,804 19,804
1024 I-DGP SG
1025 I-G SG
1026 I-SG SO 5,777 5,08 369 369
1027 I-DGU SG 17,884 16,740 1,144 1,144
1028 B4 42,553,115 40,051,537 2,501,578 323,075 2,824,654
1029
1030 404MP Amor of L T Plant. Mining Plant
1031 P SE
1032 B4
1033
1034 4040P Amort of L T Plant. Oter Plant
1035 p SG 293,921 275,126 18,796 (11,019)7,m
1036 B4 293,921 275,126 18,796 (11,019)7,777
1037
1038
1039 404HP Amorzation of Other Elecc Plant
1040 P SG 2,284 2,138 146 146
1041 P SG 38,242 35,797 2,445 2,445
1042 P SG
1043 B4 40,526 37,935 2,592 2,592
104
1045 Totl Amortzation of Limite Term Plant B4 45,796,464 43,162,170 2,634,294 312,057 2,946,351
1046
1047
1048 405 Amortzation of Oter Elecc Plant
1049 GP S.1050
1051 B4
1052
ROLLED-IN Page 9.17
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.053 406 Amorttion of Plant Acquisition Adj
054 P S
055 P SG
1056 P SG
1057 P SG 5,479,353 5,128,962 350,390 350,390
1058 P SO
1059 B4 5,479,353 5,128,962 350,390 350,390
1060 407 Amort of Prop Loses, Unrec Plant, etc
1061 DPW S 9,752,248 9,752,248
1062 GP SO
1063 P SG 780,128 730,240 49,887 49,887
106 P SE
1065 P SG 333,105 311,803 21,301 (49,887)(28,588)
1086 P TROJP 2,018,153 1,888,638 129,515 129,515
1067 B4 12,681,634 12,880,931 200,703 (49,867)150,818
1066
1069 Totl Amortzation Expense B4 64,157,451 60,972,063 3,185,388 262,170 3.447,558
1070
1071
1072
1073 Summary of Amortization Expnse by Factor
1074 S 10,758,114 10,737,713 20,01 20,401
1075 SE 3,711 3,488 244 244
1076 TROJP 2,016,153 1,888,636 129,515 129,515
1077 DGP
1078 DGU
1079 SO 30,500,217 28,881,701 1,818,518 (3,771)1,814,745
1080 SSGCT
1081 SSGCH
1082 CN 5,082,097 4,875,573 206,524 206.524
1083 SG 15,797,159 14,788,971 1,010,187 265,940 1,278,128
1084 Total Amorzation Exnse by Factor 64,157,451 60,972,063 3,185,388 262,170 3,447,558
1085 408 Taxes Other Than Income
1086 DMSC S 23,301,297 23,301,297
1087 GP GPS 69,102,426 64,982,328 4,120,098 631,860 4,751,958.088 GP SO 8,523,359 8,015,171 508,189 508,189
089 P SE 545,664 509,724 35,940 35,940
090 P SG
1091 DMSC OPRV-ID
1092 GP EXCTAX
1093 GP SG
1094
1095
1096
1097 Totl Taxes Oter Than Income B5 101,472,747 96,808,521 4,664,227 631,80 5.296,086
1098
1099
1100 41140 Deferr Investmnt Tax Creit - Fed
1101 PTD DGU (5,854,880)(5,109,951)(744,909)(744,909)
1102
1103 B7 (5,854,880)(5,109,951)(744,909)(744,909)
1104
1105 41141 Deferr Investment Tax Credit - Idaho
1106 PTD DGU
1107
1106 B7
1109
1110 Total Deferred ITC B7 (5,854,860)(5,109,951)(744,909)(744,909)
1111
.
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Page 9,18
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
.112
113 427 Interest on Long-Term Debt
1114 GP S 3,141,352 3,141,352
1115 GP SNP 278,731.910 262,496,616 16,235.294 16,235,294
1116 B6 278,731,910 262,496.616 18,235.294 3,141,352 19,376,645
1117
1118 428 Amrtzation of Debt Disc & Ex
1119 GP SNP 7,664,485 7,218,052 446,433 446,433
1120 B6 7,864,485 7,218,052 446.433 448,33
1121
1122 429 Amorzation of Premium on Debt
1123 GP SNP ~58,884)~55,455)(3,430)(3,430)
1124 B6 (3,430)(3,430)58,884)55,455)
1125
1126 431 Otr Interst Expese
1127 NUTIL OTH
1128 GP SO
1129 GP SNP 29,764,583 28,030,885 1,733,697 1,733,697
1130 B6 29,764.583 28,030,885 1,733,897 1,733.697
1131
1132 432 AFUDC - Borr
1133 GP SNP (28,853.980)(26,984,972)(1,669,008)(1,669.008)
1134 (28,853,980)126,984,972)(1,669,008)(1,669.008)
1135
1136 Totl Elec, Interest Deuctions to Tax B8 287,448,113 270,705.127 16,742,986 3,141,352 19.864.336
1137
1138 Non-Utilit Poron of Interest
1139 427 NUTIL NUTIL
1140 428 NUTIL NUTIL
1141 429 NUTIL NUTIL
1142 431 NUTIL NUTIL
1143
1144 Total Non.utlity Interest
1145
.:::
Total Interest Deducons for Tax B6 287.448,113 270,705.127 16,742,986 3,141,352 19,864,338
148
149 419 Interest & Dividends
1150 GP S
1151 GP SNP 38,523,406)
1152 Total Operating Deductions for Tax B6 3 ,523,406)
1153
1154
1155 41010 Detrred Income Tax - Federal-DR
1156 GP S 362,440,419 34,567,360 13,873,059 6,042 13,879,101
1157 P TROJD 14,659 13,717 942 942
1158 PT DGP 2,438 2,438
1159 LABOR SO 35,789,683 33,655,793 2,133,890 (60,428)2,073,462
1160 GP SNP 21,316 20,074 1,242 1,242
1161 P SE 7,127,368 6,657,927 469,441 65,760 535,202
1162 PT SG 7,668,825 7,178,423 490.402 (86,755)403,646
1163 GP GPS 1,001 941 60 60
1164 DITEXP DITEXP 1,847,457 1,847,457
1165 CUST BADDEBT 1,887,380 1,819,266 68.094 68,09
1166 CUST CN 23,817 22,849 968 96
1167 P IBT 121,199 116.316 4,883 4,883
1168 DPW SNPD
1169 B7 415,098,105 398,055,124 17,042,981 1,772.076 18.815,057
1170
.
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1171.1172
1173 41110 Deferr Inme Tax - Federal-CR
1174 GP 5 (290,988,771)(279,583,593)(11,405,178)145,221 (11,259,957)
1175 P SE (7,430,238)(6,940,848)(489,390)(366,533)(855,923)
1176 PT DGP (300,173)(300,173)
1177 GP SNP (1,765,373)(1,662,548)(102,828)(102,828)
1178 PT SG (11,033,420)(10,327,861)(705,559)(114,757)(820,315)
1179 GP GPS (531,558)(499,665)(31,693)(31,693)
1180 LABOR SO (22,243,997)(20,917,742)(1,326,255)56,950 (1,269,305)
1181 PT SNPD (38,879)(37,086)(1,793)(1,793)
1182 CUST CN
1183 P SGCT (356,221)(333,352)(22,669)(22,869)
1184 DITP DITEXP
1185 P TROJD (581,632)(54,239)(37,393)(37,393)
1166 P SG
1187
1188
1189 B7 (335,270,262)(321,147,305)(14,122,958)(279,118)(14,402,076)
1190
1191 Totl Deferrd Income Taxes B7 79,827,843 76,907,819 2,920,024 1,492,958 4,412,982
1192 SCHMAF Aditons - Flow Through
1193 SCHMAF S
1194 SCHMAF SNP
1195 SCHMAF SO
1196 SCHMAF SE
1197 SCHMAF TROJP
1198 SCHMAF SG
1199 B6
120
1201 SCHMAP Additons - Permanent
1202 P 5
1203 P SE 87,039 81,30 5,733 5,733
1204 LABOR SNP 1,096,544 1,032,673 63,870 63,870
1205 SCHMAP.SO SO 11,167,890 10,502,026 665,864 665,864
1206 SCHMAP SG 119,015 111,404 7,611 7,611.207 DPW BADDEBT
208 B6 12,470,488 11,727,410 743,078 743,078
1209
1210 SCHMAT Additis - Tempory
1211 SCHMAT-5ITUS 5 29,272,039 28,462,675 809,364 (382,653)426,711
1212 P SG
1213 DPW CIAC 65,638,740 62,612,202 3,26,538 3,026,538
1214 SCHMAT.SNP SNP 60,771,286 57,231,542 3,539,744 3,539,744
1215 P TROJD 1,532,586 1,43,056 98,530 98,530
1216 P SG
1217 SCHMAT.SE SE 19,578,509 18,288,978 1,289,531 965,806 2,255,337
1218 P SG 28,819,660 26,976,717 1,842,943 302,381 2,145,323
1219 SCHMAT.GPS GPS 1,400,646 1,317,135 83,511 83,511
1220 SCHMAT.SO SO 15,680,298 14,745,391 934,907 934,907
1221 SCHMAT-SNP SNPD 29,370,967 28,016,700 1,354,267 1,354,267
1222 CUST CN
1223 P SG 938,633 878,610 60,023 60.23
1224 BOOKDEPR SCHMDEXP 495,661,101 466,280,201 29,380,900 (1,267,124)28,113,776
1225 B6 748,664,466 706,244,207 42,420,259 (381,590)42,038,668
1226
1227 TOTAL SCHEDULE - M ADDmONS B6 761,134,953 717,971,617 43,163,336 (381,590)42,781,746
1228
.
ROLLED-IN Page 9.20
Beginning/Ending
FERC BUS UNAJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL.229 SCHMDF Deuctns - Flo Throgh
1230 SCHMDF S
231 SCHMDF DGP
1232 SCHMDF DGU
1233 S6
123 SCHMDP Deductons. Permanent
1235 SCHMDP S
1236 P SE 4,395,479 4,105,973 289,507 289,507
1237 PTD SNP 381,063 358,868 22,196 22,196
1238 SCHMDP 1ST
1239 P SG 10,90,494 10,203,435 897,058 897,058
1240 SCHMDP.SO SO 25,050,142 23,558,576 1,493,566 1,493,586
1241 B6 40,727,178 38,224,851 2,502,327 2,502,327
1242
1243 SCHMDT Deductons. Tempory
1244 GP S 68,145,801 66,295,851 1,849,750 1,849,750
1245 DPW SADDEST 4,973,203 4,793,n7 179,426 179,426
1248 SCHMDT.SNP SNP 62,812,294 59,153,667 3,658,827 3,858,827
1247 SCHMDT CN 82,758 80,20 2,550 2,550
1248 SCHMDT TROJD 38,825 36,142 2,483 2,483
1249 CUST DGP 8,423 8,423
1250 P SE 22,948,826 21,435,441 1,511,384 173,2n 1,884,661
1251 SCHMDT-SG SG 12,022,379 11,253,579 768,800 788,800
1252 SCHMDT.GPS GPS 86,940,581 82,949,380 3,991,201 3,991,201
1253 SCHMDT.SO SO 68,849,738 82,863,950 3,985,788 (9,223)3,978,583
1254 T,lDEPR TAXDEPR 80,113,141 588,303,618 35,809,524 5,328,98 41,138,510
1255 DPW SNPD
1256 B6 908,911,545 857,152,014 51,759,531 5,493,040 57,252,571
1257
1258 TOTAL SCHEDULE. M DEDUCTIONS S6 949,638,723 895,376,866 54,261,858 5,493,040 59,754,898
1259
1280 TOTAL SCHEDULE. M ADJUSTMENTS B6 (188,503,770)(1n,405,249)(11,098,521)(5,874,630)(16,973,152)
1261
1282
1283.284 40911 State Incme Taxes
265 1ST 1ST 23,999,463 23,032,482 96,981 84,097 1,031,077
266 1ST 1ST
1267 REC P SG (54,393)(54,393)
1268 1ST 1ST .-.
