20070608McDougal Exhibits Part II.pdf

IDAHO REVISED PROTOCOL Page 8.0 Total
Mise Rate Base Adjustments (Tab 8)
TOTAL
8.4
Customer
Cash Working Trapper Mine Rate Jim Bridger Mine Removal of Environmental Advances for
Total Normalized Capital Base Rate Base Glenrock Mine Settlement Construction
Operating Revenues:
2 General Business Revenues
3 Interdepartmental
4 Special Sales
5 Other Operating Revenues
Total Operating Revenues
Operating Expenses:
9 Steam Production
10 Nuclear Production
11 Hydro Production (19,193)
12 Other Power Supply
13 Transmission
14 Dist~bution
15 Customer Accounting
16 Customer Service & Info
17 Sales
18 Administrative & General
Total O&M Expenses (19 193)
20 Depreciation (44 750)
21 Amortization 876
22 Taxes Other Than Income 691)
23 Income Taxes: Federal 146 825)
State (155 834)
25 Deferred Income Taxes 950 906
26 Investment Tax Credit Adj.
27 Mise Revenue & Expense
Total Operating Expenses:(380 512)
Operating Rev For Return:380 512
Rate Base:
33 Electric Plant In Service 60,023 248 431 740 766 323 (56,035)
34 Plant Held for Future Use (65,464)
35 Mise Deferred Debits 834 634
36 Elec Plant Acq Adj
37 Nuclear Fuel
38 Prepayments
39 Fuel Stock 285,414
40 Material & Supplies
41 Working Capital 115,508 538 111
42 Weatherization Loans
43 Mise Rate Base
Total Electric Plant:193 341 538 111 431 740 766 323 (56 035)
Deductions:
47 Accum Prov For Depree 298 555 64,476
48 Accum Prov For Amort
49 Accum Def Income Tax (735 529)
50 Unamortized ITC
51 Customer Adv For Canst (499 056)(499 056)
52 Customer Service Deposits
53 Miscellaneous Deductions 069 257)069 257)
Total Deductions:005 289)64,476 069 257)(499 056)
Total Rate Base:188,051 538,111 431 740 766 323 441 069 257)(499 058)
60 Estimated ROE impact 282"10 -0.041"10 -0.012%-0.204%000%029%013%
64 TAX CALCULATION:
66 Operating Revenue 758
67 Other Deductions
68 Interest (AFUDC)
69 Interest
70 Schedule "M" Additions 627 487
71 Schedule "M" Deductions 088 723
72 Income Before Tax 432,478)
74 State Income Taxes (155 834)
76 Taxable Income 276 643
78 Federal Income Taxes 146 825)
IDAHO REVISED PROTOCOL Page 8.1 Total
Mise Rate Base Adjustments (Tal
TOTAL
Centralia Powerdale
Transrnission Line Proforma Major Miscellaneous Upper Beaver Cove Hydro Hydroelectric
Sale Piant Additions Rate Base Hydro Sale Decommission Facility
Operating Revenues:
2 General Business Revenues
3 Interdepartmental
4 Special Sales
5 Other Operating Revenues
Total Operating Revenues
Operating Expenses:
9 Steam Production
10 Nuclear Production
11 Hydro Production 716)(121)(14 356)
12 Other Power Supply
13 Transmission
14 Distribution
15 Customer Accounting
16 Customer Service & Info
17 Sales
18 Administrative & General
Total O&M Expenses 716)(121)(14 356)
20 Depreciation (163)015)(2,697)(36 876)
21 Amortization 36,876
22 Taxes Other Than Income (971)(720)
23 Income Taxes: Federal 156 434)575 182 796
State (157 140)486 161 652
25 Deferred Income Taxes 950906
26 Investment Tax Credit Adj.
27 Mise Revenue & Expense
Total Operating Expenses:(101)(362 668)(6,640)196)908)
Operating Rev For Return:101 362,668 640 196 908
Rate Base:
33 Electric Plant In Service 346)52,790,974 (209 005)(87 128)(604 276)
34 Plant Held for Future Use (65,464)
35 Mise Deferred Debits 230,358 604276
36 Elec Plant Acq Adj
37 Nuclear Fuel
38 Prepayments
39 Fuel Stock 285,414
40 Material & Supplies
41 Working Capital (422 603)
42 Weatherization Loans
43 Mise Rate Base
Total Electric Plant:(9,346)790974 027 706 (209005)(87 128)(0)
Deductions:
47 Accum Prov For Depree 286 102 858 125,935
48 Accum Prov For Amort
49 Accum Def Income Tax 262 (735 792)
50 Unamortized ITC
51 Customer Adv For Canst
52 Customer Service Deposits
53 Miscellaneous Deductions
Total Deductions:548 (735,792)102 858 125,935
Total Rate Base:798)055 182 027 706 (106 147)808 (0)
60 Estimated ROE impact 000%095%-0.027%006%000%004%000%
64 TAX CALCULATION:
66 Operating Revenue 163 701 536 356
67 Other Deductions
68 Interest (AFUDC)
69 Interest
70 Schedule "M" Additions 627,487
71 Schedule "M" Deductions 088 723
72 Income Before Tax 163 (3,461 236)701 538 356
74 State Income Taxes (157 140)486 161 652
76 Taxable Income 155 (3,304,096)215 378 13,704
78 Federal Income Taxes 156,434 575 182 796
Rocky Mountain Power
Idaho Results of Operations December 2006
Cash Working Capital
PAGE
TOTAL IDAHO
ACCOUNT COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Cash Working Capital CWC 418 897 Situs 418 897 Below
Cash Working Capital CWC (24,875)Situs (24 875)Below
Cash Working Capital CWC 144,088 Situs 144 088 Below
538,111 538 111
Adjustment Detail:
Type 1 Type 2 Type 3
O&M Expense 161,722,509 161,142 693 243,398,169
Taxes Other Than Income Tax 4,480,333 4,479,613 930,519
Federal Income Tax 323 117 217 223 600,890
State Income Tax 428,535 331 233 282 836
Total 169,954,495 168,170,762 250 212 415
Divided by Days in Year 365 365 365
Average Daily Cost of Service 465 629 460,742 685 513
Net Lag Days
Cash Working Capital 370,050 345,176 489,264
Unadjusted Cash Working Capital 951 153 370,050 345 176
Cash Working Capital Adjustment 418 897 (24 875)144 088
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 its 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
Idaho Results of Operations December 2006
Trapper Mine Rate Base
PAGE
Adjustment to Rate Base:
Mining Property
Mining Property
399
399
175,642
(615,898)
559,744
IDAHO
FACTOR FACTOR %ALLOCATED REF#
582%472 276
582%(40,536)
431 740 Below
ACCOUNT
TOTAL
COMPANY
Adjustment Detail:
December 2005 Balance
Calendar Year 2006 Change
December 2006 Balance
Average Balance December 2006
545,862
(740 440)
805,422
175 642
Calendar Year 2007 Change
December 2007 Balance
Average Balance December 2007
(491,356)
314 066
559,744
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
portion of the Trapper mine plant investment to rate base. This investment is accounted for on the Company s books in FERC account
123.1 - Investment in Subsidiary Company. However, FERC account 123 is not normally a rate base account. This adjustment reflects
net plant rather than the actual balance in FERC account 123 to recognize the depreciation of the investment over time.
Rocky Mountain Power
Idaho General Rate Case
Trapper Balance Sheet
Page 8.
DESCRIPTON Dee-Dec-Dec-
Inventories 3,454 022 482 665 655 163
Prepaid Expenses 417 653 386 284 465 808
Property, Plant, and Equipment
Lands and Leases 531 921 531 921 531 921
Development Costs 834 815 834 815 834 815
Equipment and Facilities 525 636 334 007 316 607
Total Property, Plant, and Equipment 892 372 89,700,743 683,343
Accumulated Depreciation (70 191 048)(73 211 829)(77 373 197)
Total Property, Plant, and Equipment 701,324 16,488,914 310,146
Restricted Funds: Self-bonding for Black Lung 539 845 534 084 528 408
Restricted Funds: Deposit funds for New Mining Pennit 875,468
Deferred GE Royalty Amount 272 727 909 091 545,459
TOTAL RATE BASE 35,261 039 801 038 29,504 984
PacifiCorp Ownership Share of Mine
PacifiCorp s Share
21.4%
545 862
21.4%
805,422
21.4%
314 067 Ref# 8.
Rocky Mountain Power
Idaho Results of Operations December 2006
Jim Bridger Mine Rate Base
PAGE
TOTAL IDAHO
ACCOUNT TvDe COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Mining Property 399 76,766,344 582%052,500
Mining Property 399 233,105 582%713,823
117 999,449 766,323 Below
Adjustment Detail:
December 2005 Balance
Calendar Year 2006 Change
December 2006 Balance
Average Balance December 2006
862,000
808,687
89,670,687
76,766,344
Calendar Year 2007 Change
December 2007 Balance
Average Balance December 2007
657,523
146,328,210
117 999,449
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 FERC 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 necessary to properly reflect the BCC plant investment
as of December 2007
Rocky Mountain Power
Idaho General Rate Case
Bridger Coal Mine
Page 8.
I Description
iSi.itf8Ci::MioeM0,i;:t~~i~;k!;:iif~.i;!fN,ttY::(!k;i,~,
~.. '; "
Net Property, Plant & Equipment
Materials & Supplies
Coal Inventory
Prepayments
Reclamation Liability
Bonus Bid Lease Payable~T6taISiI~~~~s~:a%"'
!~;
J;f;A \ ';r~59:;642:'6.611i:; if.;;45i624~$if9t,j;;;t;f$i922;966iW;;\;;.15~;27(a;;19.2i,H;i;;;Jj"
Dec'()5 Dec'()6 Dec'()7 Beg/End Avg
Balance
;;,
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'\::.;:;
,,,;:,j,\;~;'i,
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237 661 64,454 000 53,367 347 58,910 674
339 000 6 308 000 5,593,000 5 950 500
1,450 000 839,000 1 200 000 1 019,500000 13 000 150 000 81 500
(26,433 000) (25 989 381) (3,387 381) (14 688 381)
66.67%
66.67%
66.67%
66.67%
66.67%
66.67%
:;S:\:~:;p;ijI;1 M\ii182 528 ..
39,273,782
967 000
679,667
54,333
(9,792 254)
:unaefiJ...QMj(UMtne.
:~~'
*ff~~j!/;\:.;:~:~ifv: ':Ni~~ "'fi~;
; '
(&a~f.,~J~j!;':8::'ii::i.2U; ,.i:~i~:(.f1'\?~:;;;-i*;,!0;g:1;;!2:ff:
: "
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:;;;;;; '
Net Property, Plant & Equipment 40,947 583 70 511 000 150 257 349 110,384 175 66.67% 73 589,450Materials & Supplies 420 000 3,665 000 3,200 000 3,432 500 66.67% 2 288,333Coal Inventory 5,224 000 20,811 000 13,061 000 16 936 000 66.67% 11 290 667Prepayments 122 000 1 060,000 1 826 000 1 443,000 66.67% 962,000Reclamation Liability 66.67%
Bonus Bid Lease Payable (10 563 000) (7 165,587) (5 775 000) (6,470 294) 66.67% (4 313,529)
flli6ta I;IJ nd effirou odgFnltez BaSEt:~i8:OO~ :;~io;t);JYi:36\!~5O'.583': r~t"~,~88"; 88" 1:1U3'Ji; ii';1I62~$g; M9il.. . ~~25;;;l25;3 8, 1i*,'Ji1i' ~;1~i ~ii.:;
':~
it ;:')'83';8;1'6.1921,
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:':;t.~'ij~%;t gf.g;.vi~ffi;;;':~;mI~7'j,e,
;;~';
;:;;;f!~;:;ff;~;i;,;r1.,,; :if;'i~*~~;;r(' ':iff.f(:;f.;;:i
,:~'
1~;iJi.%Y:" ):f.k;.'d.,~i;
Structures, Equipment, Mine Developme 229 768 000 258 554 000 338,204 696 298,379 348 66.67% 198 919,565
Accumulated Depreciation (111,583,000) (123,589,000) (134 580 000) (129 084,500) 66.67% (86 056 333)
Net Property, Plant & Equipment 118 185 000 134 965 000 203,624 696 169,294 848 ' 112,863,232Materials & Supplies 7,759,000 9,973,000 8 793,000 9 383,000 66.67% 6 255 333Coal Inventory 6,674 000 21 650,000 14,261 000 17 955 500 66.67% 11 970,333Prepayments 171 000 1 073 000 1 976,000 1 524 500 66.67% 1 016 333
Reclamation Liability (26 433,000) (25,989,381) (3 387 381) (14 688,381) 66.67% (9,792 254)
Bonus Bid Lease Pa able 10,563 000 165,587) (5,775 000) (6,470 294) 66.67% (4 313,529)
~i=~;j ';;~=ftf~i.:~~~;~'~;~f;.
" '
l~:: ::~:~ 1;~:~:::i~;~;=~:: i;~:=l~~;:=f:~~~*~\~~~~~i~:::j:~~~:~8 . 3
Rocky Mountain Power
Idaho Results of Operations December 2006
Removal of Glenrock Mine
PAGE
TOTAL IDAHO
ACCOUNT COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Other Tangible Property 399 (843,851)582%(55,539)8.4.
Office Furniture and Equipment 391 (7,531)582%(496)8.4.
Accumulated Depreciation 108MP 979,630 582%64,476 8.4.