1269 Totl State Tax Expense 23,999,463 23.032,482 96,981 9,703 976,684
1270
1271
1272 Calcuation ofTaxable Income:
1273 Operating Revenues 4.242.281,360 3,996,484.880 245,798,480 68,131.861 313,928,341
1274 Opting Deductions:
1275 o & M Exnses 2,787,040,368 2,616,910,205 170,130,162 58,189,719 228,319,881
1276 Depreation Expense 417,781,814 393,017,301 24,784,513 (1,943,523)22,820.990
1277 Amortzation Expense 84,157,451 60,972,083 3,185,388 262,170 3,447,558
1278 Taxes Other Than Income 101,472,747 96,808.521 4,684,227 631,860 5,296,088
1279 Intest & Dividends (AFUDC-Equit)(40,908,060)(38,523,408)(2,382.655)(2,382,855)
1280 Misc Revenue & Expense (11,343,723)(10,817,311)(728,412)563,834 (182,578)
1281 Total Operating Deductins 3,318,202,597 3,118,587,374 199,635,223 57,704,060 257,339,283
1282 Otr Deuctions:
1283 Interet Deductons 287,448,113 270,705,127 16,742,986 3,141,352 19,84,338
1284 Intert on PCRSS
1285 Scedule M Adjustments (188,503,770)(177,405,249)(11,098,521 )(5,874,630)(18,973,152)
1286
1287 Incoe Sefore State Taxes 448,126,879 429,807,130 18,319,749 1,411,819 19,731,568
1288
1289 State Incme Taxes 23,999,463 23,032,482 96,981 9,703 978,884
1290
1291 Totl Taxble Incoe 424,127,416 408,774.648 17,352,768 1,402,116 18,754,884
1292
1293 Tax Rate 35.0%35.0%35.0%35.0%35.0%
129
1295 Fedral Income Tax . Calculated 148,44,596 142,371,127 6,073,469 490,741 6,56,210
1296
1297 Adjustments to Calculated Tax:
1298 40910 PMI P SE.299 40910 REC P SG (1,512,84)(1,512,84)
300 40910 P SO
301 40910 lAS-LASOR S
1302 Federal Income Tax Expense 148,44,596 142,371,127 6,073,469 (1,022,103)5,051,365
1303
1304 Totl Operating Expenses 3,605,525,699 3,394,292,256 211,233,443 58,184,618 269,418,060
ROLLED-IN Page 9.21
Beglnnlnglndlng
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.305 310 Land and Land Rights
306 P SG 2,329,517 2,180,551 148,967 148,967
307 P SG 34,798,446 32,573,175 2,225,271 2,225,271
1308 P SG 49,617,190 46,44,299 3,172,891 3,172,891
1309 P S
1310 P SG 1,246,363 1,166,661 79,702 79,702
1311 B8 87,991,516 82,364,686 5,626,830 5,626,830
1312
1313 311 Strres and Improements
1314 P SG 235,801,003 220,722,139 15,078,864 15,078,864
1315 P SG 328,398,258 307,398,039 21,000,219 21,000,219
1316 P SG 177,328,983 165,989,253 11,339,729 11,339,729
1317 P SG 49,781,64 46,598,236 3,183,407 3,183,407
1318 B8 791,309,887 740,707,668 50,602,219 50,602,219
1319
1320 312 Boiler Plant Equipment
1321 P SG 736,597,256 689,493,768 47,103,488 47,103,488
1322 P SG 681,187,724 637,627,532 43,560,192 43,560,192
1323 P SG 1,161,266,483 1,087,00,497 74,259,986 74,259,986
1324 P SG 225,983,471 211,532,413 14,451,058 14,451,058
1325 B8 2,805,034,933 2,625,660,209 179,374,724 179,374,724
1326
1327 314 Turenerator Units
1328 P SG 149,324,012 139,775,128 9,548,884 9,548,884
1329 P SG 148,143,206 138,669,831 9,473,375 9,473,375
1330 P SG 395,314,559 370,035,216 25,279,343 12,717,589 37,996,932
1331 P SG 53,612,242 50,183,877 3,428,364 3,428,364
1332 B8 746,394,018 698,664,052 47,729,966 12,717,589 60,447,555
1333
1334 315 Accoiy Elecc Equipment
1335 P SG 66,303,558 82,856,774 5,646,764 5,648,764
1336 P SG 139,536,216 130,613,236 8,922,980 8,922,980
1337 P SG 82,798,950 58,783,119 4,015,830 4,015,830
1338 P SG 46,958,470 43,955,597 3,002,873 3,002,873
1339 B8 337,597,194 316,008,727 21,588,467 21,588,467
.1340
1341
1342
1343 316 Mise Powr Plant Equipment
134 P SG 5,164,527 4,852,990 331,537 331,537
1345 P SG 8,241,113 5,842,010 399,103 399,103
1346 P SG 12,34,688 11,555,277 789,411 789,411
1347 P SG 3,144,722 2,943,625 201,097 201,097
1348 B8 26,915,050 25,193,902 1,721,148 1,721,148
1349
1350 317 Stem Plant ARO
1351 P S
1352 88
1353
1354 SP Unclassified Steam Plant. Accunt 300
1355 P SG 3,46,353 3,242,816 221,536 221,536
1356 B8 3,464,353 3,242,816 221,536 221,536
1357
1358
1359 Total Steam Producton Plant B8 4,798,706,950 4,491,842,061 306,864,889 12,717,589 319,582,478
1360
1361
1362 Summaiy of Steam Prouction Plant by Factor
1363 S
136 DGP
1365 DGU
1366 SG 4,798,706,950 4,491,842,061 306,864,889 12,717,589 319,582,478
1367 SSGCH ..
1368 Total Steam Procton Plant by Factor 4,798,706,950 4,491,842,061 306,864,889 12,717,589 319,582,478
1369 320 Lad and Land Rights
1370 P SG
1371 P SG
1372 B8
1373
1374 321 Strres and Improvements.375 P SG
376 P SG B8
1377
ROLLED.JN Page 9,22
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL.378
379 322 Reacor Plant Equipment
380 p SG
1381 P SG
1382 B8
1383
1384 323 Turenerator Units
1385 p SG
1388 P SG
1387 B8
1388
1389 324 Land and Land Rights
1390 P SG
1391 P SG
1392 B8
1393
1394 325 M'IS. Powr Plant Equipment
1395 p SG
1398 P SG
1397 B8
1398
1399
1400 NP Uncsified Nucar Plant - Acet 300
1401 P SG
1402 B8
1403
1404
1405 Total Nuclear Production Plant 88
1406
1407
1408
1409 Summary of Nuclear Production Plant by Factor
1410 DGP
1411 DGU
1412 SG.413
414 Totl Nucear Plant by Facor
415
1416 330 Land and Land Rights
1417 P SG 10,827,138 9,947,560 879,578 879,578
1418 P SG 5,308,218 4,968,789 339,447 339,447
1419 P SG 3,073,580 2,8n,032 198,547 198,547
1420 P SG 835,700 595,048 40,851 40,851
1421 B8 19,644,632 18,388,409 1,256,223 1,256,223
1422
1423 331 Strres and Improvements
1424 P SG 21,835,235 20,251,718 1,383,517 1,383,517
1425 P SG 5,395,695 5,050,854 345,041 345,041
1428 P SG 49,188,594 48,043,111 3,145,483 3,145,483
1427 P SG 8,885,819 8,445,302 440,318 440,318
1428 B8 83,105,144 n,790,785 5,314,359 5,314,359
1429
1430 332 Reservirs, Dams & Waterys
1431 P SG 154,814,949 144,914,933 9,900,015 9,900,015
1432 P SG 20,883,284 19,547,833 1,335,431 1,335,431
1433 P SG 73,887,929 88,975,n8 4,712,152 1,222,452 5,934,804
1434 P SG 33,845,550 31,494,004 2,151,548 2,151,546
1435 B8 283,031,891 264,932,547 18,099,144 1,222,452 19,321,598
1436
1437 333 Water Wheel, Turbines, & Generators
1438 P SG 32,984,160 30,856,187 2,107,973 2,107,973
1439 P SG 9,704,264 9,083,702 620,563 620,563
1440 P SG 35,024,227 32,784,519 2,239,709 2,239,709
1441 P SG 11,591,574 10,850,323 741,251 741,251
1442 B8 89,284,226 83,574,731 5,709,495 5,709,495
1443
144 334 Accssory Electric Equipment
1445 P SG 5,190,479 4,858,561 331,918 331,918
1446 P SG 4,058,731 3,799,185 259,545 259,545
1447 P SG 29,466,231 27,561,941 1,884,289 1,884,289.448 P SG 3,645,857 3,412,714 233,143 233,143
449 B8 42,381,297 39,652,402 2,708,895 2,708,895
450
ROLLED.IN Page 9,23
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.451
452
453 335 Mise. Por Plant Equipment
1454 P SG 1,371,951 1,284,218 87,733 87,733
1455 P SG 200,192 187,391 12,802 12,802
1456 P SG 984,383 921,435 62,949 62,949
1457 P SG 15,123 14,156 967 967
1458 68 2,571,649 2,407,199 164,450 164,450
1459
1460 336 RolKs, Railrods & 6ndges
1461 P SG 4,638,647 4,342,017 296,629 296,629
1462 P SG 836,256 782,780 53,476 53,476
1463 P SG 7,732,926 7,238,426 494,501 494,501
146 P SG 591,550 553,722 37,828 37,828
1465 68 13,799,379 12,916,944 862,435 882,435
1466
1467 337 Hydro Plant ARO
1468 P S
1469 68
1470
1471 HP Unclssified Hydro Plant. Ace 300
1472 P S
1473 P SG
1474 P SG
1475 P SG
1476 B8
1477
1478 Totl Hydraulic Prouction Plant B8 533,798,018 49,663,016 34,135,002 1,222,452 35,357,453
1479
1480 Summary of Hyraulic Plant by Factor
1481 S
1482 SG 533,798,018 499,663,016 34,135,002 1,222,452 35,357,453
1483 DGP
1484 DGU ..
1485 Total Hydraulic Plant by Factor 533,798,018 499,663,016 34,135,002 1,222,452 35,357,453.486
487 340 Land and Land Rights
488 P SG 21,542,430 20,184,847 1,377,583 1,377,583
1489 P SG
1490 P SG
1491 68 21,542,430 20,164,847 1,377,583 1,377,583
1492
1493 341 Stnre and Improvements
1494 P SG 76,609,247 71,710,284 4,898,963 4,898,963
1495 P SG 170,926 159,99 10,930 10,930
1496 P SG 4,237,997 3,966,988 271,009 271,009
1497 68 81,018,170 75,837,268 5,180,902 5,180,902
1498
1499 342 Fuel Holders, Proucers & Accssories
1500 P SG 16,813,666 15,738,475 1,075,190 1,075,190
1501 P SG 121,339 113,580 7,759 7,759
1502 P SG 2,257,625 2,113,255 144,369 144,369
1503 68 19,192,629 17,965,310 1,227,319 1,227,319
1504
1505 343 PnmeMovers
1506 P S
1507 P SG 774,173 724,666 49,506 49,506
1508 .p SG 666,532,969 623,909,911 42,623,058 (33,925)42,589,133
1509 P SG 51,317,832 48,036,190 3,281,643 3,281,643
1510 68 718,824,974 672,670,767 45,954,207 (33,925)45,920,282
1511
1512 34 Genertors
1513 P S
1514 P SG
1515 P SG 158,474,140 148,340,129 10,134,011 29,709,707 39,843,718
1516 P SG 15,873,843 14,858,565 1,015,078 1,015,078
1517 68 174,347,783 163,198,694 11,149,089 29,709,707 40,858,796
.
ROLLED-IN Page 9,24
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.518
519 345 Accry Elecric Plant
1520 P SG 10,189,291 66,262,504 4,526,192 4,526,192
1521 P SG 156,586 146,513 10,013 10,013
1522 P SG 4,041,177 3,182,154 258,423 258,423
1523 88 14,981,059 10,191,831 4,795,228 4,195,228
1524
1525
1526
1521 34 Misc. Powr Plant Equipment
1528 P SG 5,181,032 4,849,119 331,314 331,314
1529 P SG 11,813 11,058 155 155
1530 B8 5,192,845 4,860,776 332,069 332,069
1531
1532 341 Oter Prouction ARO
1533 P S
153 B8
1535
1536 OP Unclassfied Other Pro Plant.Acc 300
1531 P S
1538 P SG
1539
1540
1541 Totl Oter Prouction Plant B8 1,094,905,891 1,024,889,493 10,016,398 29,615,182 99,692,180
1542
1543 SUmmary of Other Production Plant by Factor
154 S
1545 DGU
1546 SG 1,094,905,891 1,024,889,493 10,016,398 29,615,162 99,692,180
1541 SSGCT ...
1546 Totl of Oter Prouction Plant by Facor 1,094,905,891 1,024,889,493 70,016,398 29,675,782 99,62,180
1549
1550 Experimental Plant
1551 103 Exmental Plant
1552 P SG.553 Totl Experimental Production Plant B8
554
1555 Totl Production Plant B8 6,427,410,860 6,016,394,571 411,016,289 43,615,823 45,632,112
1556 350 Land and Land Rights
1551 T SG 21,253,586 19,894,414 1,359,112 1,359,112
155 T SG 48,636,647 45,526,459 3,110,188 3,110,188
1559 T SG 23,003,146 21,532,116 1,411,030 1,411,030
1560 B8 92,893,978 86,953,649 5,940,329 5,940,329
1561
1562 352 Strctures and Improvements
1563 T S
1564 T SG 1,680,455 1,189,310 491,145 491,145
1565 T SG 18,212,141 11,103,690 1,168,456 1,168,456
1566 T SG 33,546,557 31,401,342 2,145,215 2,145,215
1561 B8 59,499,159 55,694,342 3,804,817 3,804,817
156
1569 353 Station Equipment
151O T SG 134,359,329 125,161,391 6,591,931 6,591,931
1511 T SG 196,180,332 184,196,139 12,583,593 12,583,593
1512 T SG 663,184,064 621,336,191 42,441,273 (21,907)42,425,366
1513 B8 994,923,724 931,300,927 63,622,197 (21,907)63,600,690
1514
1575 354 Towrs and Fixres
1576 T SG 156,369,123 146,369,722 9,999,401 9,999,401
1577 T SG 126,993,462 118,872,559 8,120,903 8,120,903
1578 T SG 119,294,971 111,666,367 7,628,605 7,628,605
1579 B8 402,657,556 316,908,648 25,748,909 25,748,909
1580
1581 355 Poles and Fixtures
1582 T SG 68,611,06 84,410,715 4,400,289 4,400,269
1583 T SG 118,660,645 111,012,604 7,568,041 1,568,041
1584 T SG 331,313,252 310,126,621 21,186,625 1,690,436 28,877,061
1585 B8 518,184,962 485,610,006 33,174,956 1,690,436 40,865,391
1586.
ROLLED-IN
Page 9.25
BeinningEnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DeSCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
.587 356 Cleanng and Grading
588 T SG 207,662,334 194,382,865 13,279,469 13,279,469
589 T SG 158,893,877 148.545,815 10,148,063 10,148,063
1590 T SG 312,230,054 292,263,750 19,96,304 19,98,304
1591 88 678,586,266 635,192,430 43,393,835 43,393,835
1592
1593 357 Undrground Conduit
1594 T SG 6,371 5,96 407 407
1595 T SG 162,746 152.339 10,407 10,407
1596 T SG 3,108,283 2,909,518 198,767 198,767
1597 88 3,277,400 3,067,819 209,581 209,581
1598
1599 358 Undergrond Conuctors
1600 T SG
1801 T SG 1,018,663 953,522 65,141 65,141
1602 T SG 6,301,423 5,898,463 402,960 402,960
1603 88 7,320,085 6,851,985 468,101 468,101
1604
1605 359 Roads and Trails
1606 T SG 1,897,971 1,776,600 121.370 121,370
1807 T SG 497,979 466,134 31,84 31,84
1608 T SG 9,087,425 8,506,307 581,117 561,117
1609 88 11,483,374 10,749,042 734,332 734,332
1610
1611 TP Uncassifi Trans Plant. Acc 300
1612 T SG 13,753,120 12,873644 879,476 879,476
1613 88 13,753,120 12,873,644 879,476 879,476
1614
1615 TSO Uncassified Trans Sub Plant. Acc 300
1616 T SG
1617 B8
1618
1619 Totl Transmission Plant 88 2,783,179,626 2,605,202,492 177,977,134 7,668,529 185,645,662
1620 Summar of Transmission Plant by Factor
1621 DGP.622 DGU
623 SG 2,783,179,626 2,605,202,492 177,977,134 7,668,529 185,645,662
624 Totl Transmission Plant by Factor 2,783,179,626 2,605,202,492 177,977,134 7,668,529 185,645,662
1625 360 Land and Land Rights
1626 DPW S 45,157,893 43,903,924 1,253,969 1,253,969
1627 B8 45,157,893 43,903,924 1,253,969 1,253,969
1628
1629 361 Strures and Improvements
1630 DPW S 49,196,444 48,399,387 797,057 797,057
1631 B8 49,196,444 48,399,387 797,057 797,057
1632
1633 362 Station Equipment
1634 DPW S 665,332,015 642,551,589 22,780,426 22,780,426
1635 B8 665,332,015 642.551,589 22,780,426 22,780,426
1636
1637 363 Storage Battery Equipment
1638 DPW S 1,457,805 1,457,805
1639 88 1,457.805 1,457,805
1640
1641 36 Poles, Towrs & Fixtures
1642 DPW S 820,538,196 766,677,922 53,860,274 2,953,713 56,813,987
1643 88 820,538,196 766,677,922 53,860,274 2,953,713 56,813,987
184
1645 365 Ovrhead Conductors
1646 DPW S 595,871,504 563,419,932 32,451,572 32,451,572
1647 B8 595,871,504 563,419,932 32,451,572 32,451,572
1648
.
ROLLED-IN Page 9,26
Beginnlnglnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.649 366 Underground Conduit
650 DPW S 261,883,449 255,351,582 6,531,668 6,531,668
1651 B8 261,883,449 255,351,582 6,531,868 6,531.868
1652
1653
1654
1655
1656 367 Undrground Conductors
1657 DPW S 624,968,245 603,524,381 21,443,864 21,443,864
1658 B8 624,968,245 603,524,381 21,443,864 21,443,864
1659
1660 36 Une Transformers
1661 DPW S 939,974,448 880,623.990 59,350,458 59,350,458
1662 B8 939,974,448 880,623,990 59,350,458 59,350,458
1663
166 369 Servces
1665 DPW S 483,572,023 459,755,269 23,816,753 23,816,753
1666 88 483,572,023 459,755,269 23,816,753 23,816,753
1667
1668 370 Meters
1669 DPW S 186,655,233 172,922,996 13,732,238 13,732,238
1670 88 166,655,233 172,922,996 13,732,238 13,732,238
1671
1672 371 Installations on Customers' Premises
1673 DPW S 8,86,929 8,705,243 159,686- -159,686
1674 88 8,864,929 8,705,243 159,686 159,686
1675
1676 372 Lease Propert
16n DPW S 49,658 44,785 4,873 4,873
1678 B8 49,658 44,785 4,873 4,873
1679
1680 373 Strt Lights
1681 DPW S 58,180,189 57,610,017 570,172 570,172
1682 88 58,180,189 57,610,017 570,172 570,172
1683.684 DP Uncssifi Dist Plant. Acc 300
685 DPW S 28,631,530 25,285,133 1,346,397 1,346,397
1686 88 26,631,530 25,285,133 1,346,397 1,346,397
1687
1688 DSO Uncassified Dist Sub Plant - Acc 300
1689 DPW S
1690 88
1691
1692
1693 Totl Distrbution Plant B8 4,768,333,561 4,530,233,954 238,099,607 2,953,713 241,053,320
1694
1695 Summary of Distribution Plant by Factor
1696 S 4,768,333,561 4,530,233,954 238,099,607 2,953,713 241,053,320
1697
1698 Total Distribution Plant by Factor 4,768,333,561 4,530,233.954 238,099,607 2,953,713 241,053,320
.
ROLLED.IN Page 9.27
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.699 389 La and Land Rights
700 G-ITUS S 8,429,002 8,231,363 197,639 197,639
1701 CUST CN 1,128,506 1,082,646 45,860 45,86
1702 G.OGU SG 332 311 21 21
1703 G-5G SG 1,228 1,149 78 78
1704 PT SO 5,598,055 5,264,282 333,n3 333,773
1705 88 15,157,123 14,579,751 577,371 577,371
1706
1707 390 Strres and Improvements
1708 G-ITUS S 104,122,753 94,472,779 9,649,974 9,649,974
1709 G-DGP SG 358,921 335,969 22,952 22,952
1710 G-OGU SG 1,575,372 1,474,631 100,741 100,741
1711 CUST CN 11,928,570 11,443,822 484,748 484,748
1712 G-5G SG 3,852,952 3,60,566 246,386 246,386
1713 PTO SO 103,859,576 97,867,150 6,192,425 6,192,425
1714 B8 225,698,145 209,000,917 16,697,227 16,697,227
1715
1716 391 Off Furnitre & Equipment
1717 G.srrs S 15,431,688 14,440,532 991,155 991,155
1718 G-DGP SG 313,263 293,231 20,032 20,032
1719 G-OGU SG 265,444 248,470 16,974 16,974
1720 CUST CN 6,060,597 5,814,309 246,288 246,288
1721 G-SG SG 5,202,621 4,869,927 332,694 332,694
1722 P SE 160,376 149,812 10,563 10,56
1723 PTO SO 72,507,393 68,184,281 4,323,112 4,323,112
1724 G-G SG 259,952 243,329 16,623 16,623
1725 G-SG SG 10,042 9,399 642 642
1726 88 100,211,376 94,253,291 5,958,085 5,958,085
1727
1728 392 Transporttin Equipment
1729 G-SITUS S 70,161,210 65,325,868 4,835,342 4,835,342
1730 PTO SO 8,887,4n 8,357,579 529,899 529,899
1731 G-SG SG 14,491,858 13,565,141 926,717 (3,124)923,593
1732 CUST CN 9,539 9,152 388 388
1733 G-OGU SG 1,094,538 1,024,545 69,993 69,993.734 P SE 747,710 698,462 49,248 49,248
735 G-OGP SG 160,452 150,191 10,260 10,260
736 G-G SG 354,721 332,038 22,683 22,683
1737 G-DGU SG 52,066 48,736 3,329 3,329
1738 88 95,959,571 89,511,712 6,447,859 (3,124)6,444,735
1739
1740 393 Store Equipment
1741 G-SITUS S 8,851,742 8,227,157 624,585 624,585
1742 G-OGP SG 335,670 314,204 21,465 21,465
1743 G-OGU SG 863,132 620,726 42,406 42,406
1744 PTO SO 494,538 465,052 29,486 29,486
1745 G-SG SG 2,603,966 2,624,659 179,306 179,30
1746 G-OGU SG 106,993 100,151 6,842 6,842
1747 88 13,256,040 12,351,950 904,090 90,090
.