128,248 8,441
Description of Adjustment:
The majority of Glenrock mine assets, with the exception of land, have been sold. This adjustment removes from results net rate base
associated with the Glenrock mine.
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Rocky Mountain Power
Idaho Results of Operations December 2006
Environmental Settlement
PAGE
ACCOUNT TvDe
TOTAL
COMPANY FACTOR FACTOR %
IDAHO
ALLOCATED REF#
Adjustment to Rate Base:
Unspent Environmental Proceeds 25399 (18,204,788)873%069,257)
Description of Adjustment:
From 1996 to 1998, PacifiCorp received an insurance settlement of $38 million for environmental clean-up projects. These funds
were transferred to a subsidiary called PacifiCorp Environmental Remediation Company (PERCO). This adjustment reduces utility
rate base by the amount of unspent cash proceeds on regulated projects from the insurance settlement.
Page 8.
Rocky Mountain Power
Idaho General Rate Case
Environmental Remediation Co.
Spending by Environmental Project
Actual Cumulative Cash Remaining
Spending Actual Spending Received Cash
Site WBS CY 2006 thru 12/31/06 1996 & after at 12/31/06
American Barrel PERC/19971E1001 111 577 151 308 134 194 982,886
Astoria Unocal PERC/19971E1002 113.218 079,398 1,424 380 344.982
Eugene - PacifiCorp PERC/19971E1003 23.590 278,693 892 622 613 929
Everett - PacifiCorp PERC/19971E1004 625)(369,069)223,143 592,212
Jordan Barber Tar PERC/19971E1005 628 865,363 823.735
Ogden PERC/19971E1006 746 876 398.531 329,655
Tacoma A Street PERC/19971E1007 705 631 661 084,254 1,452,593
Tacoma River Street PERC/19971E1008 054 068 213,635 159.567
Bridger GW Sampling PERC/19971E1009 50.071 478,797 369,495 (109,302)
Bridger Landfill Repermitting PERC/19971E1010 (98)51,772 539 (20,233)
Bridger Oil Spill PERC/19971E1011 374,402 791 372 416.970
Carbon Fuel Oil PERC/19971E1012 15,781 26,034 10,253
Carbon Landfill Permit PERC/19971E1013 034 179 060 156,026
Carbon Emerg. Gen. Remediation PERC/19971E1014 16,598 756 158
Centralia Heavy Equipment Shop PERC/19971E1015 380 023 68,643
Dave Johnston GW Sampling PERC/19971E1016 674 206,585 311 657 105,072
Dave Johnston Landfill Repermit PERC/19971E1017 (179)182 133 391 209
Dave Johnston Diesel Release PERC/19971E1018 528 085 557
Dave Johnston Landfill Closure PERC/19971E1019 (1,604)267 870 310 425 042,555
Dave Johnston Landfill Reclamation PERC/19971E1020 288,190 475,080 186,890
Farm GW Monitoring - Hunter PERC/19971E1021 19,156 211,721 221.036 315
Farm GW Monitoring - Huntington PERC/19971E1022 46.101 215,699 194 267 (21,432)
Hunter Fuel Oil PERC/19971E1023 553 31,485 101.696 70.211
Hunter Injection Wells PERC/19971E1024 124.523 302 889 533,458 230,569
Hunter Landfill Permit PERC/19971E1025 798 863 132,745 76,882
Huntington Injection Wells PERC/1997/E1026 9,416 854,595 845.179
Huntington Landfill Closure PERC/19971E1027 066 634,441 706 819 378
Huntington Landfill Permit PERC/19971E1028 379 45,259 193,883 148 624
Huntington Lead Paint Removal PERC/19971E1029 315,468 000,804 (314,664)
Huntington Wellhead Protection PERC/19971E1030 14,052 846 206)
Buried Pitch PERC/19971E1031 78,446 50,848 (27,598)
Tank Farm PERC/19971E1032 12,136 12,623 152 868 140,245
Naughton FGD Pond Closure PERC/19971E1033 126,309 277,403 362,166 84,763
Naughton GW Monitoring PERC/19971E1034 29,460 222 500 351,477 128,977
Naughton Landfill Repermit PERC/19971E1035 (124)29,887 63.664 777
Naughton Landfill Closure PERC/19971E1036 975 63,814 839
Wyodak Pond Study PERC/19971E1037 167 69,585 100,972 387
Wyodak Fuel Oil PERC/19971E1038 749 27,878 206,196 178,318
Bank Stabilization & Restoration PERC/19971E1039 121 227 779 234,043 264
Restore River Embankments PERC/19971E1040 19,498 072 70.574
Cutler PERC119971E1041 76,560 333 773
Bank Stabilization & Restoration PERC/19971E1042 66,534 66,534
Merwin Hatchery Fix Erosion Problems PERC/19971E1044 94,425 018 (33,407)
Speelyai Hatchery Stabilize River Bank PERC/19971E1045 668 40,678 40,010
No, Umpqua Erosion Repairs PERC/19971E1046 32.205 27,809 396)
Klamath River Domestic Water Studies PERC/19971E1048 176 25,424 21,248
No. Umq Remove Contaminated Soils PERC/19971E1052 464 20,339 19,875
Rogue River Domestic Water Studies PERC/19971E1053 909 085 176
UST Removal PERC/19971E1054 786 339 15,553
Lead Paint Removal PERC/19971E1055 386,611 390,586 975
Annex I PERC/19971E1056 992 697 294 325,818 628 524
Cedar Diesel PERC/19971E1057 070 73,424 83,147 723
Holiday Gun Club PERC/19971E1058 709,275 616,950 (92 325)
Jordan Substation PERC/19971E1059 17,511 348.386 661 975 313.589
Montague Ranch PERC/19971E1060 133,977 400.957 188 757 (212 200)
Ross Island Tower Clean-up PERC/19971E1061 597 174 609,581 101,696 (507 885)
Spill Prevention, Containment and Countermeasl PERC/19971E1062 360.840 651,592 969 252 317 660
Ashton Substation PERC/19971E1070 271 28,434 25.163
Rock Springs Plant Substation PERC/19971E1071 733 638 905
Sinclair Substation PERC/19971E1072 (82)915 326 48,411
Parco Substation PERC/19971E1073 673 524 49,326 45.802
Garland Substation PERC/19971E1074 13,761 14.450 760 16,310
Dexter Substation PERC/19971E1075 43,185 903 718
WyoMont Substation PERC/19971E1076 33.705 903 18,198
Salt Lake Automotive Shop PERC/19971E1077 130,033 59.153 (70.880)
Vernal Diesel PERC/19971E1078 1,408 593 185
Page 8.
Rocky Mountain Power
Idaho General Rate Case
Environmental Remediation Co.
Spending by Environmental Project
Actual Cumulative Cash Remaining
Spending Actual Spending Received Cash
Site WBS CY 2006 thru 12/31/06 1996 & after at 12/31/06
Salt Lake Terminal Oil Spill PERC/1997/E1079 756 10,170 414
Bridger Coal Fuel Oil Spill PERC/1997/E1080 84,831 435,016 507 747 72,731
Bors Property PERC/1997/E1081 15,873 20,016 143
Coal Creek PERC/1997/E1082 416 867 2,452
Ekotek PetroChem PERC/1997/E1083 35,779 214 515 178,736
Environmental Pacific PERC/1997/E1084 611 10,008 397
Mountaineer Refinery PERC/1997/E1085 102
Northwest Triangle Property PERC11997/E1086 388 10,008 620
Pinedale PERC/1997/E1087 113,985 105,061 (8,924)
PCB, Inc.PERC/1997/E1088 143,312 10,007 (133,305)
Portable Equipment GW PERC/1997/E1089 634 (260,044)106,844 366,888
Idaho Falls Pole Yard PERC/1997/E1090 375,370 558 586 761,803 203,217
Astoria Steam Plant PERC/1997/E1092 529,908 435,322 (94 586)
Bear River Erosion Control PERC/1997/E1093 394 33,409 30,015
Beaver Bay Drainfield Cleanup PERC/1998/E1094 20,264 19,693 (571)
Bridger Boron Contaminated Soil Rem PERC/1998/E1095 340 199,834 197,494
Bridger Coal Warehouse Spill PERC/1998/E1097 278 146,835 144 558
Bridger Oil Spill (New Releases)PERC/1998/E1098 103,436 430,518 280,425 (150,093)
Cedar Steam Plant PERC/1998/E1099 517 223 76,423 73,200
Centralia Mine Pond Reclamation PERC/1998/E1100 503,287 695,377 192,090
Cougar Shore Line Repair PERC/1998/E1101 921 38,695 774
Mining Central Warehouse Cleanup PERC/1998/E1102 (176)59,849 279,159 219,310
Deer Creek Terrace Stablization PERC/1998/E1103 187 839 265 063 253 224
Domestic Water System Testing and Review PERC/1998/E1104 211 59,905 180,935 121 030
Hale Plant Cleanup PERC/1998/E1105 300 828 443,703 142 875
Huntington Ash Storm Runoff Pond PERC/1998/E1106 33,455 36,470 015
Huntington Lead Paint Removal PERC/1998/E1107 140,000 143,979 145,951 972
Lead Paint Removal (1998 Funds)PERC/1998/E1108 (462)129 127,715 118,586
Lewis Swift Reservoir Cleanup PERC11998/E1109 290,538 300,580 10,042
Lifton Pumping Station Cleanup PERC/1998/E1110 401 742 19,341
Merwin Oil House Removal PERC/1998/E1111 022 19,348 (674)
Naughton South Ash Pond Reclam PERC/1998/E1112 239,493 245,301 5,808
Ogden Pole Treating Remediation PERC/1998/E113 000,000 000,000
Speelyai Well PERC/1998/E1114 176 10,020 844
Big Fork PCB Soil Cleanup PERC/2003/E1123 17,251 103,360 122,000 18,640
Pwr Delivery UST Compliance Audit PERC/2003/E1124 12,123 47,000 877
Attorney contingency fee received 000 56,000
REGULATED TOTAL 625,184 21,732,036 38,624,232 16,892,196
Coos Bay - Advance Ross Liabilities PERC/1999/E1116 (8,410)(1,895)602 566 604,461
Coos Bay - PacifiCorp Liabilities PERC/1999/E1117 (1,861)478 202,094 200,616
Everett - Advance Ross Liabilities PERC/1999/E1118 365 377 627 625,168 247 541
Eugene - Advance Ross Liabliites PERC/1999/E1119 23,588 143,310 474 888 331 578
Tacoma A Street - Advance Ross Liabilities PERC/1999/E1120 679 543 379 280,018 736,639
Thea Foss - Advance Ross Liabilities PERC/1999/E1121 209,843 583,346 107,368 524 022
Thea Foss - PacifiCorp Liabilities PERC/1999/E1122 82,394 563,914 707 898 143,984
Thea Foss Shared Account PERC/2003/E1125 724 305 724 305)
NON.REGULATED TOTAL 313,598 935,465 10,000,000 064,535
GRAND TOTAL 938,782 28,667,502 48,624,232 19,956,730
December 2006 Regulated Balance 16,892 196
Add back Calendar Year 2006 Spend 625,184
December 2005 Regulated Balance 19,517,380
December 2006 Regulated Balance 16,892,196
December 2006 Average Balance 18,204,788 Ref# 8.
Rocky Mountain Power PAGE
Idaho Results of Operations December 2006
Customer Advances for Construction
TOTAL IDAHO
ACCOUNT COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Customer Advances 252 713,184 035%351,541
Customer Advances 252 (591,619)Situs (591,619)
Customer Advances 252 73,347 Situs
Customer Advances 252 258,513)Situs
Customer Advances 252 614,230 WYE Situs
Customer Advances 252 381 647 WYW Situs
Customer Advances 252 (893,772)WY-ALL Situs
Customer Advances 252 (223)Situs
Customer Advances 252 (13 981)Situs
Customer Advances 252 106,588)306%(258,980)
(82,288)(499,058)
Description of Adjustment:
Customer advances for construction are booked into FERC account 252. When they are booked, the entries do not reflect the proper
allocation. This adjustment corrects the allocation of customer advances for construction in the account.
Rocky Mountain Power
Idaho General Rate Case
Customer Advances for Construction
Beainnina Endina Averaae Basis:
Account Booked Allocation Correct Allocation Adjustment
252CN 713,184)713 184
2521DU 591 314 (305)(591 619)
2520R (154 897)(81 549)347
252UT 843,558 (3,414 956)258 514)
252WYE (614 230)614 230
252WYW (381 647)381 647
252WY-AII (893 772)(893 772)
252CA (15 175)(15 398)(223)
252WA 585)(16 566)(13 981)
252SG 106,588)106 588)
Total (8,446,846)(8,529,134)(82,288) Ref# 8.
Page 8.
Rocky Mountain Power PAGE
Idaho Results of Operations December 2006
Centralia Transmission Line Sale
TOTAL IDAHO
ACCOUNT COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment Rate Base:
Land and Land Rights 350 (16,943)306%069)
Station Equipment 353 (48,366)306%(3,050)
Towers and Fixtures 354 (8,266)306%(521)
Poles and Fixtures 355 (22 205)306%(1,400)
Overhead Conductors 356 (52 415)306%(3,306)
(148 195)(9,346)
Accumulated Depreciation:
Transmission Plant 108TP 83,818 306%286
Depreciation Expense:
Transmission Plant 403TP 580)306%(163)
Accumulated Deferred Income Tax Expense:
Transmission Plant 282 000 DITBAL 559%262
Description of Adjustment:
In December 2006, the Company completed and recorded the sale of the Centralia 230 kV transmission line and related facilities to
TransAlta Centralia Generation, LLC. This adjustment removes the beginning! ending electric plant in service, accumulated
depreciation, depreciation expense and accumulated deferred taxes associated with the transferred assets from the test period.