ROLLED-IN Page 9.28
Beginning/Ending
FERC BUS UNAJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.748
749 394 Tools, Shop & Garage Equipment
_ 750 G-ITUS S 30,655,179 29,077,781 1,577,397 1,577,397
1751 G.DGP SG 2,939,080 2,751,134 187,947 187,947
1752 G-SG SG 17,437,638 16,322,546 1,115,092 27,481 1,142,572
1753 PTD SO 4,173,558 3,924,718 248,840 351,015 599,855
1754 P SE 7,106 6,638 468 468
1755 G-DGU SG 4,305,862 4,030,513 275,349 275,349
1756 G-G SG 2,003,148 1,875,052 128,096 128,09
1757 G-G SG 70,469 65,963 4,506 4,506
1758 B8 61,592,041 58,54,345 3,537,695 378,495 3,916,191
1759
1760 395 Laboratory Equipment
1761 G-ITUS S 26,594,275 25,285,64 1,309,211 1,309,211
1762 G-DGP SG 69,613 85,162 4,452 4,452
1763 G-OGU SG 690,785 846,611 44,174 44,174
1784 PTO SO 5,566,385 5,234,500 331,885 331,885
1765 P SE 42,438 39,843 2,795 2,795
1766 G-G SG 5,552,332 5,197,274 355,057 355,57
1767 G-G SG 244,754 229,102 15,651 15,651
1768 G-G SG 110,119 103,077 7,042 7,042
1769 B8 38,870,700 36,800,434 2,070,267 2,070,267
1770
1771 396 Pow Operated Equipment
1772 G-ITUS S 89,014,469 82,429,611 6,584,858 6,584,858
1773 G-DGP SG 1,017,722 952,841 65,081 65,081
1774 G-SG SG 27,240,493 25,498,534 1,741,959 1,741,959
1775 PTO SO 1,772,743 1,667,047 105,696 105,696
1776 G-OGU SG 2,369,618 2,218,087 151,531 151,531
1777 P SE 73,823 68,961 4,862 4,862
1778 P SG
1779 G-SG SG 724,648 678,308 46,339 46,339
1780 B8 122,213,516 113,513,189 8,700,327 8,700,327
1781 397 Communication Equipment
1782 COM_EO S 106,085,949 99,833,157 6,252,792 6,252,792.783 COM_EO SG 5,733,819 5,367,156 36,663 366,663
784 COM_EO SG 10,815,866 10,124,220 691,847 691,647
785 COM_EO SO 47,820,936 44,969,706 2,851,230 2,851,230
1786 COM_EO CN 4,543,876 4,359,224 184,652 184,652
1787 COM_EO SG 60,376,453 56,515,536 3,860,918 3,860,918
1788 COM_EO SE 108,187 101,061 7,126 7,126
1789 COM_EO SG 914,651 856,162 58,490 58,490
1790 COM_EO SG 51,265 47,987 3,278 3,278
1791 B8 236,451,003 222.174,207 14,276,796 14,276,796
1792
1793 398 Misc. Equipment
1794 G-ITUS S 1,133,655 1,072,772 60,883 60,883
1795 G.OGP SG 24,300 22,746 1,554 1,554
1796 G-OGU SG 23,636 22,125 1,511 1,511
1797 CUST CN 189,588 181,884 7,704 7,704
1798 PTD SO 3,108,758 2,923,404 185,354 185,354
1799 P SE 3,531 3,299 233 233
1800 G-SG SG 1,164,094 1,089,653 74,441 74,441
1801 G-SG SG 2,650 2,481 169 169
1802 B8 5,650,213 5,318,364 331,849 331,849
1803
1804 399 Coal Mine
1805 P SE 257,896,236 240,723,168 16,973,068 12,183,099 29,136,167
1806 MP P SE
1807 B8 257,696,236 240,723,168 16,973,068 12,163,099 29,136,167
1808
1809 399L WIOCO Capital Lease
1810 P SE B8
1811
1812
1813 Remove Capitl leases
1814 B8
1815.
ROLLED.IN Page 9,29
BeginningEnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRiP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL.816 1011390 General Capital Leases
817 G-srrs S 7,306,030 7,306,030
818 P SG 12,411,745 11,618,46 793,699 793,899
1619 PTO SO 12,902,451 12,133,167 789,284 769,284
1820 B9 32,820,228 31,057,244 1,562,983 1,562,983
1821
1822 Rennve Capnl Leases (32,820,226)(31,057,244)(1,562,983)(1,562,983)
1823
1824
1825 1011346 Genera Gas Line Capital Leases
1826 P SG
1827 B9
1828
1829 Rennve Capital Leases
1830
1831
1832 GP Unclassified Gen Plant - Acc 300
1833 G-SITUS S
1834 PTD SO 450,243 423,398 26,845 26,845
1835 CUST CN
1836 G-SG SG
1837 G-DGP SG
1838 G-OGU SG
1839 B8 450,243 423,398 26,845 26,845
1840
----~~-_... -----~-_.-
1841 399G Uncassified Gen Plant. Acc 300
1842 G-SITUS S
1843 PTO SO
1844 G-SG SG
1845 G-DGP SG
1846 G.DGU SG
1847 B8
1848
1849 Total General Plant B8 1,173,206,205 1,096,704,726 76,501,480 12,538,471 89,039,950
1850.851 Summary of General Plant by Factor
852 S 467,785,952 435,702,115 32,083,837 32,08,837
1853 DGP
1854 DGU
1855 SG 188,198,282 176,183,489 12,034,793 24,357 12,059,150
1856 SO 267,142,113 251,214,284 15,927,829 351,015 16,278,84
1857 SE 258,839,407 241,791,04 17,048,363 12,163,099 29,211,462
1858 CN 23,86,817 22,891,037 969,840 969,840
1859 DEU
1860 SSGCT
1861 SSGCH
1862 Less Capital Leases 32,620,228)31,057,244)1,582,983)
1863 Total General Plant by Factor 1,173,2 8, 05 1,0 ,704,726 76,501,480
1884 301 Organization
1865 I-ITUS S
1866 PTD SO
1887 I-SG SG
1868 B8
1869 302 Franchise & Consent
1870 I-ITUS S 1,000,000 1,000,000 1,000,000
1871 I-G SG 2,945,256 2,756,915 188,342 1,198,597 1,386,938
1872 I.SG SG 62,829,189 58,811,425 4,017,764 4,017,784
1873 I-SG SG 9,471,942 8,866,236 605,706 805,706
1874 I-DGP SG 1,422,439 1,331,478 90,961 90,961
1875 l-DGU SG 840,289 599,344 40,945 40,945
1876 B8 78,309,116 72,365,398 5,943,718 1,198,597 7,142,315
1877
.
ROlLED.IN Page 9.30
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.878 303 Misllaneous Intangibie Plant
879 i-rrs S 1,533,253 1,140,872 392,381 392,381
880 I-SG SG 61,669,612 57,726,000 3,943,612 3,943,612
1881 PTO SO 383,450,837 360,588,326 22,862,511 (70,936)22,791,574
1882 P SE 2,873,331 2,684,080 189,251 189,251
1883 CUST CN 107,447,682 103,081,270 4,36,412 4,366,412
1884 P SG 34,575 322,541 22,035 22,035
1885 I.DGP SG
1866 88 557,319,289 525,543,088 31,776,201 (70,936)31,705,265
1887 303 Less Non-Utility Plant
1888 I-SITUS S
1889 557,319,289 525,543,088 31,776,201 (70,936)31,705,265
1890 IP Unclassified Intangible Plant. Ace 300
1891 I.SITUS S
1892 I-SG SG
1893 I.DGU SG
1894 PTO SO
1895
1896
1897 Totl Intangible Plant B8 635,628,405 597,908,486 37,719,919 1,127,660 38,847,579
1898
1899 Summary of Intangible Plant by Factor
1900 S 2,533,253 1,140,872 1,392,381 1,392,381
1901 DGP
1902 DGU --~'-----~
1903 SG 139,323,303 130,413,938 8,909,365 1,198,597 10,107,962
1904 SO 383,450,837 360,588,326 22,862,511 (70,938)22,791,574
1905 CN 107,447,682 103,081,270 4,36,412 4,36,412
190 SSGCT
1907 SSGCH
190 SE 2,873,331 2,68,080 189,251 .189,251
1909 Total Intangible Plant by Factor 635,628,405 597,908.486 37,719,919 1,127,660 36,647,579
1910 Summary of Unclassified Plant (Accnt 106)
1911 DP 26,631,530 25,285,133 1,346,397 1,34,397
1912 DSO.913 GP 450,243 423,398 26,845 26,845
914 HP
915 NP
1916 OP
1917 TP 13,753,120 12,873,644 879,476 879,476
1918 TSO
1919 IP
1920 MP
1921 SP 3,484,353 3,242,816 221,536 221,536
1922 Total Unclssified Plant by Factor 44,299,245 41,824,991 2,474,254 2,474,254
1923
1924 Total Electr Plant In Service B8 15,787,158,656 14,846,44,228 941,314,428 61,904,196 1,009,218,624
.