Rocky Mountain Power
Idaho General Rate Case
Centralia Transmission Line Sale
Beginning/Ending Average
Account Description
Electric Plant in Service:
350.Land Rights353 Station Equipment354 Towers and Fixtures355 Poles and Fixtures356 Overhead Conductors and Devices
Total Electric Plant in Service
Accumulated Depreciation:
350.Land Rights353 Station Equipment354 Towers and Fixtures355 Poles and Fixtures356 Overhead Conductors and Devices
Total Accumulated Depreciation
Depreciation Expense:
350.Land Rights353 Station Equipment354 Towers and Fixtures355 Poles and Fixtures356 Overhead Conductors and Devices
Total Depreciation Expense
Amount
943
48,366
266
205
52,415
148,195 Ref# 8.
(7,864)
(18,404)
(5,821)
(14 873)
(36 856)
(83,818 Ref# 8.
241
606
179
442
112
580 Ref# 8.
Page
Rocky Mountain Power PAGE
Idaho Results of Operations December 2006
Proforma Major Plant Additions
TOTAL IDAHO
ACCOUNT COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Steam Production 314 92,768,074 306%850 371
Hydro Production 332 070,005 SG-306%193,608
Other Production 344 178,386,287 306%249,840
Transmission 355 37,477,887 306%363,524
Distribution - Idaho 364 Situs
Distribution - Utah 364 541,005 Situs
Distribution - Oregon 364 697 871 Situs
Distribution - Wyoming 364 102 WY-ALL Situs
General Plant 394 644 Situs
General Plant 394 25,101 Situs
General Plant 392 813,837 873%106,536
General Plant 394 101 828 306%69,486
Mining Plant 399 929.955 582%192,840
Intangible Plant 303 641,861 873%390,109
Intangible Plant 303 151 350 306%72,609
335,613,807 20,488,924
Steam Production 314 30,203,550 306%904,771
Hydro Production 332 155,003 SG-306%388,162
Other Production 344 297,717 905 306%18,775,428
Transmission 355 81,581 791 306%144 914
Distribution - Idaho 364 614 249 Situs 614,249
Distribution - Utah 364 12,291,827 Situs
Distribution - Oregon 364 367 493 Situs
Distribution - Wyoming 364 563,907 WY-ALL Situs
General Plant 397 717,022 Situs
Mining Plant 399 501,408 582%296,267
Intangible Plant 302 18,683,392 SG-306%178,259
473,397,547 32,302 051
Tax Adjustments:
Accu(T1ulated Deferred Income Tax 282 571,141)DITBAL 559%(299 836)
Schedule M Deduction for Tax Depr SCHMDT 37,057,901 TAXDEPR 855%169,746
Schedule M Addition for Book Depr SCHMAT 968,203 SCHMDEXP 855%759,290
Deferred Income Tax 41010 142,281 DITEXP 238%387 495
Accumulated Deferred Income Tax 282 (6,646,365)DITBAL 559%(435,956)
Schedule M Deduction for Tax Depr SCHMDT 49,854 288 TAXDEPR 855%918,977
Schedule M Addition for Book Depr SCHMAT 828,253 SCHMDEXP 855%868,197
Deferred Income Tax 41010 13,292,731 DITEXP 238%563,411
Description of Adjustment:
This adjustment places into rate base the major plant additions greater than $2 million for calendar year 2006 and calendar year
2007. These additions are included into rate base using a half-year methodology with the exception of certain production
equipment where the in-service date was used.
The associated depreciation expense and accumulated reserve impacts are accounted for in adjustment 6.1 and 6.
Rocky Mountain Power
Idaho General Rate Case
Major Plant Addition Surnrnary
Jan06 to Dec06 Plant Adds Jan07 to Dec07 Plant Adds Total Plant Adds
Description Factor Plant Additions Months Included in Adj Plant Additions Months Included in Adj Included in Adj
Steam Production Plant:
Various 67,698,988 33,849 494 51,173 552 25,586,776 436 270
Huntington Scrubber 117 837,160 918 580 58,918,580
Blundell Bottornlng Cycle 700,643 616,774 616,774
Total Steam Plant 185 536 148 92,768,074 78,874,195 30,203,550 122 971,624
Hydro Production Plant:
Various SG-140,010 070,005 12,310,005 155 003 225 008
Various SG-U
Total Hydro Plant 140 010 070,005 310 005 155 003 9,225 008
Other Production Plant:
Hermiston 694,476 347,238 347238
Leaning Juniper 175,434,259 717,130 87,717,130
Currant Creek 176,643,838 88,321,919 88,321,919
Goodnoe Hills 196 572,406 24,571 551 24,571,551
Marengo Wind Project 258 541,351 107 725 563 107,725,563
Lake Side Capital Build 330,841,583 165,420,792 165 420,792
Total Other Production Plant 356,772 573 178 386,287 785 955 340 297 717 905 476 104,192
Transmission Plant:
Various 74,955,774 37,477,887 163,163,582 81,581,791 119,059,678
Total Transmission Plant 74,955,774 37,477,887 163 163,582 581,791 119059678
Distribution Plant:
Idaho 228,499 614,249 614 249
Utah 17,082,009 541,005 24,583,654 12,291 827 832 832
Oregon 395,742 697,871 14,734,987 367,493 065 364
Wyoming East WYE 12,203 102 13,127,814 563,907 570,009
Total Distribution Plant 489 955 10,244,977 674954 837 477 41,082,454
General Plant:
Oregon 289 644 434 045 717,022 719,667
Utah 201 101 25,101
General Office 627,673 813 837 813 837
Various 203 655 101,828 101,828
Total General Plant 886 818 943,409 434,045 717 022 660 432
Mining Plant:
Coal Mine 859 909 929,955 002,816 501,408 7,431 363
Total Mining Plant 859909 929 955 002,816 501,408 431 363
Intangible Plant:
General Office 13,283727 641 864 641,864
Various 302,699 151,350 151,350
Hydro Relicensing SG-P 37,366,783 18,683 391 18,683,391
Total Intangible Plant 15,586,426 793,213 366,783 683 391 476,605
Total Electric Plant in Service 671 227 613 335 613 807 155 781 719 473,397 547 809 011 354
Ref# 8.Ref# 8.Ref# 8.Ref# 8,
Rocky Mountain Power
Idaho General Rate Case
Major Plant Addition Detail - Jan2006 to Dec2006
Other Production
Hermiston: Comb Turbine Rotor Repl
Leaning Juniper 1 Wind Plant
Currant Creek Power Project
Other Production Total
Jan06 to DecO6
Account Factor In-Service Date Plant Additions
314 CY2006 109,660
314 CY2006 157 832
314 CY2006 554,011
314 CY2006 636,741
314 CY2006 643,198
314 CY2006 725,482
314 CY2006 748,115
314 CY2006 894,360
314 CY2006 053,069
314 CY2006 196,037
314 CY2006 3,412,866
314 CY2006 548,466
314 CY2006 603,730
314 CY2006 962,358
314 CY2006 586,000
314 CY2006 639,367
314 CY2006 047 854
314 CY2006 592 135
314 CY2006 587 706
314 07-Dec-117 837 160
185,536,148
332 SG-P CY2006 127 825
332 SG-P CY2006 012,185
140,010
344 CY2006 694,476
344 14-Sep-175,434,259
344 22-Mar-176 643 838
356 772,573
355 CY2006 178 027
355 CY2006 230 374
355 CY2006 663,741
355 CY2006 558,157
355 CY2006 376,579
355 CY2006 790,814
355 CY2006 3,445,752
355 CY2006 000 120
355 CY2006 660 594
355 CY2006 5,498,258
355 CY2006 915,145
355 CY2006 100,721
355 CY2006 13,680,809
355 CY2006 856,683
955,774
Project Description
Steam Production
Generator Stator Bars
NAU U2 Retube Condensor (ovhl)
U1 Scrubber Mist Eliminator Upgrade
HTG U2 Exciter Replacement FY2006
Wyodak Turbine Overhaul
UO - Purchase & Install Add'i Cent
Htg U2 Boiler Rear Reheat Replacement
U1 Scrubber Recycle Pipe
Wy - Rewind Main Generator Stator
NAU U3 Minewater Well (intangible)
U2 Boiler Front Reheat Replacement
U2 Boiler Low Temp. SH Replacement
U1 Boiler Low Temp. SH Replacement (Capp
Unit 1 Controls Upgrade
Wy - Reheat DMW Replacement
302 Cooling Tower Replacement
JB 1 Submerged Drag Chain Conveyor
Jim Bridger Scrubber
Wy2004U1 Controls Upgrade
Huntington Scrubber
Steam Production Total
Hydro Production
Replace Prospect Flumes
North Umpqua Implementation
Hydro Production Total
Transmission
809 POrT EMS SCADA Phase 2 (EPIC)
Beall Ln Sub Construct New 115-12kV Sub
Gordon Ave (Layton): New 138-12.5k Sub
Currant Creek Power Project
Bitter Creek Provide 230kV Svc Anadarko
90th South-Oquirrh Reconductor 138kV Ln
Claim Jumper Provide 230 Svc Anadarko
Quarry-DimpleDell Loop-Phase 2
Crow Reservation Renew Right-of-Way
Syracuse Add 345-138kV Transfmr (394MV A)
519 PDIT RQAS Ranger QAS Sys SCADA PT015
90th So & Terminal Subs: Loop- in CW Lns
Summit-Vineyard (Lake Side) Interconnect
SW Utah Load Growth Project
Transmission Total
Mining
Deer Creek-7th North Slope & Raise
Deer Creek-Rilda Canyon Vent. Slopes/Fan
Mining Total
Jan06 to Dec06
Account Factor In-Service Date Plant Additions
364 CY2006 (94 606)
364 WYE CY2006 12,203
364 CY2006 16.258
364 CY2006 123,407
364 CY2006 302,595
364 CY2006 898,315
364 CY2006 395,742
364 CY2006 3,491 700
364 CY2006 033,117
364 CY2006 311,224
20,489,955
394 CY2006 496
394 CY2006 289
394 CY2006 15,814
394 CY2006 33,597
394 CY2006 49,705
394 CY2006 58,363
394 CY2006 105 532
394 CY2006 396 610
394 CY2006 609,181
394 CY2006 984,559
392 CY2006 627,673
886,818
399 CY2006 303,625
399 CY2006 556,284
859,909
303 CY2006 954 615
303 CY2006 2,491,438
303 CY2006 302,699
303 CY2006 837,675
15,586,426
671,227 613
Ref# 8.
Project Description
Distribution
Quarry-DimpleDell Loop-Phase 2
Claim Jumper Provide 230 Svc Anadarko
90th South-Oquirrh Reconductor 138kV Ln
Summit-Vineyard (Lake Side) Interconnect
Herriman Purch Sub Prop & Trans ROW
Sunrise Inst 2nd 138-12kv Trnsfmr & Fdrs
Beall Ln Sub Construct New 115-12kV Sub
106th South New 138-12.5kV Sub-Tms-Dist
Gordon Ave (Layton): New 138-12.5k Sub
70th South #1 New 138-12.5kV 30MVA Sub
Distribution Total
General
70th South #1 New 138-12.5kV 30MVA Sub
Beall Ln Sub Construct New 115-12kV Sub
Quarry-DimpleDell Loop-Phase 2
Syracuse Add 345-138kV Transfmr (394MVA)
Gordon Ave (Layton): New 138-12.5k Sub
Summit-Vineyard (Lake Side) Interconnect
90th South-Oquirrh Reconductor 138kV Ln
90th So & Terminal Subs: Loop- in CW Lns
SW Utah Load Growth Project
North Umpqua Implementation
King Air 8200 Turboprop
General Total
Intangible
519 PDIT RQAS Ranger QAS Sys SCADA PT015
300 SR10/SR57 Improvement Project
Swift No.1 Capacity Retention
809 PDIT EMS SCADA Phase 2 (EPIC)
Intangible Total
8.4
Rocky Mountain Power
Idaho General Rate Case
Major Plant Addition Detail - Jan2007 to Dec2007
JanO7 to DecO7 Plant
Project Description Account Factor In-Service Date Additions
Steam Production
303 Secondary SH Replacements 314 Jun-158,370
U3 Replace Coal Pipe 314 May-187,403
303 FGD Tower Linings 314 Jun-569,426
303 Turbine HP Nozzle Box 314 Jun-589,404
303 Bottom Ash Repairs 314 Jun-593,624
U2 - Turbine - Generator Major 314 Dec-270,276
303 Turbine L-O Bucket Replacements 314 Jun-347 319
U3 Reheater Replacement 314 Aug-015,512
303 Reheater Replacements 314 Jun-021 737
JB U3 NOX 314 Dec-777 792
HTR U3 NOX 314 Dec-524 625
303 Main Controls System Upgrade 314 Nov-118 064
Blundell Bottoming Cycle 314 01-Nov-27,700,643
Steam Production Total 78,874,195
Hydro Production
Irongate Tunnel 332 SG-P Oct-545,231
North Umpqua Implementation 332 SG-P Jun-925,430
Copco 2 Electrical Overhaul 332 SG-Dec-839,344
Hydro Production Total 12,310 005
Other Production
Goodnoe Hills 344 15-Nov-196,572,406
Marengo Wind Project 344 01-Aug-258,541,351
Lake Side Capital Build 344 30-Jun-330,841,583
Other Production Total 785,955,340
Transmission
McClelland Emigration Tap 1.4Mi OH Line 355 Dec-122,182
Emery Moore 69kV Add 355 Jul-2,418,912
Transmission Relay Repl Zone 3 Setting 355 Dec-546,723
Oakley-Kamas line 355 Dec-3,469,191
Shute Creek To Mona System Upgrade Study 355 Dec-945,882
Craven Crk Provide 230kV Svc to Enterprise Prod-Pioneer 355 Jul-108,986
Copco transformer 250 MVA 355 Sep-695,049
Marengo Wind Project 355 Apr-866,514
Line 1 Conversion Project, Convert Line 1 to 115 kV 355 Dec-703,240
Upper Green River Valley project 355 Nov-013,738
Summit Vineyard (Lake Side) Tms Interconnect 355 May-861,575
Cache Valley Add. Bridgerland Sw St Ph 1 355 Jul-15,505,664
Chappel Creek - provide 230kV service to Jonah Field 355 Dec-16,102,548
Camp Williams-Mona 345kV #4 Line Project 355 Jun-253,547
Summit Vineyard Lake Side Transmission 355 Sep-549,831
Transmission Total 163 163 582
Project Description
Distribution
70th South #1 New 138-12.5kV 30MVA Sub
Quail Creek Sub Conv 12.47kv to 69kV Inst Tmsfm
Campbell Sub - Increase 115-12.5 kV Capacity
Cozydale Sub
FifthWest - Install 2nd 138-12.5kV Transformer & Feeders
Walnut Grove Sub, 3200 W Gordon
BDO/Build 138-12.5kV Sub & Line 30MVA
Porter Rockwell- New 138-12.5 kV Sub-Transm-Dist
Bond St Sub - Construct New 69-12.5 Sub
Elk Hom -115-12.5 kV, 25 MVAsub
Latham Install 230-34 5kV 25MVA Sub
Yew Ave. Substation - Construct New Substation
Cinder Butte - 161-12.5 kV 2-30 MVA sub
Distribution Total
General
Spectrum Purchase - Oregon
Bend Service Center
General Total
Mining
Mainline Extension
Rilda Canyon Storage Facilities
60" Terminal Group-Addition
Section Extension
Mining Total
Intangible
LI Rogue Relicensing-Hydro South
Swift Relicensing Superior
Merwin Relicensing Superior
Yale Relicensing Superior
Intangible Total
Account Factor In-8ervice Date
364
364
364
364
364
364
364
364
364
364
364
364
364
397
397
399
399
399
399
302
. 302
302
302
UT Feb-
UT Jun-
OR Sep-
UT Dec-
UT Sep-
UT Nov-
UT Oct-
UT Jun-
OR Mar-
WYE Aug-
WYE Mar-
OR Dec-
ID Nov-
OR Dec-
OR Dec-
Jan-
Oct-
May-
Jan-
SG-P May-
SG-P Aug-
SG-P Aug-
SG-P Aug-
JanO7 to DecO7 Plant
Additions
184,309
737,073
781,111
263,638
3,489,408
982,328
4,441,168
4,485,730
275,242
6,488,837
638,977
678,634
228,499
61,674 954
2,434 045
000,000
434,045
161,000
180,816
258,000
2,403,000
002,816
051,296
134 142
607,989
12,573,356
37,366,783
155,781,719
Ref# 8.
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r
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9
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8
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33
2
10
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6
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1
33
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7

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1
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8
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6
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5
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9
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4
7
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68
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10
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10
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7
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53
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11
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5
7
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53
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1
3
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2
8
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6
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52
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7
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3
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6
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77
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9
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7
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8
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18
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8
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2
,
89
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8
2
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(1
9
1
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9
)
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t
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1
0
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C
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6
,
77
4
21
9
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33
3
,
28
5
15
1
,
23
8
18
2
,
04
7
37
,
95
1
%
69
,
08
9
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9
,
08
9
)
(3
4
,
54
4
)
To
t
a
l

S
t
e
a
r
n

P
l
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n
t
20
3
,
55
0
18
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39
4
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9
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1
19
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45
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98
6
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5
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2
5
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d
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o

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P
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t
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Va
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15
5
00
3
21
9
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44
4
33
0
16
5
,
31
6
27
9
01
4
37
.
95
1
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10
5
88
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0
5
,
88
9
)
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2
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94
4
)
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o
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s
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21
9
%
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,
95
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%
To
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a
l

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y
d
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o

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l
a
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t
15
5
,
00
3
44
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33
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16
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31
6
27
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01
4
10
5
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88
9
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5
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2
94
4
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h
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P
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P
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9
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.
95
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00
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%
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r
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%
Go
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H
i
l
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s
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,
57
1
,
55
1
20
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00
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,
31
0
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2
,
86
2
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1
,
4
4
8
37
.
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%
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4
9
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,
02
4
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4
9
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,
02
4
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4
6
01
2
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W
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P
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7
,
72
5
,
56
3
20
,
00
0
%
54
5
,
11
3
30
9
,
02
3
17
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23
6
,
09
0
37
.
95
1
%
54
1
,
26
9
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,
54
1
,
26
9
)
27
0
,
63
4
)
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k
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p
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l

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d
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5
42
0
,
79
2
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,
94
1
,
72
7
72
6
,
30
8
21
5
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41
9
37
.
95
1
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8
,
32
4
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73
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32
4
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,
36
9
,
16
2
)
To
t
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l

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P
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n
t
29
7
,
71
7
,
90
5
38
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40
1
,
15
0
10
,
01
8
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19
3
28
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38
2
.
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7
77
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,
61
6
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0
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5
,
80
8
)
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a
n
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m
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s
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o
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P
l
a
n
t
:
Va
r
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o
u
s
81
,
58
1
,
79
1
00
0
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9
,
09
0
79
8
,
85
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28
0
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23
4
37
.
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1
%
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5
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6
5
,
37
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3
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68
6
)
To
t
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r
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58
1
,
79
1
07
9
09
0
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23
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6
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3
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68
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s
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l
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n
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:
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a
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61
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24
9
21
9
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3
,
10
3
12
4
56
5
20
8
53
7
37
,
95
1
%
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2
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9
,
14
2
)
(3
9
57
1
)
Ut
a
h
12
,
29
1
,
82
7
21
9
%
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7
,
34
7
31
0
,
37
5
57
6
,
97
2
37
.
95
1
%
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8
,
96
6
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1
8
96
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0
9
,
48
3
)
Or
e
g
o
n
36
7
,
4
9
3
21
9
%
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1
,
85
9
21
2
,
10
9
31
9
,
75
0
37
,
95
1
%
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1
,
34
8
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2
1
,
34
8
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0
,
67
4
)
Wy
o
r
n
i
n
g

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a
s
t
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56
3
,
90
7
21
9
%
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3
,
84
8
18
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,
04
8
29
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80
0
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,
95
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1
0
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1
0
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5
,
18
1
)
To
t
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l

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s
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b
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a
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,
47
7
22
6
,
15
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83
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09
8
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Rocky Mountain Power PAGE
Idaho Results of Operations December 2006
Miscellaneous Rate Base
TOTAL IDAHO
ACCOUNT COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
1 - Plant Held for Future Use 105 038,046)306%(65,464)
2 - Coal Lease 182M 500,000 582%230,358
Cash OWC131 (7,397,250)SNP 713%(422,603)
4 - Fuel Stock 151 16,425,036 582%081 040
4 - Fuel Stock 151 347 618 SSECH 105%204 374 9.4
837 358 027 706
Description of Adjustment:
1 - Plant held for future use is not permitted in Idaho rates unless an item is explicitly approved for inclusion in rates by the
Commission, per section 61-502A of Title 61 , Public Utility Regulation. In accordance with this statute, this adjustment removes plant
held for future use from results. For this filing, the Company is not seeking recovery of a specific project. It expects to propose
recovery of projects in the future.
2 - The company is preparing to participate in an auction to lease Cottonwood coal reserves from the Utah Trust Lands Administration.
Upon completion of the successful bid, the company plans to extract the coal for use in its electric generation operations. In order to
secure the mineral rights through a successful bid, the company estimates that it will have to submit 5 annual payments of $7 million
to the Utah Trust Lands Administration, beginning in calendar year 2007. This adjustment reflects the first annual payment into
results.
3 - In order to avoid earning its ROR rate on its cash balance, the company is removing the balance from rate base via this
adjustment.
4 - The cost of the companys 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.
Rocky Mountain Power
Idaho General Rate Case
1) Removal of Plant Held for Future Use
Account Description Seconda Account Descri tion Factor
1050000 Plant Held For Future Use 3500000 Land and Land Rights SG
1050000 Plant Held For Future Use 3501000 Land Owned in Fee
Dec 06 Beg/End
Average Balance Ref
031 067
979
038,046 To 8.
Rocky Mountain Power
Idaho General Rate Case
2) Cottonwood Coal Lease
Year
2007
Account
182M
Factor Pmt Amount Beg/End Average Ref
000,000 3,500,000 To 8.
Cottonwood Coal Reserves Lease
The Company is preparing to participate in an auction to lease Cottonwood coal reserves near
the Trail Mountain Mine from the Utah Trust Lands Administration. The successful participant of
the auction will gain the rights to the coal reserves contained in the Cottonwood tract. Upon
completion of a successful bid for the Cottonwood reserves, the company plans to extract the
coal for use in is electric generation operations. In order to secure the mineral rights through a
successful bid, the company estimates that it will have to make 5 annual payments of $7 million
to the Utah Trust Lands Administration. In order to reflect this payment in results, the first annual
payment of $7 million is being adjusted into account 182M
Rocky Mountain Power
Idaho General Rate Case
3) Removal of Cash Balance
Account
131
Factor
SNP
Jan 2006 to Dec 2006
12 Mo" Average Balance Ref
397 250 To 8.
Rocky Mountain Power
Idaho General Rate Case
4) Coal Fuel Stock Balances
Dec 2005 - Dec 2006 Dec 2006 - Dec 2007
Plant Account Factor Average Balance Average Balance Adjustment
Carbon Plant 151 917 904 059,722 141 818
Cholla Plant 151 SSECH 640 026 987 644 347 618
Colstrip Plant 151 439 767 471,787 32,020
Craig Plant 151 805,429 825 619 191
Dave Johnston Plant 151 910,772 368,027 457 255
Deer Creek Coal Mine and Prep Plant 151 20,545,999 245,549 699 550
Hayden Plant 151 963,699 966,581 882
Hunter Plant 151 239,900 13,476,982 237 082
Huntington Plant 151 476,979 150,101 673,123
Jim Bridger Plant 151 487 422 796,744 309,321
Naughton Plant 151 373,182 592,477 219,295
Rock Garden 151 632,500 632 500
65,801,079 85,573,733 19,772 654 To8.
Rocky Mountain Power PAGE
Idaho Results of Operations December 2006
Upper Beaver Hydro Sale
TOTAL IDAHO
ACCOUNT TvDe COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Reservoirs, Dams & Waterways 332 (2,485,609)SG-306%(156,754)
Station Equipment 353 3 -(828,536)306%(52,251)
Hydraulic Plant Accum Depr 108HP 1 ,223,244 SG-306%77,143
Transmission Plant Accum Depr 108TP 407 748 306%25,714
683,153)(106,147)10.
Adjustment to O&M Expense:
Misc. Hydro Expenses 539 (41 126)SG-306%594)
Maint. of Dams & Waterways 543 (33,648)SG-306%(2,122)
(74 774)(4,716)10.
Adjustment to Depreciation Expense:
Hydro Depreciation 403HP (79,516)SG-306%(5,015)10.
Adjustment to Property Tax:
Taxes Other Than Income 408 (16,531)GPS 873%(971)10.
Description of Adjustment:
PacifiCorp has entered into an agreement to sell the Upper Beaver hydro electric facilities to Beaver City, Utah. The sale will be
completed once the final regulatory approvals are obtained.
This adjustment removes the Upper Beaver assets that are being sold as well as removing the associated expenses such as
operation and maintenance, depreciation and property tax expense incurred in calendar year 2006, etc.
Rocky Mountain Power
Idaho General Rate Case
Upper Beaver Hydro Facilities Sale
Rate Base (Assets Retired)
Electric Plant in Service
Accumulated Depreciation
OMAG
SAP OMAG
500250 Overtime Meals
500312 IBEW 57 PS Prem Pay
503110 Lodging
503115 On-Site Meals & Ref
503135 Auto/Park/Mileage
503140 Cell Phone
503185 Travel Per Diem
516010 Metal & Steel
516040 Cement & Concrete P
516050 Chemicals
516120 Gases
516200 Uniform / Safety Eq
516260 Electronic Supplies
516300 Office Supplies
516310 Oth Elect Equip/Sup
516320 Pipe, Vlvs and Fitn
516330 Wood Products
516340 Fastners
516350 Hse Ftgs(Non-Hyd)
516410 Tools
516438 Vehicle Expense - L
516440 Veh/Mob Equip-Fuels
516460 Hvy Equp Mat'l & Su
516900 Misc M&S
530073 Freight Serv
530120 Delivery/Courier Se
530190 Misc Contr/Serv
535300 Other Utilities
541000 Equipment Rent
541002 RightsofWayExp
545350 Postage
610003 Operator
TotalOMAG
Depreciation
Depreciation Expense
Property Taxes
Property Taxes
Balance Balance
1/1/06 12/31/06 Average
314,146 314,146 314,146
(1,587,102)(1,674,881)630,992)
727 044 639,264 683,154
CY 2006
510
299
313
128
046
219
823
308
231
363
631
108
130
207
440
658
519
293
684
876
891
068
31,689
74,774
Ref
CY 2006
79,516
CY 2006
16,531
Ref
Page 8.10.