ROLLED.IN Page 9.31
Belnnlnglndlng
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.925 Summary of Elecc Plant by Factor
926 S 5,238,652,766 4,967,076,941 271,575,825 2,953,713 274,529,538
927 SE 261,712,737 244,475,124 17,237,814 12,163,099 29,400,713
1928 DGU
1929 DGP
1930 SG 9,538,112,070 8,928,174,490 609,937,580 52,507,305 662,44,885
1931 SO 650,592,949 811,802,609 38,790,340 280,078 39,070,419
1932 eN 131,308,359 125,972,307 5,336,051 5,336,051
1933 DEU
1934 SSGCH
1935 SSGCT
1936 Less Capitl Leases 32,620,226)
1937 8,656
1938 105 Plant Held For Future Use
1939 DPW S 1,375,461 1,375,461
1940 P SNPPS
1941 T SNPT 6,677,614 6,250,597 427,016 (427,016)
1942 P SNPP
194 P SE 476,507 445,122 31,385 (31,385)
194 G SNPG
1945
194
1947 Totl Plant Held For Futre Use B10 8,529,582 8,071,181 45,401 (458,401)
1948
1949 114 Elecc Plant Acquisition Adjustments
1950 P S
1951 P SG 142,633,069 133,512,053 9,121,016 9,121,016
1952 P SG 14,560,711 13,629,591 931,120 931,120
1953 Total Elecc Plant Acquisition Adjustment B15 157,193,780 147,141,644 10,052,135 10,052,135
1954
1955 115 Accm Proision for Asset Acquisition Adjustments
1956 P S
1957 P SG (4,607,856)(4,607,856)
1958 P SG 676,023)676.023)
1959 815 5,283,878),28 ,878)
.960
961 120 Nuclear Fuel
1962 P SE
1963 Totl Nuclear Fuel B15
196
1965 124 Weathertion
196 DMSC S 5,072,805 5,032,634 40,171 40,171
1967 DMSC SO ~2,463)(2,316)(147)(147)
1968 816 5,0 0,342 5,030,318 40,024 40,024
1969
1970 182W Weathenation
1971 DMSC S 6,751,640 659,758 6,091,882 6,091,882
1972 DMSC SG
1973 DMSC SG
1974 DMSC SO ..
1975 816 6,751,640 659.758 6,091,882 6,091,882
1976
1977 186W Weatherization
1978 DMSC S
1979 DMSC CN
1980 DMSC CNP
1981 DMSC SG
1982 DMSC SO
1983 816
1984
1985 Totl Weatherization B16 11,821,982 5,690,076 6,131,906 6,131,906
.
ROLLED.IN Page 9.32
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL~9~
987 151 Fuel Stok
1988 P DEU
1989 P SE 85,712,130 80,066,732 5,645,398 1,070,604 6,716,002
1990 P SE
1991 P SE 4,570,393 4,269,365 301,027 301,027
1992 Totl Fuel Stock B13 90,282,522 84,336,097 5,946,425 1,070,604 7,017,029
1993
1994 152 Fuel Stok. Undistrbuted
1995 P SE
1996
1997
1998 25316 00& T Woring Capital Deposit
1999 P SE (398,00)(371,788)(26,214)(26,214)
200 813 (398,000)(371,786)(26,214)(26,214)
2001
2002 25317 DG& T Woring Capital Deposit
2003 P SE (1,398,721)(1,306,594)(92,126)(92,126)
2004 813 (1,398,721)(1,306,594)(92,126)(92,126)
2005
200 25319 Provo Woring Capitl Deposit
2007 P SE
2008
2009
2010 Total Fuel Stoc 813 88;485,802 82,657,717 5,828,085 . -1 ,070,604--. 6;898;689-
2011 154 Materals and Supplies
2012 MSS S 70,04,166 65,887,854 4,156,312 4,156,312
2013 MSS SG 1,854,615 1,736,017 118,598 118,598
2014 MSS SE 3,861,454 3,607,121 254,333 254,333
2015 MSS SO 124,020 116,626 7,394 7,394
2016 MSS SNPPS 68,638,749 64,249,479 4,389,270 4,369,270
2017 MSS SNPPH (21,081)(19,733)(1,348)(1,348)
2018 MSS SNPD (4,610,980)(4,398,372)(212,608)(212,80)
2019 MSS SNPT
2020 MSS SG~~1 MSS SG
022 MSS SNPPS
. 2023 MSS SNPP
2024 MSS SNPPS
2025 Totl Materials and Supplies B13 139,890,944 131,178,992 8,711,952 8,711,952
2026
2027 163 Sto Expense Undistrbuted
2028 MSS SO
2029
2030 813
2031
2032 25318 Proo Woring Capital Deposit
2033 MSS SNPPS (273,000)(255,542)(17,458)(17,458)
2034
2035 813 (273,000)(255,542)(17,458)(17,458)
2036
2037 Totl Materials & Supplies 813 139,617,944 130,923,450 8,694,494 8,894,494
2038
2039 165 Prepayments
2040 DMSC S 2,901,782 2,737,400 164,382 164,382
2041 GP GPS 8,255,999 7,763,751 492,248 492,248
2042 PT SG 3,874,108 3,626,369 247,739 247,739
203 P SE 3,238,141 3,24,862 213,279 213,279
2044 PTD SO 18,992,151 17,859,781 1,132,370 1,132,370
2045 Totl Prepayments B15 37,262,181 35,012,163 2,2ŠÖ,018 2,250,018
204
.
.047
048
049
2050
2051
2052
2053
2054
2055
2056
2057
2058
2059
2060
2061
2062
2063
206
2065206
2067
2068
2069
2070
2071
2072
2073
2074
2075
2076
2077
2078
2079
2080
2081.082
083
084
2085
2086
2087
2088
2089
2090
2091
2092
2093
2094
2095
2096
2097
2098
2099
2100
2101
2102
2103
2104
2105
2106
.
ROLLED.IN
Beginning/Ending
FERC
ACCT
182M
BUS
DESCRIP FUNC
Mise Regulatory AsselS
DDS2
DEFSG
P
DEFSG
P
P
DDS02
186M Mise Deferrd Debits
LABOR
P
P
DEFSG
LABOR
P
P
GP
Totl Mise, Deferred Debits
Working Capital
CWC Cash Working Capital
CWC
CWC
CWC
OWC
131
135
141
143
232
232
232
232
2533
2533
230
230
254105
254105
2533
Otr Wor Cl.CU GP
Wo Fun GP
No Rlivibl GP
OlAiR GPAl PTAl PTDAl PAl T
0C -. Of. Cnl. P
0C-' Of. Cn. P
_Rtl.Ob P
_ Rtl. 0b. P
AARegLJ P
AA ROl Uo Pe-R_P
FACTOR
S
SG
SGCT
SG
SE
SG
SO
S
SG
SG
SG
SO
SE
SNPPS
EXCTA)
S
SO
SE
SNP
SG
SO
SO
S
SO
SE
SG
S
SE
SE
S
S
SE
SE
Totl Working Capil
Miscllaneos Rate Base
18221 Unre Plant & Reg Study CoslSP S
18222 Nucar Plant - Troan
P
P
P
S
TROJP
TROJD
Ref
UNADJUSTED RESULTSTOTAL OTHER
51,94,280
3,546,418
11,317,786
°
B11
6,550,280
73,362,764
390,548
1,415,300
4,270,905
35,922,452
196,247
6,941,114
B11 47,330,718
53,061,003
52,252,361
3,319,634
10,591,189
6,159,732
72,322,915
4,270,905
33,625,304
184,54
6,483,940
44,564,696
50,525,279
IDAHO
(304,080)
226,784
726,597
o
390,548
1,039,849
2,297,148
11,701
457,174
2,766,023
2,535,724
Page 9.33
IDAHO
ADJUSTMENT ADJ TOTAL
o
6,759
368,692
375,451
806,161
(297,321)
595,477
726,597
o
2,297,148
11,701
457,174
-
2,766,023
3,341,885
3,341,885B1453,061,003
22,999,473
2,691
918,460
16,607,230
(1,278,895)
(1,216,083)
2
(5,605,322)
(2,401,443)
(30,363)
(437,406)
50,525,279
21,659,823
2,519
863,699
15,617,056
(1,202,644)
(1,135,986)2
(5,236,130)
(2,243,273)
(30,363)
(408,596)
2,535,724
1,339,650
172
54,761
990,174
(76,252)
(80,097)
o
(369,192)
(158,170)
(28,810)
806,161
(1,339,650)o
172
54,761
99,174
(76,252)
(80,097)
o
(369,192)
(158,170)
(28,810)
B14 29,558,343
3,674,472B1482,619,346
27,886,107
78,411,385
1,672,237
4,207,961
(1,339,650)
(533,489)
332,587
B15
B15
(1,231,660)
2,938,099
4,287,665
5,994,104
(1,231,660)
2,749,359
4,012,011
5,529,710
188,740
275,654
464,394
168,740
275,654
464,394
ROLLED.IN Page 9.34
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.107
108 1869 Mise Deferd Debits-Trojan
2109 P 5
2110 P 5NPPN
2111 B15
2112
2113 Totl Miscellaneous Rate Base 815 5,994,104 5,529,710 46,394 464,394
2114
2115 Totl Rate Base Additons 815 569,589,712 532,980,324 36,609,389 45,164 37,063,553
2116 235 Customer Serice Deposits
2117 CU5T 5
2118 CU5T CN
2119 Totl Customer Service Deposits 815
2120
2121 2281 Prop Ins PTD SO (709,335)(667,042)(42,293)(42,293)
2122 2282 In¡&Dam PTD SO (4,671,915)(4,393,361)(278,54)(276,554)
2123 2283 Pen & Ben PTD SO (41,762,931)(39,272,897)(2,490,034)(2,490,034)
2124 2283 Pen & Ben PTD 5
2125 254 In5 Prov PTD 50 66,573)
2126 B15 2,8 ,3)
2127
2128 22844 Accm Hydro Relicensing Obligation
2129 P 5
2130 P 5G
2131 B15
2132
2133 22842 prv.Troan P TROJD (2,526,679)(2,384,239)(162,440)(162,440)
2134 230 ARO P TROJP (2,325,760)(2,176,356)(149,404)(149,404)
2135 254105 ARO P TROJP (849,801)(795,211)(54,590)(54,590)
2136 254 P 5 125,999 125,999 .-
2137 B15 (5,576,241)(5,209,807)(366,434)(366,434)
2138
2139 252 Customer Advances for Construction
2140 DPW 5 (11,982,333)(11,956,287)(26,046)(62,170)(88,217)
2141 DPW 5E.142 T 5G (1 ,n1 ,936) (1,658,626)(113,311)(183,472)(296,783)
143 DPW SO
2144 CUST CN 153,983)6,523 6,523 °
2145 Totl Customer Advances for Constrction B19 1 , 68,896 , 80)9,1 0), 99)
2146
2147 25398 502 Emissions
2148 P 5E 12,350,872)12,350,872)
2149 B19 2,350,872)2,350,872)
2150
2151 25399 Other Deferred Credits
2152 P 5 (5,101,539)(77,471)
2153 LABOR SO (798,561)(960,483)(1,008,095)
2154 P SG (13,676,816)(874,597)
2155 P 5E 3,080,207)202,877)
2156 B19 ,6 ,122), 63,040)
.