Rocky Mountain Power PAGE
Idaho Results of Operations December 2006
Cove Hydro Decommission
TOTAL IDAHO
ACCOUNT COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Reservoirs, Dams & Waterways 332 381 562)SG-306%(87 128)11.
Hydraulic Plant Accum Depr 108HP 549,663 SG-306%664 11.
Hydraulic Plant Accum Depr (1)108HP 447 269 SG-306%271 11.
615,370 38,808
Adjustment to O&M Expense:
Misc. Hydro Expenses 539 924)SG-306%(121)11.
Adjustment to Depreciation Expense:
Hydro Depreciation 403HP (42 763)SG-306%697)11.
Adjustment to Property Tax:
Taxes Other Than Income 408 (12 262)GPS 873%(720)11.
Description of Adjustment:
The Cove hydro electric plant was decommissioned in the fall of 2006. Most of the assets were retired and a few were transferred to
other locations for use as capitalized spare parts. By December 31 , 2006, most assets that were going to be retired were, in fact
retired. The powerhouse has not been retired as its ultimate disposition has not been determined. A few other assets were not retired
until January 2007. Removal costs of about $3.3 million have been booked into the depreciation reserve and will be depreciated over
the life of the remaining Bear River system assets. That depreciation will not begin until January 1 , 2008 at the earliest so is not
adjusted here.
This adjustment removes the Cove assets from calendar year 2006 results and also removes the associated expenses such as
operation & maintenance, depreciation and property tax expense, etc incurred in calendar year 2006. This adjustment also adjusts
the beginning/ending depreciation reserve balance for the removal costs to reflect the ongoing level which was on the books at
December 31, 2006. That part of the adjustment is noted by (1) above.
, '
Rocky Mountain Power
Idaho General Rate Case
Cove Hydro Decommissioning
Rate Base (Assets Retired)
Electric Plant in Service
Accumulated Depreciation
Balance Balance Beg/End
1/1/06 12/31/06 Averaqe
530,484 232 640 381,562
(1,006 768)(92 557)(549,663)
523,716 140 083 831 900
* A limited number of assets were not retired
until January of 2007.
Removal Costs 434,883 3,329,420
Beginning/Ending Balance 882,152
Adjustment** 447 269
** The removal costs will remain at the year-end level until they begin
being depreciated 1/1/08. This adjustment brings the beginning/ending
average up to the ongoing (year-end) level.
Ref
OMAG
SAP OMAG
500312 IBEW 57 PS Prem Pay
503140 Cell Phone
503185 Travel Per Diem
516050 Chemicals
516120 Gases
516310 Oth Elect Equip/Sup
516320 Pipe, Vlvs and Fitn
516410 Tools
Total OMAG to be Removed
RefCY 2006
292
255
057
201
924
Depreciation
Depreciation Expense
CY 2006
42,763
Property Taxes
Property Taxes
CY 2006
12,262
Ref
Page 8.11.
Rocky Mountain Power PAGE
Idaho Results of Operations December 2006
Powerdale Hydroelectric Facility
TOTAL IDAHO
ACCOUNT COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Reclassify EPIS to Reaulatorv Asset
Franchise & Consent 302 (2,467,099)SG-306%(155,586)12.
Land and Land Rights 330 (117)SG-306%(7)12.
Structures and Improvements 331 (404,507)SG-306%(25,510)12.
Reservoirs and Waterways 332 810,059)SG-306%(366,408)12.
Water Wheel, Turbines & Generator 333 (660,367)SG-306%(41 646)12.
Accessory Electric Equipment 334 (203,738)SG-306%(12,849)12.
Misc. Power Plant Equipment 335 (11 649)SG-306%(735)12.
Roads, Railroads & Bridges 336 (24,340)SG-306%(1,535)12.
Regulatory Asset 182M 581,876 306%604,276 12.
Adjustment to Depreciation:
Reclassify Depr. Expense as Amort. ExpenseDepreciation Expense 403HPAmortization Expense 4O4IP
(584,728)
584,728
SG-
SG-
306%
306%
(36,876)
36,876
12.
12.
Adjustment to Expense:
Remove Avoided Operation and Maintenance Expense
Operation Supervision 535 (15 146)SG-306%(955)12.
Hydraulic Expenses 537 (15,299)SG-306%(965)12.
Misc. Hydro Expenses 539 (161 616)SG-306%(10,192)12.
Rents 540 (362)SG-306%(23)12.
Maint. of Structures 542 (758)SG-306%(48)12.
Maint. of Dams & Waterways 543 (10,040)SG-306%(633)12.
Maint. of Electric Plant 544 (8,519)SG-306%(537)12.
Maint. of Misc. Hydro Plant 545 (15,898)SG-306%003)12.
(227 638)(14,356)
Description of Adjustment:
The Company filed in the state of Idaho, Case No. PAC-07-04, for an Order authorizing the Company to transfer its undepreciated net
investment of approx. $8.9 million (month end Jan 31 , 2007) in the Powerdale Plant from FERC account 101 , EPIS to FERC account
182., unrecovered plant and regulatory study costs. This adjustment removes $9.58 million which represents the calendar years 2005
and 2006 beginning ending average. The adjustment also reclassifies accumulated depreciation to accumulated amortization.
This adjustment also removes the avoided operation & maintenance (O&M) expenses incurred for calendar year 2006.
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Rocky Mountain Power
Idaho General Rate Case - December 2007
Powerdale Hydroelectric Facility
O&M Expenses for the Calendar Year 2006
Page 8.12.
FERC
Plant Acccount FERC Acccount Description
POWERDALE 5350000 OPERATION SUPERVISION AND ENGINEERING 146 (15,146
POWERDALE 5374000 HYDRAULIC EXPENSES-OTHER REC FACILITIES 299 (15,299
POWERDALE 5390000 MISC HYDRAULIC POWER GENERATION EXPENSE 233 616 72,000 (161 616
POWERDALE 5400000 RENTS (HYDRO GENERATION)362 (362
POWERDALE 5420000 MAINTENANCE OF STRUCTURES 758 (758
POWERDALE 5430000 MAINT OF RESERVOIRS, DAMS AND WATERWAYS 040 (10 040
POWERDALE 5441000 PRIME MOVERS & GENERATORS 899 899
POWERDALE 5442000 ACCESSORY ELECTRIC EQUIPMENT 619 619
POWERDALE 5459000 MAINT MISC HYDRO PLANT - OTHER 898 (15 898
Grand Total 299 639 000 (227,638
CY 2006 Total
Estimated On-
Going Level of
O&M Costs Difference
Ref# 8.
Rocky Mountain Power
IDAHO
Normalized Results of Operations - ROLLED.
12 Months Ended DECEMBER 2006
Operating Revenues:
2 General Business Revenues
3 Interdepartmental
4 Special Sales
5 Other Operating Revenues
Total Operating Revenues
Operating Expenses:
9 Steam Production
10 Nuclear Production
11 Hydro Production
12 Other Power Supply
13 Transrnission
14 Distribution
15 Customer Accounting
16 Customer Service & Info
17 Sales
18 Administrative & General
20 Total O&M Expenses
22 Depreciation
23 Amortization
24 Taxes Other Than Income
25 Incorne Taxes - Federal
26 Incorne Taxes - State
27 Incorne Taxes - Def Net
28 Investment Tax Credit Adj.
29 Misc Revenue & Expense
31 Total Operating Expenses:
33 Operating Rev For Return:
35 Rate Base:
36 Electric Plant In Service
37 Plant Held for Future Use
38 Mise Deferred Debits
39 Elec Plant Acq Adj
40 Nuclear Fuel
41 Prepayments
42 Fuel Stock
43 Material & Supplies
44 Working Capital
45 Weatherization Loans
46 Mise Rate Base
48 Total Electric Plant:
50 Rate Base Deductions:
51 Accurn Prov For Depree
52 Accurn Prov For Amort
53 Accurn Def Income Tax
54 Unamortized rrc
55 Customer Adv For Canst
56 Custorner Service Deposits
57 Mise Rate Base Deductions
59 Total Rate Base Deductions
61 Total Rate Base:
63 Return on Rate Base
65 Return on Equity
67 TAX CALCULATION:
68 Operating Revenue
69 Other Deductions
70 Interest (AFUDC)
71 Interest
72 Schedule "M" Additions
73 Schedule "M" Deductions
74 Income Before Tax
76 State Incorne Taxes
77 Taxable Incorne
79 Federallncorne Taxes + Other
(1)
Total Adjusted
Results
(2)
Price Change
178 992 843 223,143
122,881,936
331,786
308 206,564
Page 9.
(3)
Results with
Price Change
194 215,986
52,123,411
324,572
145 180,457
009 675
136,621
586 151
661 078
22,383
585,920
608 534
236 607 886
582 531
343 233
934,724
868,278
594,961
505 478
(757 790)
(168,472)
078 726
690 114
275 510 830 791 223
32695735 9431 919
926 866,310
978 218
047 975
775 307
769 371
512 081
110 789
828,486
587 735
934,724
947,004
285,076
281 302,053
42127654
961 476 271 961 476,271
(357 076 347)
(20 735 812)
(78 030 048)
125 317)
(259,285)
718,553)
(466 945 362)
494 530 909
(466 945 362)
494530909
611%519%
966%
38,906 662 200,760
200 199
758 169
568 144
896 488 15,200 760
594 961
13301 526
690,114
14510645
10.750%
54,107,422
200 199
758 169
568 144
097 247
285 076
27812172
3868278 5078726 8947004
Ref, Page 9,
Rocky Mountain Power
RESUL 15 OF OPERATIONS
Page 9.
USER SPECIFIC INFORMATION
STATE:
PERIOD:
IDAHO
DECEMBER 2006
FILE:
PREPARED BY:
DATE:
TIME:
JAM-Idaho GRC-Dec2006
Revenue Requirement Department
5/17/2007
1:43:34 PM
TYPE OF RATE BASE:
ALLOCATION METHOD:
Beginning/Ending
ROLLED-
FERC JURISDICTION:Separate Jurisdiction
80R 12CP:12 Coincidental Peaks
DEMAND %
ENERGY %
75% Demand
25% Energy
TAX INFORMATION
TAX RATE ASSUMPTIONS:
FEDERAL RATE
STATE EFFECTIVE RATE
TAX GROSS UP FACTOR
FEDERAUSTATE COMBINED RATE
TAX RATE
35.00%
54%
614
37.95%
CAPITAL STRUCTURE INFORMATION
CAPITAL
STRUCTURE
EMBEDDED
COST
WEIGHTED
COST
DEBT
PREFERRED
COMMON
49.10%
50%
50.40%
100.00%
26%
5.41%
10.75%
074%
027%
418%
8.519%
OTHER INFORMATION
ROLLED-Page 9.