ROLLED-IN Page 9.35
BeInnIng/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT OESCR(P FUNC FACTOR Ref TOTAL OTHeR IDAHO ADJUSTMENT ADJTOTAL
em158 190 Accmulated Deferred Income Taxes
159 P S 10,233,594 9,875,889 357,705 (166,075)191,630
2160 CUST CN 124,106 119,063 5,043 5,043
2161 LABOR SO 71,280,601 67,030,634 4,249,967 (58,878)4,191,089
2162 P DGP 1,587 1,587
2163 CUST SADDEBT 3,783,186 3,646,694 136,492 136,492
2164 P TROJD 7,466 6,986 480 480
2165 P SG 23,715,219 22,198,693 1,516,527 1,516,527
2166 P se 14,306,239 13,363,96 942,275 892,158 1,834,433
2167 PTD SNP 10,657 10,37 621 621
2168 OPW SNPD 758,586 723,609 34,978 34,978
2169 P SSGCT 1,252,667 1,160,302 92,365 92,365
2170 Totl Accum Deferred Income Taxes B19 125,473,911 118,137,457 7,336,454 667,205 8,003,659
2171
2172 281 Acmulated Deferr Income Taxes
2173 P S
2174 PT OGP (150,087)(150,087)
2175 T SNPT
2176 B19 (150,087)(150,087)
2177
2178 282 Acmulated Deferred Income Taxes
2179 GP S (2,761,061)(2,506,527)(254,534)(254,534)
2160 ACCMDIT DITSAL (1,278,405,455)(1,194,550,780)(83,854,675)(1,429,525)(85,264,200)
2181 PT OGP
2182 LABOR SO (14,44,370)(13,583,153)(661,218)(861,218)
2183 PTO SNP
2164 P SE (11,511,381)(10,753,188)(758,193)(758,193)
2185 P SG 1,557,280 1,457,696 99,584 43,737 143,321
2166 B19 (1.305,564,986)(1,219,935,951)(85,629,035)(1,385,788)(87,014,823)
2187
2188 283 Acmulated Deferr Incme Taxes
2189 GP S (33,186,298)(32,781,705)(404,593)(404,593)
2190 P SG (8,736,115)(8, 1 n,463) (558,652)(254,679)(813,331)
2191 P se (14,204,598)(13,269,018)(935,581)(935,581).192 LABOR SO (4,572,640)(4,300,005)(272,635)(272,635)
193 GP GPS (21,483,987)(20,203,04)(1,280,941)(1,280,941 )
194 PTO SNP (8,826,525)(8,312,406)(514,118)(514,118)
2195 P TROJO (110,766)(103,645)(7,121)(7,121)
2196 P SG
2197 P SG (3,085,875)(2,888,541)(197,334)(197,334)
2198 P SG
2199 B19 (94,206,804)(90,035,829)(4,170,975)(254,679)(4,425.653)
2200
2201 Totl Accum Deferr Income Tax B19 (1,274,447,966)(1,191,984,410)(82,463,556)(973,262)(83,436,818)
2202 255 Acmulated Investment Tax Creit
2203 PTO S
2204 PTD ITC64 (3,199,757)(3,199,757)
2205 PTO ITC85 (4,741,072)(4,741,072)
2206 PTO ITC86 (2,096,319)(2,096,319)
2207 PTO ITC88 (296,316)(296.316)
2208 PTO ITC89 (634,042)(634,042)
2209 PTD ITC90 (387,846)(333,619)(54,227)(54,227)
2210 PTO IBT 96,296)
2211 Totl Accumlated fTC B19 150,3)
2212
2213 Totl Rate Base Deductions (1.376,212,194)(1,289,102,088)(87,110,106)(4,620,033)(91,730,139)
2214
.
ROLLED.JN Page 9,36
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
.215
2216
2211 108SP Steam Pro Plant Accumulated Der
2218 P S
2219 P SG (831,394,016)(183,844,836)(53,549,180)(53,549,180)
2220 P SG (911,904,525)(853,590,591 )(58,313,934)(58,313,934)
2221 P SG (449,860,467)(421,093,054)(28,767,413)1,387,079 (27,380,334)
2222 P SG (215,424,115)(201,648,300)(13,775,815)(13,775,815)
2223 817 (2,414,583,122)(2,260,176,781)(154,406,341 )1,387,079 (153,019,262)
2224
2225 108NP Nucear Pro Plant Accmulated Depr
222 P SG
2227 P SG
2228 P SG
2229 817
2230
2231
2232 108HP Hyraulic Pro Plant Accum Depr
2233 P S
2234 P SG (147,514,849)(138,081,656)(9,433,193)(9,433,193)
2235 P SG (27,395,647)(25,643,953)(1,751,893)(1,751,893)
2236 P SG (48,993,812)(43,988,680)(3,005,133)153,085 (2,852,048)
2237 P SG (10,016,317)(9,375,800)(640,518)(640,518)
2238 817 (231,920,825ì (217,090,088)(14,830,736)153,085 (14,677,652)
2239
2240 1080P Oter Prouction Plant. Accm Depr
2241 P S
2242 P SG (1,943,487)(1,819,206)(124,281)(124,281)
2243 P SG
2244 P SG (14,94,987)(10,152,449)(4,792,538)(542,414)(5,334,952)
2245 P SG (14,501,527)(13,574,192)(927,335)(927,335)
2246 817 (91,390,001 ì (85,545,847)(5,844,154)(542,414)(6,386,568)
2247
2248 108EP Exrimental Plant. Accm Depr"249 P SG
250 P SG
251
2252
2253 Total Prouction Plant Accum Depreciation B17 (2.737,893,948)(2,562,812,717)(175,081,232)997,749 (174,083,482)
2254
2255 Summary of Pro Plant Depreiation by Factor
2256 S
2257 DGP
2258 DGU
2259 SG (2,737,893,948)(2,562,812,717)(175,081,232)997,749 (174,083,482)
2260 SSGCH
2261 SSGCT ...-
2262 Total of Pro Plant Deprecation by Factor (2,737,893,948)(2,562,812,717)(175,081,232)997,749 (174,083,482)
2263
2264
2265 108TP Transmission Plant Accmulated Depr22TSG
2267 T SG
2268 T SG
2269 Totl Trans Plant Accum Depreciation B17
.
.270
271
2272
2273
2274
2275
2276
2277
227&
2279
2280
2281
2282
2283
2284
2285
2286
2287
2288
2289
229
2291
2292
223
2294
2295
2296
2297
2296
2299
2300
2301
2302
2303
2304.305
306
2307
2308
2309
2310
2311
2312
2313
2314
2315
2316
2317
2318
2319
2320
2321
2322
2323
2324
2325
2326
2327
2328
2329
2330
2331
2332
2333
233
2335
2338
2337
2338
2339
.. 340
341
2342233
234
2345
2346
ROLLED-IN
Beginning/Ending
FERC
ACCT
108360
BUS
DESCRIP FUNC
Lad and Land Rights
DPW
FACTOR
S
108361 Stures and ImprovementsDPW S
108362 Stati EquipmentDPW S
108363 Storge Battery EquipmentDPW S
10838 Pols, Towrs & FixresDPW S
108365 Overhd ConducorsDPW S
108368 Undergrond ConduitDPW S
108367 Undergrond ConductrsDPW S
108368 Line TransfoersDPW S
108369 Services DPW S
108370 Meters DPW S
108371 Installations on Customers' PremisesDPW S
108372 Lease PropertDPW S
108373 Strt Lights DPW S
10800 Unclassified Dist Plant. Ace 300DPW S
108DS Unclassified Dist Sub Plant. Ace 300DPW S
108DP Unclassifed Dist Sub Plant. Ace 300DPW S
Total Distrbuton Plant Accum Depreciation
Summary of Distrbuton Plant Depr by Factor
S
Total Distribution Depreation by Factor
Ref
UNADJUSTED RESULTSTOTAL OTHER
817 15,276,092)5,276,092Î
817
(15,722,519)
(15,722,519)
817
(168,215,913)
(168,215,913)
817
(413,993)
(413,993)
817
(429,399,408)
(429,399,408Î
817
(243,480,744)
1243,480,744)
817 f09,395,401)109,395,401)
817
(22,125,886)
(226,125,886)
B17
(349,591,323)
(349,591,323)
817
(145,434,084)
1145,434,084)
817
(82,548,535)
(82,548,535)
817 15,894,862)5,894,862)
817
(41,533)
141,533)
817
(20,482,590)
(20,482,590)
(5,058,312)
15,058,312)
(15,188,692)
(15,188,692)
(160,713,306)
1160,713,306)
(413,993)
(413,993)
(405,299,222)
1405,299,222)
(231,527,196)
1231,527,196)
(108,175,695)
1106,17,695)
(215,663,117)
1215,663,117)
(322,815,426)
1322,815,426)
(134,832,353)
1134,832,353)
(76,998,945)
176,998,945)
(5,757,901)
15,757,901)
(36,825)
(36,825)
(20,215,990)
(20,215,990)
Pag 9.37
IDAHO
IDAHO
ADJUSTMENT ADJ TOTAL
(217,780)
(217,780)
(217,780)
(217,780)
(533,827)
(533,827)
(533,827)
(533,827)
(7,502,607)
(7,502,607)
(7,502,607)
(7,502,607)
(24,100,186)
(24,100,186)
118,887
118,887
(23,981,299)
(23,981,299)
(11,953,548)
(11,953,548)
(11,953,548)
(11,953,548)
(3,219,705)
(3,219,705)
(3,219,705)
(3,219,705)
(10,462,769)
(10,462,769)
(10,462,769)
(10,462,769)
(26,775,897)
(26,775,897)
(26,775,897)
(26,775,897)
(10,601,731)
(10,601,731)
(10,601,731)
(10,601,731 )
(5,549,590)
(5,549,590)
(5,549,590)
(5,549,590)
(136,962)
(136,962)
(136,962)
(136,962)
(4,708)
(4,708)
(4,708)
(4,708)
(266,600)
(266,600)
(266,600)
(266,600)
817
817
817
B17 (1,802,022,882)
817
(1,802,022,882)
(1,802,022,882)
(1,700,696,971)
(1,700,696,971)
(1,700,696,971)
(101,325,911)118,887 (101,207,024)
(101,325,911)
(101,325,911)
118,887
118,887
(101,207,024)
(101,207,024)
ROLLED-IN
Page 9.38
Beginnlnglnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
.347 108GP General Plant Accumulated Depr
348 G-ITUS S (146,543,987)(134,712,504)(11,831,483)44,593 (11,786,890)
349 G-DGP SG (8,043,401 )(7,529,048)(514,355)(514,355)
2350 G-DGU SG (15,450,484)(14,462,465)(988,018)(988,018)
2351 G-G SG (40,139,148)(37,572,353)(2,566,795)16,928 (2,549,866)
2352 CUST CN (5,920,313)(5,679,726)(240,587)1,413 (239,174)
2353 PTD SO (89,871,749)(84,513,320)(5,358,428)13,861 (5,34,567)
235 P sE (478,024)(448,539)(31,485)20 (31,465)
2355 G-SG SG (56,469)(52,858)(3.611)(3,611)
2356 G.SG SG (2,771,824)(2,594,573)(1n,251)(177251)
2357 817 (309,275,399)(287,563,385)(21,712.013)76,815 (21,635,198)
2358
2359
2360 108MP Mining Plant Accmulated Depr.