innin /Endin
RESULTS OF OPERATIONS SUMMARY
UNADJUSTED RESULTS IDAHO
Descri tion of Account Summa Ref TOTAL OTHER IDAHO ADJUSTMENTS ADJ TOTAL
Operating Revenues
General Business Revenues 847 007,473 707,459,234 139 548,239 39,444 604 178,992 843
Interdepartmental (7)(7)
Special Sales 750,904 692 704 076 767 46,827,925 054,011 122 881 936
Other Operating Revenues 2.4 147 397 762 142,055,483 342 278 989,507 331 786
Total Operating Revenues 2.4 745 309,919 553 591,476 191 718 442 116,488,122 308,206 564
Operating Expenses:
Steam Production 740 727,406 692 670,254 057 153 066,259 123,411
Nuclear Production
Hydro Production 36,497 550 34,195 851 301 699 22,872 324 572
Other Power Supply 925 911 510 891 540,876 370 633 110,809,824 145,180,457
Transmission 136,930,481 128,278 726 651 756 357,919 009 675
Distribution 218 820,422 207 464 521 355,901 (1,219,279)10,136,621
Customer Accounting 107 864 332 103,228 728 635,604 (49,453)586 151
Customer Service & Infor 739,370 49,601 990 137 380 476,302)661 078
Sales
Administrative & General 238 975,926 225,787 243 188 683 602,763)585,920
Total 0 & M Expenses 458,466,997 332 768 189 125 698 808 110,909,078 236 607 886
Depreciation 391 176 792 368,272,603 904 189 678,342 582,531
Amortization 931 521 728 985 202,536 140 698 343 233
Taxes Other Than Income 101 034,471 317 393 717 078 217 647 934,724
Income Taxes - Federal 140,416 691 135 305,575 111 116 242 838)868 278
Income Taxes - State 945 018 288,151 656,867 (61 906)594 961
Income Taxes - Def Net 178,051 503 851 674 200 831 278 505,478
Investment Tax Credit Adj.854,860)(5,097 070)(757 790)(757 790)
Mise Revenue & Expense (15,439 233)(14 415 638)023 595)855 123 (168,472)
Total Operating Expenses 177 855 448 015,672,040 162 183,408 113 327,422 275 510 830
Operating Revenue for Retum 567,454,471 537 919,437 535 034 160 700 32,695,735
Rate Base:
Electric Plant in Service 745 911 135 879 068,499 866 842 636 60,023,674 926 866,310
Plant Held for Future Use 283,901 218,437 65,464 (65 464)
Mise Deferred Debits 112 065 538 108 832 917 232 621 745,597 978,218
Elec Plant Acq Adj 80,044 642 996 668 047 975 047 975
Nuclear Fuel
Prepayments 29,605,268 829 961 775 307 775 307
Fuel Stock 885 637 63,417 634 4,468 002 301 369 769,371
Material & Supplies 123 572 819 116 060 739 512 081 512 081
Working Capital 66,788,220 63,786,414 001 806 108 983 110,789
Weatherization Loans 187 445 358 959 828,486 828,486
Miscellaneous Rate Base 676,454 088,719 587 735 587 735
Total Electric Plant 15,255 021 059 356 658 947 898 362 112 63,114 159 961 476,271
Rate Base Deductions:
Accum Prov For Depr 801 309 811)444 796,456)(356 513 355)(562 991)(357 076 347)
Accum Prov For Amort (372 108 846)(351,411 364)(20,697,482)(38,330)(20,735 812)
Accum Def Income Taxes (1,194 262 511)115 976 938)(78,285 573)255 525 (78 030,048)
Unamortized ITC (12 979 804)(12 921 554)(58,250)067 067)125,317)
Customer Adv for Const (8,446 845)686 619)239 773 (499 058)(259 285)
Customer Service Deposits
Misc. Rate Base Deductions (92 950 646)(87 653 159)297,488)(3,421 065)718 553)
Total Rate Base Deductions 482 058 464)021 446 090)(460.612 375)(6,332 987)(466 945 362)
Total Rate Base 772,962 594 335 212 857 437,749 737 56,781 172 494 530 909
Return on Rate Base 300%747%611%
Return on Equity 333%235%966%
Net Power Costs 773,021 586 890 631 715 965
100 Basis Points in Equity:
Revenue Requirement Impact 135 748 555 614 016,818
Rate Base Decrease (501 972 197)(30 426,900)(35 028 435)
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
Sales to Ultimate Customers
440 Residential Sales
065 628 795 032 652 803 32,975 992 074,470 51,050 462
065,628,795 032 652,803 975,992 18,074 470 050 462
442 Commercial & Industrial Sales
746,291,229 639 970 519 106,320,710 370,359 127,691 069
746 291 229 639,970,519 106,320 710 370 359 127 691 069
444 Public Street & Highway Lighting
18,427 832 176,295 251 537 (225)251 312
427 832 18,176,295 251 537 (225)251 312
445 Other Sales to Public Authority
16,659 617 659 617
16,659 617 659 617
448 Interdepartmental
DPW (7)(7)
(7)(7)
Total Sales to Ultimate Customers 847 007 465 707,459,226 139,548,239 39,444,604 178,992 843
100
101
102
103 447 Sales for Resale
104 WSF 738,888 738,888
WSF 757,499 306 709 727 999 47,771 307 75,110 628 122 881,936
106 WSF (14 333,503)(13,390,120)(943,383)943,383
107 WSF
108
109 750 904 692 704 076 767 46,827 925 76,054,011 122 881 936
110 449 Provision for Rate Refund
111 WSF
112 WSF
113
114
115
116
117 Total Sales from Electricity 597,912,157 411,535,993 186,376,164 115,498,615 301,874,779
118 450 Forfeited Discounts & Interest
119 CUST 910 738 673,838 236 900 236 900
120 CUST
121 910 738 673,838 236 900 236 900
122
123 451 Misc Electric Revenue
124 CUST 263 802 148 114 115 688 115 688
125
126 024 23,553 1,471 471
127 288 827 171 667 117 159 117 159
128
129 453 Water Sales
130 228 267 960 960
131 15,228 267 960 960
132
133 454 Rent of Electric Property
134 DPW 268 511 13,913,665 354,846 354 846
135 906 539 597 111 309,428 309 428
136 217 826 205,021 805 805
137 392 877 715 797 677 080 677 080
138
ROLLED-Page 9.4
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
140
456 Other Electric Revenue
142 DMSC 969,612 969,388 224 224
143 GUST
144 OTHSE 951 743 165 120 786,623 786,623
145 OTHSO 241 227
146 OTHSGR 868,497 52,345,179 523,318 989 507 512 826
147
148
149 115 790,092 111 479 913 310,179 989 507 299 687
150
151 Total Other Electric Revenues 147,397,762 142,055,483 342 278 989,507 331,786
152
153 Total Electric Operating Revenues 745,309,919 553,591,476 191 718,442 116,488,122 308,206,564
154
155 Summary of Revenues by Factor
156 929,159,018 788,903,121 140,255 897 39,444 604 179 700 501
157
158 381 760)(2,225,001)(156 759)943 383 786 623
159 243,091 228 801 290 290
160 818 289,570 766,684 556 605 014 100 135 127 705 150
161 DGP
162
163 Total Electric Operating Revenues 745,309,919 553,591,476 191 718 442 116 488 122 308 206 564
164 Miscellaneous Revenues
165 41160 Gain on Sale of Utility Plant - CR
166 DPW
167
168
169
170
171
172
173 41170 Loss on Sale of Utility Plant
DPW
176
177
178 4118 Gain from Emission Allowances
179
180 (15,619,250)(14 591 244)028 006)855 123 (172 883)
181 (15 619,250)(14 591 244)028,006)855,123 (172 883)
182
183 41181 Gain from Disposition of NOX Credits
184
185
186
187 4194 Impact Housing Interest Income
188
189
190
191 421 (Gain) Loss on Sale of Utility Plant
192 DPW 72,809 841 (32)(32)
193 253 237
194
195 PTD 67,583 856 727 727
196 PTD 182,879 172 128 751 10,751
197 (143,507)(134,457)(9,050)050)
198 180,017 175,606 4,411 4,411
199
200 Total Miscellaneous Revenues (15,439,233)(14 415,638)(1,023,595)855,123 (168,472)
201 Miscellaneous Expenses
202 4311 Interest on Customer Deposits
203 GUST
204
205 Total Miscellaneous Expenses
206
207 Net Misc Revenue and Expense (15,439,233)(14 415 638)023,595)855,123 (168 472)
~08
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
!09 500 Operation Supervision & Engineering
~10 SNPPS 159 284 824 885 334,399 257 291 591 690
211 SNPPS 526,906 430,613 294 96,294
212 686,191 255,498 1,430 693 257 291 687 984
213
214 501 Fuel Related
215 439,6)2,173 410,678,392 933 781 587 647 521,428
216
217
218
219 45,467 404 42,474 894 992 510 992 510
220 485 079,578 453 153 286 31,926 291 587 647 513,938
221
222 502 Steam Expenses
223 SNPPS 831 632 950 315 881,317 881 317
224 SNPPS 488,756 331 804 156,952 156,952
225 320,388 282 119 038 269 038,269
226
227 503 Steam From Other Sources
228 110 724 905 987 204 737 57,427 262,164
229 110,724 905,987 204 737 57,427 262 164
230
231 505 Electric Expenses
232 SNPPS 862 058 681 564 180 494 180,494
233 SNPPS 353,346 267 998 348 348
234 215,405 949 562 265,842 265,842
235
236 506 Misc. Steam Expense
237 SNPPS 28,907 136 084 123 823 014 823 014
238
239 SNPPS 783,535 671 058 112,478 112,478
240 690 672 755 180 935,492 935,492
241
242 507 Rents
':'43 SNPPS 050 584 984 329 66,255 255
SNPPS 122 887 115 138 750 750
245 173,471 099 467 004 004
246
247 510 Maint Supervision & Engineering
248 SNPPS 171,457 845 321 326,135 326 135
249 SNPPS 2,432 903 279,473 153,430 153,430
250 604 360 124 794 479,565 479 565
251
252
253
254 511 Maintenance of Structures
255 SNPPS 800 652 614 998 185,654 185 654
256 SNPPS 675,302 632 714 588 42,588
257 475 953 18,247 712 228,241 228 241
258
259 512 Maintenance of Boiler Plant
260 SNPPS 213 304 713,241 500,063 500 063
261 SNPPS 033 533 842 225 191 308 191 308
262 90,246,837 555,466 691 371 691 371
263
264 513 Maintenance of Electric Plant
265 SNPPS 859,935 850,704 009 231 009 231
266 SNPPS 646 757 605 970 787 787
267 506 692 30,456,674 050 018 050,018
268
269 514 Maintenance of Misc. Steam Plant
270 SNPPS 115,402 540 543 574 858 163 894 738,752
271 SNPPS 501 736 343,965 157 771 157 771
272 617 137 884 508 732 629 163 894 896 523
273
274 Total Steam Power Generation 740,727,406 692,670,254 057,153 066,259 52,123,411
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
'275 517 Operation Super & Engineering
~76 SNPPN
2.77
278
279 518 Nuclear Fuel Expense
280
281
282
283
284 519 Coolants and Water
285 SNPPN
286
287
288 520 Steam Expenses
289 SNPPN
290
291
292
293
294 523 Electric Expenses
295 SNPPN
296
297
298 524 Misc. Nuclear Expenses
299 SNPPN
300
301
302 528 Maintenance Super & Engineering
303 SNPPN
304
305
306 529 Maintenance of Structures
307 SNPPN
308
109
;10 530 Maintenance of Reactor Plant
J11 SNPPN
312
313
314 531 Maintenance of Electric Plant
315 SNPPN
316
317
318 532 Maintenance of Misc Nuclear
319 SNPPN
320
321
322 Total Nuclear Power Generation
323
324 535 Operation Super & Engineering
325 DGP
326 SNPPH 867,553 560 583 306,970 110 348 080
327 SNPPH 581,405 2,418,610 162 795 162 795
328
329 448 958 979 193 469,765 110 510,875
330
331 536 Water For Power
332 DGP
333 SNPPH 157 569 147 632 937 937
334 SNPPH 976 78,680 296 296
335
336 241 545 226,312 233 15,233
337
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
138 537 Hydraulic Expenses
139 DGP
340 SNPPH 978,341 727 449 250 892 (965)249,927
341 SNPPH 651 063 610 004 059 059
342
343 629 403 337,452 291 951 (965)290 986
344
345 538 Electric Expenses
346 DGP
347 SNPPH 170 970 200 200
348 SNPPH 616 578
349
350 787 548 239 239
351
352 539 Misc. Hydro Expenses
353 DGP
354 SNPPH 12,660,214 861 804 798,410 (12 907)785,503
355 SNPPH 419 792 077 995 341 796 341 796
356
357
358 080,006 16,939 800 140 206 (12 907)127 299
359
360 540 Rents (Hydro Generation)
361 DGP
362 SNPPH 79,758 729 030 (23)007
363 SNPPH 874 936 938 938
364
365 633 88,665 968 (23)945
366
367 541 Maint Supervision & Engineering
368 DGP
369 SNPPH
370 SNPPH
371
"172
;73
374 542 Maintenance of Structures
375 DGP
376 SNPPH 885,458 829 617 55,841 (48)793
377 SNPPH 186 791 175 011 780 11,780
378
379 072 249 004 628 621 (48)573
380
381
382
383
384 543 Maintenance of Dams & Waterways
385 DGP
386 SNPPH 080 640 012,490 150 755)65,395
387 SNPPH 354,622 332 258 364 364
388
389 435 262 344,748 514 755)87,759
390
391 544 Maintenance of Electric Plant
392 DGP
393 SNPPH 410,100 384 237 25,863 (537)325
394 SNPPH 538 167 504 228 33,939 33,939
395
396 948 267 888,465 59,802 (537)59,265
397
398 545 Maintenance of Misc. Hydro Plant
399 DGP
400 SNPPH 972 072 847 704 124 368 (1,003)123 365
401 SNPPH 571 368 535,335 36,033 36,033
402
403 543 441 383,040 160,401 003)159 398
404
405 Total Hydraulic Power Generation 36,497 550 34,195,851 301,699 22,872 324 572
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
406
407 546 Operation Super & Engineering
408 SNPPO 170,218 096,419 73,799 (763)73,036
409 SNPPO
410 170,218 096,419 799 (763)73,036
411
412 547 Fuel
413 102,611 570 858 025 753 545 107 808 15,861 353
414 082,022 25,299,576 782 447 782,447
415 129,693,593 121 157,601 535,992 107 808 643 800
416
417 548 Generation Expense
418 SNPPO 301,472 777 944 523,528 13,260 536,788
419 SNPPO 900,581 654,592 245,988 245 988
420 12,202 052 11,432 536 769 516 13,260 782,776
421
422 549 Miscellaneous Other
423 SNPPO 930,812 745,982 184 830 489,913 674 744
424 SNPPO
425 930,812 745,982 184 830 489,913 674,744
426
427
428
429
430 550 Rents
431 SNPPO 566,261 530 550 711 (71 004)(35,293)
432 SNPPO 13,076,156 251 515 824 641 824,641
433 13,642,417 782,065 860,352 (71 004)789 348
434
435 551 Maint Supervision & Engineering
436 SNPPO
437
438
439 552 Maintenance of Structures
440 SNPPO 100 339 011 328 328
441 SNPPO 138 686 129 939 746 746
442 239,024 223,950 15,074 074
443
444 553 Maint of Generation & Electric Plant
445 SNPPO 639,986 536,561 103,425 103,425
446 SNPPO 922,328 864,162 58,166 58,166
447 562 314 400,723 161 591 161 591
448
449 554 Maintenance of Misc. Other
450 SNPPO 258 198 241 915 283 283
451 SNPPO 177 890 166,671 219 219
452 436,088 408,586 27,502 502
453
454 Total Other Power Generation 162,876,518 152,247,862 10,628.656 539,214 20,167,870
455
456
457 555 Purchased Power
458 DMSC (111 678 304)(79 926 206)(31 752 098)752 098
459 691 191 252 647 601 628 43,589,624 73,585,491 117 175 115
460 127 941 208 119,520,552 8,420,656 943 356)3,477 300
461 Seasonal Co P
462 DGP
463
464 707,454 156 687 195 974 20,258,182 100,394 234 120 652,416
465
466 556 System Control & Load Dispatch
467 2,484,435 327 755 156 680 314 158,993
468
469 484,435 327 755 156,680 314 158,993
470
471
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
472
173 557 Other Expenses
474 (183 792)(150 819)(32 973)996,370 963 397
475 280,193 920 105 360 088 (122 307)237 781
476 SGCT
477
478
479 TROJP
480
481 53,096 401 769,286 327 115 874 063 201 178
482
483 Embedded Cost Differentials
484 Company Owned Hyc P DGP
485 Company Owned Hyc P
486 Mid-C Contract
487 Mid-C Contract
488 Existing OF Contract~ P
489 Existing OF Contract~ P
490
491
492
493 Total Other Power Supply 763,034,992 739,293,015 741,977 101,270,610 125,012,587
494
495 Total Production Expense 103,136,466 618,406,981 129,485 114,898,955 199,628,440
496
497
498 Summary of Production Expense by Factor
499 (111,862 096)(80 077,026)(31 785,071)32,748,468 963 397
500 746 955,880 699,849 488 106 392 73,465 498 120 571 890
501 745 825 103 696 737,426 087 677 809,526 56,897 203
502 SNPPH 36,497 550 195,851 301 699 872 324 572
503 TROJP
504 SGCT
505 DGP
,06 DEU
DEP
508 SNPPS 252 537 104 236 610 981 926 124 421 185 16.347 308
509 SNPPO 182 925 090,261 092 664 431 406 524 070
510 DGU
511
512 SSGCT
513 SSECT
514 SSGC
515 SSGCH
516 SSECH
517 Total' Production Expense by Factor 703 136 466 618,406 981 729 485 114 898,955 199 628,440
518 560 Operation Supervision & Engineering
519 SNPT 758 554 269 265 489 289 698 505 987
520
521 758 554 269 265 489,289 16,698 505,987
522
523 561 Load Dispatching
524 SNPT 562 245 148 400 413,845 413,845
525
526 562 245 148,400 413 845 413 845
527 562 Station Expense
528 SNPT 320,015 299,834 182 182
529
530 320,015 299 834 182 182
531
532 563 Overhead Line Expense
533 SNPT 320,086 173 771 146 315 146,315
534
535 320 086 173 771 146 315 146 315
536
537 564 Underground Line Expense
538 SNPT
539
,40
ROLLED-Page 9.10
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
142 565 Transmission of Electricity by Others
i43 186 215 624 796 561 419 825 289 386,708
544 924,418 534,493 389 925 (380 314)611
545
546
547 110 633 159 289 951 344 444 975 396 319
548
549 566 Misc. Transmission Expense
550 SNPT 938 870 879 661 59,209 59,209
551
552 938 870 879,661 209 59,209
553
554 567 Rents - Transmission
555 SNPT 343,348 258,631 718 (31 840)52,878
556
557 343,348 258,631 718 (31 840)878
558
559 568 Maint Supervision & Engineering
560 SNPT 19,767 18,520 247 247
561
562 19,767 18,520 247 247
563
564 569 Maintenance of Structures
565 SNPT 958 521 835 008 123,513 (6,306)117 207
566
567 958 521 835.008 123,513 (6,306)117 207
568
569 570 Maintenance of Station Equipment
570 SNPT 10,062 229 9,427 660 634,569 634 569
571
572 062 229 9,427 660 634 569 634 569
573
574 571 Maintenance of Overhead Lines
575 SNPT 812 758 10,130,857 681,901 (65 608)616,294
812 758 130,857 681 901 (65,608)616 294
578
579 572 Maintenance of Underground Lines
580 SNPT
581
582
583
584 573 Maint of Misc. Transmission Plant
585 SNPT 723,453 677 829 45,624 45,624
586
587 723,453 677 829 45,624 624
588
589 Total Transmission Expense 136,930,481 128,278,726 651 756 357,919 009,675
590
591 Summary of Transmission Expense by Factor
592 924,418 534,493 389 925 (380 314)611
593 186 215 624 796 561,419 825,289 386,708
594 SNPT 819 849 119,437 700,412 (87 056)613 356
595 Total Transmission Expense by Factor 136 930,481 128 278 726 651 756 357 919 009 675
596 580 Operation Supervision & Engineenng
597 DPW 722 506 736,966 (14 460)391 (14 069)
598 DPW SNPD 650,460 23,537 166 113 294 (210,424)902 870
599 25,372 966 274 132 098,834 (210 032)888 801
600
601 581 Load Dispatching
602 DPW
603 DPW SNPD 12,310 097 754 134 555,963 328 573 292
604 310 097 754 134 555,963 328 573,292
605
606 582 Station Expense
607 DPW 989 947 696,002 293 945 809 299,754
608 DPW SNPD 165 859 158 368 7,491 128 619
609 155,806 854 370 301,436 937 307 373
,10
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
111 583 Overhead Line Expenses
.12 DPW 597 211 657 946 939 265 939 958 203
613 DPW SNPD 932 158 890 059 099 689 788
614 529,369 16,548,005 981 364 628 000,991
615
616 584 Underground Line Expense
617 DPW 527 073 511 717 356 360 717
618 DPW SNPD
619 527 073 511 717 15,356 360 15,717
620
621 585 Street Lighting & Signal Systems
622 DPW 851 851
623 DPW SNPD 148,456 141 751 705 470 175
624 149,307 142 602 705 470 175
625
626 586 Meter Expenses
627 DPW 678,544 3,493 366 185 179 264 189,442
628 DPW SNPD 448 356 382 943 65,412 533 66,945
629 126 900 876 309 250 591 797 256,388
630
631 587 Customer Installation Expenses
632 DPW
633 DPW SNPD
634
635
636 588 Misc. Distribution Expenses
637 DPW 516,422 174 384 342 038 068 349 106
638 DPW SNPD 341 398 829,184 512 214 19,819 532 033
639 857 820 003 568 854 252 887 881 139
640
641 589 Rents
642 DPW 632 664 600,467 198 32,198
643 DPW SNPD 692,187 660 925 261 261
644 324 851 261 392 63,459 459
'45
590 Maint Supervision & Engineering
647 DPW 226 901 226,901
648 DPW SNPD 283,243 180 125 103 119 211 106,329
649 510,144 2,407,026 103 119 211 106 329
650
651 591 Maintenance of Structures
652 DPW 973 736 866 936 106 800 106,800
653 DPW SNPD 339 217 323 897 320 320
654 312,953 190 832 122 120 122 120
655
656 592 Maintenance of Station Equipment
657 DPW 10,058 873 424 629 634 245 11,090 645 335
658 DPW SNPD 291 132 187 657 103,475 189 107 664
659 350,005 612 286 737 720 15,280 752 999
660 593 Maintenance of Overhead Lines
661 DPW 915,799 951,469 964 330 179,358)784,972
662 DPW SNPD 665,667 545 277 120 390 58,538 178,928
663 85,581,466 80,496,746 084 720 120 821)963 899
664
665 594 Maintenance of Underground Lines
666 DPW 22,136 180 21,476,576 659,604 136)658,468
667 DPW SNPD 139,753 133 442 312 122 434
668 275 933 610,017 665,916 (1,014)664 902
669
670 595 Maintenance of Line Transformers
671 DPW (10,548)(27 172)624 298 16,922
672 DPW SNPD 182 45,051 131 264 395
673 36,634 879 755 562 317
674
675 596 Maint of Street Lighting & Signal Sys.
676 DPW 111 030 948 985 162 044 610 165,654
677 DPW SNPD 814 596 217 223
678 115,843 953 582 162 262 615 165,877
179
ROLLED-Page 9.12
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
'380 597 Maintenance of Meters
381 DPW 185 839 942 984 242,855 750 248 605
682 DPW SNPD 914 197 827 745 86,451 602 053
683 100,036 770,730 329,306 352 337 658
684
685 598 Maint of Misc. Distribution Plant
686 DPW 197 670 192 994 677 728
687 DPW SNPD (14 453)(13,800)(653)109 4,456
688 183,218 179 194 024 160 184
689
690 Total Distribution Expense 218,820,422 207,464,521 355,901 (1,219,279)10,136,621
691
692
693 Summary of Distribution Expense by Factor
694 157,460,701 148,876 001 584 699 122,863)7,461 836
695 SNPD 61,359 721 588,520 771 202 (96,416)674 785
696
697 Total Distribution Expense by Factor 218,820,422 207,464 521 355,901 219 279)136,621
698
699 901 Supervision
700 GUST 762 498 384 658 377 840 824 385 664
701 GUST 957 030 716 688 240 341 504 246,845
702 10,719,527 10,101 346 618,181 328 632 509
703
704 902 Meter Reading Expense
705 GUST 26,360 168 25,076,592 283,576 252 317 828
706 GUST 468 178 449 289 18,889 (101 161)(82 272)
707 26,828,346 25,525,881 302,465 (66 910)235 555
708
709 903 Customer Receipts & Collections
710 GUST 080,040 835,385 244 654 543 251 197
711 GUST 869 152 978,176 890,976 920 942,895
712 949,192 50,813,562 135,630 462 194 092
713
904 Uncollectible Accounts
GUST 9,499,899 236,719 263,180 263 180
716
717 GUST 593 398 327 382 266,016 (55 562)210,454
718 093,297 15,564 101 529,196 (55,562)473 634
719
720 905 Misc, Customer Accounts Expense
721 GUST 445 445
722 GUST 242 525 192 394 131 229 359
723 273 970 223,839 50,131 229 50,359
724
725 Total Customer Accounts Expense 107,864,332 103,228,728 635,604 (49,453)586,151
726
727 Summary of Customer Accts Exp by Factor
728 46,734,050 564,799 169,251 618 217 869
729 130 282 58,663,929 466,353 (98 071)368,282
730
731 Total Customer Accounts Expense by Factor 107 864 332 103,228 728 635 604 (49,453)586 151
732
733 907 Supervision
734 GUST
735 GUST 301 809 249,286 523 703 226
736 301 809 249 286 523 703 53,226
737
738 908 Customer Assistance
739 GUST 562 065 822 263 739 803 (1,365 964)373 838
740 GUST 148 849 981,461 167 389 (57 062)110,327
741
742
743 710 915 803 723 907 191 (1,423,026)1,484 165
744
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
745 909 Informational & Instructional Adv
'46 GUST 630 967 584 787 46,181 181
747 GUST 989 708 869 086 120 622 (53 979)643
748 620,675 3,453 873 166 803 (53 979)112 824
749
750 910 Misc. Customer Service
751 GUST 060 85,597 10,463 10,463
752 GUST 911 511 400 400
753
754 105 971 95,108 863 863
755
756 Total Customer Service Expense 52,739,370 49,601 990 137,380 (1,476,302)661 078
757
758
759 Summary of Customer Service Exp by Factor
760 289 093 41,492 646 796,446 365,964)1,430,482
761 8,450,277 109 344 340,934 (110,338)230 596
762
763 Total Customer Service Expense by Factor 739 370 49,601 990 137 380 (1,476 302)661 078
764
765
766 911 Supervision
767 GUST
768 GUST
769
770
771 912 Demonstration & Selling Expense
772 GUST
773 GUST
774
775
776 913 Advertising Expense
777 GUST
778 GUST
779
181 916 Misc. Sales Expense
782 GUST
783 GUST
784
785
786 Total Sales Expense
787
788
789 Total Sales Expense by Factor
790
791
792 Total Sales Expense by Factor
793
794 Total Customer Service Exp Including Sales 52,739,370 49,601,990 137,380 (1,476,302)661 078
795 920 Administrative & General Salaries
796 PTD 639 855 639,855