2361 P S
2362 P SE (154,578,471 )(144,397,217)(10,181,254)(1.303)(10,182,558)
2363 817 (154,578,471)(144,397,217)(10,181,254)(1,303)(10,182,558)
23 10SMP les Centrlia Situs Depreciation
2365 P S
236 817 (154,578,471)(144,397,217)(10,181,254)(1,303)(10,182,558)
2367
2368 1081390 Accm Depr. Caplllease
2369 PTD SO 817
2370
2371
2372 Remove Capital leases
2373 817
2374
2375 1081399 Accum Depr . Capltllease
2376 P S
2377 P SE 817
2378
2379
2380 Remove Capital leases .381 817
382
383
2384 Total General Plant Accum Depreciation B17 463,853,870)431,960,602)31,893,268)75,512 31,817,756)
2385
2386
2387
2388 Summary of General Depreiation by Factor
2389 S (148,543,987)(134,712.504)(11,831,483)44,593 (11,786,890)
2390 DGP
2391 DGU
2392 SE (155,056,496)(144,843,756)(10,212,739)(1,284)(10,214,023)
2393 SO (89,871,749)(84,513,320)(5,358,428)13,861 (5,34,567)
2394 CN (5,920,313)(5,679,726)(240,587)1,413 (239,174)
2395 SG (66,461,325)(62,211,295)(4,250,030)16,928 (4,233,101)
2396 DEU
2397 SSGCT
2398 SSGCH
2399 Remove Capital leases
-
2400 Total General Depreiation by Factor (463,853,870)(431.960,602)(31,893,268)75,512 (31,817,756)
2401
2402
2403 Total Accum Depreciation. Plant In Service B17 6,053,908,945)5,678,45,912)375,454,033)1,208,642 374,245,391)
2404 111SP Acm Prov for Amort-Steam
2405 P SG
2406 P SG 30,486 30,486)
2407 818 0,486)0.46)
2408
2409
2410 111GP Accm Prav for Amort.General
2411 G-ITUS S (16,629,267)(16,629,267)
2412 CUST CN (1,862,80)(1,787,104)(75,700)(75,700)
2413 J-SG SG (547,837)(512,804)(35,033)(35,033)
2414 PT SO (6,311,685)(5,935,363)(376,322)(376,322)
2415 P SE
-
.416 818 (25,351,593)(24.864.538)(487,055)(487.055)
417
ROLLED-IN
Page 9.39
Beinnlnglnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL.18
19 111HP Accm Prov fo Amor-Hydro
420 P SG (34,575)(322,541)(22,035)(22,035)
2421 P SG
2422 P SG (3,017)(2,824)(193)(193)
2423 P SG ~292,800)
t274,076)
(18,724)(18,724)
2424 818 (40,951)(40.951)640,392)599,441Ì
2425
2426
2427 1111P Accm Prov fo Amor.lntangible Plant
2428 I-SITUS S (715,816)(30,784)(665,032)(685,032)
2429 I-DGP SG (1,422,439)(1,331,478)(90,961)(90,961)
2430 I-U SG (310,163)(290,329)(19,634)(19,834)
2431 P SE (790,384)(738,326)(52,058)(52,058)
2432 I-G SG (29,988,205)(28,070,537)(1,917,668)89,456 (1,628,212)
2433 I-G SG (10,850,007)(10,156,177)(693,830)(693,830)
2434 I-SG SG (2,568,044)(2,403,824)(164,220)(164,220)
2435 CUST eN (7,207,762)(74,070,227)(3,137,535)(3,137,535)
2436 P SG
2437 P SG (17,091)(15,998)(1,093)(1,093)
2438 PTD SO (241,083,157)(226,709,042)(14,374,115)15,254 (14,358,860)
2439 818 (364,953,068)(343,816,721)(21,136,347)104,710 (21,031,636)
2440 1111P Less NonUtility Plant
2441 NUTIL OTH -
2442 (364,953,068)(343,816,721)(21,136,347)104,710 (21,031,636)
2443
244 111390 Accm Amtr - Capitl Lease
2445 G-ITUS S
2446 P SG
2447 PTD SO
2448
2449
2450 Remoe ClpRI! L.... Amlr
2451
2452 Totl Accum Provision for Amortzation B18 (391,421,787)(369,726,948)(21,694,838)104,710 (21,590,128)
.453
454
2455
2456
2457 Summry of Amorttion by Facor
2458 S (17,345,083)(16,66,051)(685,032)(685,032)
2459 DGP
2460 DGU
2461 SE (790,384)(738,326)(52,058)(52,058)
2462 SO (247,394,842)(232,64,405)(14,750,437)15,254 (14,735,182)
2463 CN (79,070,566)(75,857,331)(3,213,235)(3,213,235)
246 SSGCT
2465 SSGCH
246 SG (46,820,912)(43,826,836)(2,994,076)89,456 (2,904,620)
2467 Less Capital Lease
2468 Totl Provision For Amorttion by Factor (391,421,787)(369,726,948)(21,694,838)104,710 (21.590,128)
.
.
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.RockY Moulntln Powe
Sa Anual
Dember 2007
COIIDENTAL PEAS
MoJan7FÐ-7
Mar-l7
Af-l7Ma7Ju7
Jui07/I7Se70c7N07Da7
MoJa7FÐ-7Ma-l7
Af-l7
May-7Jun7Ju7
Au07Se70c7N07Da7
Day
16
2
1
30
31
20
10
14
4
31
28
11
Day
18
2
1
30
31
20
10
14
4
31
28
11
.Mont Da TI
Jan7 16 80
FÐ-7 2 80
Ma-l7 1 190
Af-l7 30 150
Ma7 31 1700Ju7201700Ju7101700/I7 14 1700
Sap7 4 1800c73180N0728180Da711180
MoJan7FÐ-7
Mar-l7
Af-l7May7Jun7JIJ7Au7
Sep-070c7
No-l7Da7
Day
16
2
1
30
31
20
10
14
4
31
28
11
Mon Da Time
Jan-7 16 80
FÐ-7 2 800
Mar-l7 1 190
Af-l7 30 150
May-7 31 1700.Ju07 20 1700
JIJ7 10 1700
Au7 14 1700
Se7 4 1600c73180
No-l7 28 1800Da711180
Tim8080
190
150
1700
1700
1700
170018080
180180
I .METERED LOADS ICP .
.NonERC FERC ,
CA OR WA E.WY ToIlUT 10 W.WY UT NETUT Totl
178 2,84 789 1,02 3,228 430 152 28 3,20 8,84
163 2,68 793 1,04 3,137 46 149 25 3,112 8,433
160 2,311 641 1.027 3,139 387 144 27 3,112 7,80
125 1,748 470 915 3,197 451 131 31 3,166 7,037
150 2,150 631 884 3.209 643 127 30 3,179 7,80
159 2,163 678 981 4,123 84 136 40 4,08 8,887
160 2,60 754 98 4,424 701 141 43 4,381 9,775
165 2,310 707 1,00 4,473 60 138 43 4,429 9,40
129 1,86 628 1,018 3,99 50 124 37 3,959 8,254
131 2,181 69 90 2,723 370 143 23 2,70 7,144
145 2,43 711 1,020 3,475 48 148 29 3.44 8,395
155 2517 782 1,069 3552 433 162 30 3522 8650
1621 27812 8253 11893 42676 8093 1690 38 42,289 100,237
(less)
Time8080
190
150
1700
1700
1700
170018080180180
Aduitmni. for Cunallmenl, Buy- Throuohi ind Lod No Lonoer Served (Reductons to Loidl
I ....NoFERC FERC 1
CA OR WA E.WY UT 10 W.WY UT NETUT Tota
....
-...
....
....
.-..
(891 -(S1 (89)
(901 (71)(90)(1601
(881 (71)(81 (159)
(851 (711 181 (156)
....
-(711 .(711
(921 .(8)(92
..--144\263 -.144\17271
equals
I COINCIDENTAL PEAK SERVED FROM COMPANY RESOURCES
I ........ Non-FERC ......FERC
CA OR WA E.WY UT 10 W.WY UT NETUT Total
178 2,84 789 1,02 3,228 43 152 28 3,2 8,84
163 2,68 793 1,04 3.137 482 148 25 3,112 8,43
160 2.311 641 1,027 3,139 387 144 27 3,112 7,80
125 1.748 470 915 3,197 451 131 31 3,168 7,037
150 2,150 631 88 3,209 84 127 30 3.179 7,80
159 2,163 678 981 4,035 84 136 40 3.99 8,798
160 2,60 754 989 4,335 630 141 43 4,29 9,615
165 2,310 707 1.00 4,385 53 136 43 4,341 9,247
129 1,86 82 1,018 3,910 431 124 37 3,87 8.09
131 2.181 69 90 2,723 370 143 23 2.700 7,144
145 2,43 711 1,020 3,475 389 148 29 3,44 8,324
155 2,517 782 1,069 3,48 43 162 30 3,43 8,558
1621 27,812 8253 11893 42.232 5810 1,690 368 4164 99,511
+plus
TI8080
190
150
1700
1700
1700
170016080180180
Adluitm for Ancllarv Seei Contrac1lncludlng Reaervel(Addltlonl to LoadlrNon-FERC FeRC ,
CA OR WA E.WY UT 10 W.WY UT NETUT Tota
...
...
-.-
...
-.-
71 .71
71 .71
71 .71
71 -71
.-.
71 .71
...
-...354 .--354--equals
I LOADS FOR JURISDICTIONAL ALLOCATION (CP).
r NoERC FERC 1
CA OR WA E.WY UT 10 W.WY UT NETUT -Total
178 2,84 789 1,022 3,228 43 152 28 3,200 8,84
163 2,664 793 1,04 3.137 482 149 25 3,112 8,43
160 2,311 641 1,027 3,139 387 144 27 3.112 7,80
125 1,748 470 915 3,197 451 131 31 3.168 7,037
150 2,150 631 88 3,209 643 127 30 3,179 7,80
159 2,163 678 981 4,035 717 136 40 3,99 8,689
160 2,60 754 989 4,335 701 141 43 4,292 9,885
165 2.310 707 1,009 4,385 60 136 43 4,341 9,318
129 1,680 628 1,018 3,910 50 124 37 3,873 8,169
131 2,181 690 90 2,723 370 143 23 2,700 7,144
145 2,438 711 1,020 3,475 48 146 29 3,44 8,395
155 2,517 762 1,069 3,48 43 162 30 3,43 8,558
1,821 27,812 8,253 11893 42232 6164 1690 368 41846 99685
Page 10.12
.
.
-
Rocky Moulntln PowrSaAnnual
Deber 2007
ENERGY
Year Mon207 Jan7207 Feb07207 Mar-C72007 An-C72007 May-72007 Ju7207 JuJ72007 Au7207 Sep72007 0C7207 No'(72007 0f7
Yea Mo2007 Jan-7207 Feb-07207 Mar-072007 An-C72007 Møy72007 J~7207 Ju~72007 Au7207 $ep-72007 Oc-C72007 Nov-72007 De7
Yea207
2007
2007207207
2007
2007
2007
2007
2007
2007
2007
Year Mon2007 Jan-72007 Feb-7
2007 Mar-C72007 An-C72007 Møy7207 J~72007 JuI72007 Au72007 Sep-72007 Oc-C72007 Nov-72007 0f7
Year
2007
2007
2007
2007
2007
2007
207
2007
2007
2007
207
2007
METERED LOADS 'MW
I NoERC .FERC I
CA OR WA E.WY Tot UT 10 W.WY UT NelUT Tot
97,192 1,572,33 461,73 715,08 2,113,473 29,84 99,86 17,410 2,09,06 5,35,631
82,867 1,297,863 371,26 828,943 1,10,68 224,28 89,442 14,498 1,79,190 4,50,716
87,215 1,2,162 353,798 66,825 1,80,20 250,763 84,423 15,679 1,784,528 4,525,392
87,951 1,170,197 324,757 621,206 1,719,957 251,970 90,381 15,43 1,704,524 4,28,420
92,283 1,206,898 311,841 835,787 1,918,429 38,08 93,54 17,398 1,901,031 4,84,841
93,106 1,193,34 34,371 843,991 2,112,03 447,449 92,02 19,402 2,09,631 4,92,318
91,698 1,33,26 411,50 68,659 2,50,08 461,357 97,139 23,38 2,476,721 5,578,70
93,807 1,30,327 38,54 68,158 2,428,152 357,794 84,43 22,94 2,40,206 5,35,017
74,898 1,181,393 358,019 65,342 1,927,54 30,751 86,712 17,370 1,910,170 4,577,652
78,56 1,240,775 38,128 659,33 1,84,702 28,181 98,972 15,753 1,827,949 4,55,654
80,05 1,331,073 391,731 68,287 1,840,814 271,886 99,710 15,46 1,925,35 4,777,æ9
95180 1477040 449310 73688 216580 265087 109411 17869 2146136 5315522
106595 15573692 4532,172 7989310 24280,684 3803,529 1,144,056 212,381 24,068,503 58 368,238
(less)
Adluitmnti for Curtllmenti, Buy.Throghl ind L.d No Longer Served IReductlonl to L.dl
Non-FERC .FERC
CA OR WA E.WY UT 10 W.WY UT NETUT Tota
(5,977 (5,977 (5,977
.-.-
--.
.(2801 .(280)
.(581 .(581
(5,8691 (1,5411 (5,6691 (7,210)
(8,681 (9,3361 (8,680)(16,016)
(7,541 (9,0011 (7,5451 (16,541
(4,331 (4,9161 (4,330)(9,246)
.(4,553).(4,551
.(2,5221 16,Õ13)
(2,5221
(8,0131 (8,6151 (14,629)
....138 2151 .1413241 ..(362151 77 5391
equals
MonJan7Feb7
Mar'(7
An.(7May-7Ju7Ju~7Au7Sep7
0C.07
Nov'(70f7
I LOADS SERVED FROM COMPANY RESOURCES (NPC)
r Non-ERC FERC I
CA OR WA E.WY UT 10 W.WY UT NelUT Tot
97,192 1,572,336 461,73 715,08 2,107,498 29,84 99,86 17,410 2,09,08 5,352,65
82,867 1,297,683 371,628 628,84 1,810,688 224,28 89,442 14,498 1,798,190 4,50,718
97.215 1,26,182 353,798 66,825 1,80,206 250,783 84,423 15,679 1,784,528 4,525,392
87,951 1,170,197 324,757 621,206 1,719,957 251,690 90,361 15,433 1,704,524 4,28,140
92,28 1,2,898 311,841 83,787 1,918,429 367,520 93,54 17,398 1,901,031 4,84,08
93,106 1,193,34 34,371 64,991 2,106,38 44,90 92,020 19,402 2,08,962 4,919,108
91,698 1,33,26 411,50 68,659 2,49,40 452,021 97,139 23,38 2,470.041 5,56,890
93,607 1,30,327 369,543 68,158 2,420,607 348,793 84,436 22,94 2,397,661 5,342,471
74,89 1,181,393 356,019 850,342 1,923,209 29,835 86,712 17,370 1,905,84 4,56,408
78,56 1,240,775 38,128 85,334 1,84,702 28,628 96,972 15,753 1,827,949 4,54,101
60,05 1,331,073 391,731 682,297 1,94,814 28,38 99,710 15,46 1,925,354 4,775,047
95,180 1,477,040 449,310 73,688 2,159,792 276,472 109,411 17,669 2,142,123 5,30,894
106595 15573692 4532,172 7,989310 24244,669 3,762205 1.144,056 212,381 24032,289 58,310,699
+ plus
Aditmenti for Ancllary Servlc.. Contracti Including Riierves (Additons to Loadl
I .NonERC FERC I
~A OR WA E.WY UT 10 W.WY UT NetUT Tot
38 1,295 365 1,68
492 224 492 717
420 229 420 849
26 99 260 1,254
421 1,32 421 1,743
347 4,759 347 5,106
180 13,458 180 13,636
59 12,437 598 13,033
350 5,851 350 8,201
326 6,433 326 6,759
167 2,710 167 2,878
418 9,857 418 10,275
...4,38 59,568 .4,364 63931
= equals
MonthJan7
Feb-7
Mar'(7
An'(7Møy7J~7JuI7Au7Sep-7
Oc.(7
Nov.(7De07
I LOADS FOR JURISDICTIONAL ALLOCATION (MWH)
I Non-FERC FERC -i
CA OR WA E,WY UT 10 W.WY UT UT Totl
97,192 1,572,336 461,736 715,08 2,107,881 30,239 99,86 17,410 2,09,471 5,35,333
82,867 1,297,683 371,628 828,843 1,811,181 224,491 89,442 14,498 1,798,682 4,50,432
97,215 1,260,162 353,798 66,825 1,80,627 250,993 94,423 15,679 1,784,948 4,52,042
87,951 1,170,197 324,757 621,206 1,720,218 252,684 90,361 15,433 1,704,785 4,267,384
92,283 1,206,896 311,641 835,787 1,918,850 38,842 93,54 17,398 1,901,452 4,647,824
93,106 1.193,348 34,371 643,991 2,106,711 450,667 92,020 19,402 2,087,309 4,924,214
91,698 1,333,28 411,50 68,659 2,493,583 465,479 97,139 23,38 2,470,221 5,576,328
93,607 1,309,327 369,543 686,158 2,421,203 361,230 84,436 22,94 2,398,257 5,35,50
74,896 1,181,393 356,019 650,342 1,923,58 301,68 86,712 17,370 1,90,190 4,574,607
78,56 1,240,775 36,128 659,334 1,84,028 267,061 98,972 15,753 1,828,275 4,55,86
80,058 1,331,073 391,731 662,297 1,94,981 272,074 99,710 15,46 1,925,521 4,m,925
95,180 1,477,040 449,310 733,688 2,160,210 286,329 109,411 17,669 2,142,541 5,311,169
106,595 15,573692 4532172 7,989310 24249,033 3,821,773 1,144056 212,381 24,036,652 58374,631
Page 10.13
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.IDAHO
ANAL EMBEDDD COSTS
Decelir-G7AVERAGE BA
Company Owd Hydro. Wet
Account Dellp!on Amount Mw $I Direntlal RatlrenCi
535.54 Hy Opratio & Maintenance Expanse 23,197,411 Pag 2.7, West only
40P Hy Deti Expae 10,847,290 p. 2.15, West on
404IP Hyro R_si Amrtiztion 7,166,254 Pag 2.16, West on
Totl We Hydro Opeting Expen..41,212,955
33.33 Hy Ele PI in Serv 44,143,423 Pag 2.23, west on
30& 182M Hy R_si 11,337,219 p. 2.29, west on
106HP Hy Aced Depreition Reseive (192,155,083)p. 2.36, West only
1111P Hy Relnsin Aclated Resirv (11,416,592)p. 2.39, Wist only
154 Ma" an SUs (21,081)Pag 2.32, wet onl
We Hyro NI RIte BaH 328,887,887
Pl1I Ret 11.33%
Ra _ RenUl Rlquirme 37,028,34
_I Emli_d CotWe Hyro_ Rliourc.i 78,242,297 3,887,521 20.23 (90,001,2~ MW fro GRID
Mid C Contel
Account Deicr!n Amunt Mw $/h Diraial Raterence
55 An Mi Contracts eosts 58,78,542 2,08,90 28.46 (31,061,037) GRID
Gr Rea__ Por (7,90,311)(7,90 311) GRID
50,885,231 (38,961,346)
QuI_ Facilits
Account DIllon Amount Mw SlMwh Dierential Reference
555 lJh Annual QuUfied FaciHties Costs 29,659,623 40,804 74.04 12,232,705
555 Or Annual Quaifed Facllies Coits 44,143,294 389,178 113.43 27,213,423
55 1- Anal Quad Facies Cots 4,101,55 77,028 53,25 750,_
555 W' An Qualied Facities Costs
555 W' AniI Qualifed Ficilities Costs 887,305 11,394 58.7 171,662
55 Ci Ani Qualifoed Faclites Costs 4,097,924 35,502 115.43 2,55,54
555 Wishon Annu Qualifed Ficills Costs 2,191,788 20,339 107.76 1,30,99.Toi Quili Facits Costs 84,661,483 93,04 90.85 44,229,018 GRID
Al otr oenl Rnourcia
(Ex West Hy, MI C, an QF)
Acunt Dnptri Amount Mw SlMwh Rerence
50-514 Steam Opion & Maintenanc Exnse 855,653,611 Pige 2.5
53.54 Eut Hyro Opti & Miinenance Exs.12,258,36 Pag 2,7, Eist only
54.55 Ot Gelio Opration & Maintnance Exse 437,833,05 P.2,8
55 Ot Pused Pow Cocts 1,40,961,872 GRID less QF ind Mi
4010 Renbl En Credi (3,192,244)P.2.20
4118 S0 Emisio _ans (2,53,802)P.2,4
J_ RIr I Ulle Mo Ofset (5,859,9871 Jam Rivr Adj (T1b 51
Gn Til Revnui (5,596,8291 Gre Tag (Tib 3)
403P Sin Depratio Exnse 104,182,052 Pige 2.15
40P East Hy Deatin Exnse 4,312,738 p. 2.15, Ealonl
40P Ot G.ne Depration Exnse 49,478,481 Pag 2.15
403MP Mi Deati Exse 39,573 Pag 2.15
401P Eat Hy Relnsing Amization 327,571 Pag 2,16, EIS only
40 Am 01 Plint Acquiiton Costs 5,478,35 Pag 2,17
Tot All otr Oprating Expensei 2,822,255,805
310.316 stea El Plnt in seic 4,997,562,693 Pag 2.21
33.33 Ee Hy Ele Plnt in Servce 108,nl,112 Page 2.2, Easl only
30 & 166M EIS Hy R_sing 9,581,031 p. 2.29, Easl on
340-34 Ot Ele Plnt in serv 1,55,971,303 P.2.24
399 MI 44,36,371 P1Q2.28
I08P Slea Acllted Deprtio Reseive (2,392,892,191)PIQ2.36
108P Otr o-ra Acmulated Deprcitio Reseive (99,872,1951 P.2,36
108P Ot Acmulated Depreltio Reserv (154,598,258)p. 2.38, Eiat only
108HP East Hy Acmulated Deprltio ReSOle (37,371,827)p. 2.36, East only
1111P East Hy Relinsing Accmuiiled Riseive (2,847,007)p. 2.39, Eaat on
114 El Pl Acisit Adjustment 157,193,780 Pag 2.31
115 AcII Prsio Acisit Adjustmnt (82,828,491)Pag 2.31
151 Fuast 108,537,128 Pag 2.32
253.16.253,19 Join Ow we Depoit (2,069,721)Pile 2.32
253.98 $02 Emili _nces (3,692,484)PIQ2,34
154 M1lrials & Sus 88,838,749 PIQ2.32
154 Eist Hy Materiils & Supplies
ToIl NI RIte Baii 4,842,167,995P_Retu 11.33%
Ra Ba.. RenUl Reqirement 525,857,44._I Embded Coit
Al Ot Geration Resources 3,348,113,249 76,96,188 43.50 MW fr GRID
Tot Annual Embedded Costs 3,562,082,260 83,831,654 42.49
P.10.23
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