797 GUST
798 PTD 141 303,971 132 997 376 306,595 050,907)255,688
799 142 943 826 134,637 231 306 595 050 907)255 688
800
801 921 Office Supplies & expenses
802 PTD (433 633)(434 262)629 629
803 GUST 041 999
804 PTD 10,486,023 869 600 616,424 (55,089)561 335
805 053,431 9,436,336 617 095 (55 089)562 006
806
807 922 A&G Expenses Transferred
808 PTD
809 GUST
810 PTD (23 386 081)(22 011 323)(1,374 758)(102)374 860)
811 (23,386 081)(22 011 323)374 758)(102)374 860)
812
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
113 923 Outside 5ervices
:14 PTD 403 391
815 CU5T
816 PTD 18,368,024 288,254 079 770 (107 819)971 950
817 18,460,427 380,645 079 781 (107 819)971 962
818
819 924 Property Insurance
820 PTD 23,392,399 017 270 375 129 375,129
821 23,392 399 22,017 270 375 129 375,129
822
823 925 Injuries & Damages
824 PTD 10,053,029 462 059 590 970 590,970
825 053 029 9,462 059 590,970 590,970
826
827 926 Employee Pensions & Benefits
828 LABOR
829 CU5T
830 LABOR
831
832
833 927 Franchise Requirements
834 DM5C
835 DM5C
836
837
838 928 Regulatory Commission Expense
839 DM5C 234 710 920 106 314 605 314 605
840 CU5T
841 DM5C 527 1,437
842 FERC 198 856 123,251 605 75,605
843 8,435,094 044 794 390,300 390,300
844
845 929 Duplicate Charges
846 LABOR
. \47 LABOR 238,413)(8,695,330)(543 083)604)(545 686)
238,413)695 330)(543,083)604)(545,686)
849
850 930 Misc General Expenses
851 PTD 13,150,472 076 147 325 28,865 103 190
852 CU5T 485 72,439 045 045
853 LABOR 162,922 330 350 832 571 542 136 374 707
854 388 879 26,478,937 909 942 571 001 2,480,942
855
856 931 Rents
857 PTD 714 714
858 PTD 188 579 707 211 481 368 (78 333)403,035
859 197 293 715,925 481 368 (78 333)403,035
860
861 935 Maintenance of General Plant
862 352 342 308,069 274 118 391
863 CU5T 005 302 703 703
864 256 696 948,329 308 366 119 973 428 339
865 676 043 21,320 700 355 343 121 091 1,476,434
866
867 Total Administrative & General Expense 238,975,926 225,787,243 13,188,683 (1,602 763)11,585,920
868
869 5ummary of A&G Expense by Factor
870 044 864 611 020 433 844 29,983 463,827
871 215,588,676 202 915 233 673 442 632 745)040 697
872 198 856 123 251 605 75,605
873 143 531 137 740 791 791
874 Total A&G Expense by Factor 238,975 926 225,787 243 188 683 602 763)585 920
875
876 Total O&M Expense 458,466,997 332 768 189 125,698,808 110,909,078 236,607,886
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
0,77 403SP Steam Depreciation
178 38,067 698 35,666 978 2,400 720 2,400 720
879 102,483 38,510,375 592 107 592 107
880 223 994 993,579 230 415 365 623 596,038
881 977 377 8,411 224 566,154 566 154
882 139,371 552 130 582 156 789,396 365,623 155 018
883
884 403NP Nuclear Depreciation
885
886
887
888 4O3HP Hydro Depreciation
889 170 500 844 425 326 075 326 075
890 227 723 150,298 426 77,426
891 341 805 004 927 336 878 (28 961)307 917
892 1,472 897 380 010 888 888
893 212 926 379 660 833 266 (28,961)804 305
894
895 4030P Other Production Depreciation
896 42,197 536 661 661
897 514 823 16,410,259 104 563 016,657 121 220
898 161 217 961 856 199,361 199,361
899
900 20,718,236 411 651 306,585 016 657 323 242
901
902 403TP Transmission Depreciation
903 338 372 560,259 778 113 778,113
904 13,404,865 559 494 845,371 845 371
905 173 292 333,493 839 799 165,396 005,195
906 54,916 530 453 247 3,463,283 165 396 628,679
907
908
909
910 403 Distribution Depreciation
911 360 Land & Land Righls DPW 272 235 254 766 469 17,469
112 361 Structures DPW 845 531 831 123 408 408
\113 362 SlationEqlOpmem DPW 13,447 237 080 774 366 463 366,463
914 363 SlorageBatteryEql DPW 145,834 145,834
915 364 Poles & Towers DPW 000 531 031 839 968 692 124 565 093 257
916 365 OH Conductors DPW 16,201 694 338 992 862 702 862,702
917 366 UG Conduit DPW 226 098 078,850 147 248 147 248
918 367 UG Conductor DPW 094 024 654 398 439 627 439 627
919 368 Line Trans DPW 304 443 992 342 312 101 312 101
920 369 Services DPW 126,537 641 838 484 699 484,699
921 370 Meters DPW 6,423 840 964 957 458 883 458 883
922 371 11151 Gust Prom DPW 381 075 373,838 237 237
923 372 Leased Property DPW 293 166 127 127
924 373 SbeetLigtting DPW 309 814 278 318 496 496
925 123 780,186 117 669,035 111 151 124 565 235 716
926
927 403GP General Depreciation
928 SITUS 076,085 211 700 864 385 864,385
929 DGP 482 726 452 283 30,443 443
930 DGU 874 488 819 339 149 149
931 026 29,918 108 108
932 GUST 375,422 319 930 493 55,493
933 720 321 4,422 636 297 685 2,498 300,183
934 PTD 18,410,269 328 016 082 253 583 089 836
935 322 12,482 840 840
936 192 704 180 551 153 153
937 177 362 776,854 400 508 081 2,410,589
938
939 403GVO General Vehicles
940 G-5G
941
942
943 403MP Mining Depreciation
944 982 982
945 982 982
146
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FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
947 403EP Experimental Plant Depreciation
!48
949
950
951 4031 ARO Depreciation
952
953
954
955
956 Total Depreciation Expense 391 176,792 368,272 603 22,904,189 678,342 582,531
957
958 Summary 136 856 270 129,880,735 975,536 124 565 100,101
959 DGP
960 DGU
961 234 502 804 219,714 005 788,800 521 213 16,310,012
962 18,410 269 328 016 082 253 583 089 836
963 375,422 319,930 55,493 55,493
964 026 918 108 982 090
965 SSGCH
966 SSGCT
967 Total Depreciation Expense 8y Factor 391 176 792 368 272 603 22,904 189 678,342 582 531
968
969 404GP Amort of L T Plant - Capital Lease Gen
970 SITUS 123 509 123 509
971
972 PTD 941 179 827 067 114 113 114 113
973 DGU
974 GUST 214 060 205 424 636 636
975 DGP
976 278 749 155 999 122 749 122 749
977
978 404SP Amort of L T Plant - Cap Lease Steam
979
980
q81
182
983 4O41P Amort of L T Plant - Intangible Plant
984 SITUS 609 200 20,409 162 571
985 809 624 185 185
986 290,254 893 562 396 692 85,239 481,931
987 PTD 626 700 28,826,301 800,399 297 828 696
988 GUST 555,055 371 278 183 778 183,778
989 2,471 230 315,383 155 847 155 847
990 397 626 372 550 25,076 25,076
991 DGP 84,454 79,128 326 326
992
993 777 5,413 364 364
994 DGU 380 221 159 159
995 521 894 932 659 589 235 140,698 729,933
996
997 404MP Amort of L T Plant - Mining Plant
998
999
1000
1001 4040P Amort of L T Plant - Other Plant
1002 240 199 225 051 15,148 148
1003 240,199 225,051 148 15,148
1004
1005
1006 404HP Amortization of Other Electric Plant
1007 511 353 158 158
1008 37,428 068 360 360
1009
1010 940 37,421 519 519
1011
1012 Total Amortization of Limited Term Plant 080,782 45,351,131 729,651 140,698 870,349
1013
1014
1015 405 Amortization of Other Electric Plant
016
1017
1018
1019
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
'020 406 Amortization of Plant Acquisition Adj
021
1022
1023
1024 5,479,353 133,800 345 553 345,553
1025
1026 5,479,353 133 800 345 553 345 553
1027 407 Amort of Prop Losses, Unrec Plant, etc
1028 DPW 363,418 363 418
1029
1030
1031
1032 333,105 312,098 007 007
1033 TROJP 674 863 568 538 106,325 106,325
1034 371 386 244 054 127 332 127 332
1035
1036 Total Amortization Expense 62,931,521 59,728 985 202,536 140,698 343 233
1037
1038
1039
1040 Summary of Amortization Expense by Factor
1041 556,536 536,127 20,409 162 571
1042 809 624 185 185
1043 TROJP 674,863 568 538 106 325 106 325
1044 DGP
1045 DGU
1046 567 880 30,653 368 914 512 297 942 809
1047 SSGCT
1048 SSGCH
1049 769,116 576,702 192,414 192 414
1050 15,360,318 391 627 968,691 239 053 930
1051 Total Amortization Expense by Factor 931 521 728 985 202 536 140 698 343 233
1052 408 Taxes Other Than Income
1053 DMSC 20,839,643 20,839,643
054 GPS 71,469 505 268,149 201 355 217,647 4,419,002
)55 326,867 837 369 489,497 489,497
1056 398,457 372 232 225 26,225
1057
1058 DMSC OPRV-
1059 EXCTAX
1060
1061
1062
1063
1064 Total Taxes Other Than Income 101,034,471 96,317 393 717,078 217 647 934,724
1065
1066
1067 41140 Deferred Investment Tax Credit - Fed
1068 PTD DGU (5,854,860)097 070)(757 790)(757 790)
1069
1070 (5,854,860)097 070)(757 790)(757 790)
1071
1072 41141 Deferred Investment Tax Credit - Idaho
1073 PTD DGU
1074
1075
1076
1077 Total Deferred ITC (5,854,860)(5,097,070)(757 790)(757 790)
1078
ROLLED-Page 9.18
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
079
080 427 Interest on Long-Term Debt
1081 857,469 857 469
1082 SNP 245 313,780 231 302 250 011,530 011 530
1083 245 313,780 231 302 250 011 530 857,469 868 998
1084
1085 428 Amortization of Debt Disc & Exp
1086 SNP 627,114 134 361 492 753 492 753
1087 627 114 134 361 492 753 492 753
1088
1089 429 Amortization of Premium on Debt
1090 SNP (86,967)(82,000)(4,967)967)
1091 (86 967)(82 000)967)967)
1092
1093 431 Other Interest Expense
1094 NUTIL OTH
1095
1096 SNP 26,043 696 556,164 1,487 532 1,487 532
1097 043,696 556 164 487,532 487 532
1098
1099 432 AFUDG - Borrowed
1100 SNP (22 680 359)(21 384 930)295,429)295,429)
1101 (22 680,359)(21 384 930)295,429)295,429)
1102
1103 Total Elec. Interest Deductions for Tax 257 217 264 242 525,845 691,418 857,469 548 887
1104
1105 Non-Utility Portion of Interest
1106 427 NUTIL NUTIL
1107 428 NUTIL NUTIL
1108 429 NUTIL NUTIL
1109 431 NUTIL NUTIL
1110
1111 Total Non-utility Interest
1112
113 Total Interest Deductions for Tax 257 217,264 242 525 845 691,418 857 469 16,548,887
114
1115
1116 419 Interest & Dividends
1117
1118 SNP (23,612 825)(22 264 137)348 688)348 688)
1119 Total Operating Deductions for Tax (23,612,825)(22 264 137)348 688)348 688)
1120
1121
1122 41010 Deferred Income Tax - Federal-
1123 294 175,203 280 847,321 13,327 882 042 13,333,924
1124 TROJD 25,516 894 622 622
1125 DGP 265 265
1126 LABOR 340,317 676,274 664 043 664,043
1127 SNP 56,246 033 213 213
1128 972,412 815 031 157 381 65,619 223 000
1129 923,383 612,892 310,491 (136 257)174 234
1130 GPS 266,635 663 108 603,527 603 527
1131 DITEXP DITEXP 950,906 950,906
1132 GUST BADDEBT 10,492 884 147 846 345,038 345,038
1133 GUST 19,848 047 801 801
1134 SGCT
1135 DPW SNPD 320 154 305,695 14,459 14,459
1136 447 596 863 425 168,406 22,428,457 886,310 23,314 767
1137
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1138
139
1140 41110 Deferred Income Tax - Federal-
1141 (262,338 420)(251 160,459)(11 177 961)(10,308)(11 188,269)
1142 (32 668,592)(30 518,456)(2,150,136)(142,875)(2,293,011)
1143 DGP (362 775)(362 775)
1144 SNP 469 355)(3,271 197)(198 158)(198 158)
1145 (30 799 515)(28 857 159)942,356)98,151 844,204)
1146 GPS 555,281)463 853)(91,428)(91,428)
1147 LABOR (84 366 245)(79,406,751)959,494)959,494)
1148 SNPD 191 311)092 344)(98 967)(98 967)
1149 GUST (3,564)(3,420)(144)(144)
1150 GUST BADDEBT 093 241)057 292)(35,949)(35,949)
1151 DITEXP DITEXP
1152 TROJD (947 126)(886,930)(60,196)(60 196)
1153 SGCT (623 386)(583,917)(39,469)(39,469)
1154
1155
1156 (420,418 811)(399,664 555)(20 754 257)(55,032)(20 809 288)
1157
1158 Total Deferred Income Taxes 178,051 25,503,851 674 200 831,278 505,478
1159 SCHMAF Additions - Flow Through
1160 SCHMAF
1161 SCHMAF SNP
1162 SCHMAF
1163 SCHMAF
1164 SCHMAF TROJP
1165 SCHMAF
1166
1167
1168 SCHMAP Additions - Permanent
1169 645,089 645,089
1170 332 156 244,478 678 (52,456)35,222
1171 LABOR SNP 652,931 444 288 208 644 208 644
172 SCHMAP-178,251 756,275 421 976 421 976
173 DPW BADDEBT 229 804 090 715 139 089 139 089
1174 18,038,231 180,845 857 386 (52 456)804 930
1175
1176 SCHMAT Additions - Temporary
1177 SCHMAT-SITUS S 38,508,157 37,494 227 013,930 27,162 041 092
1178 SGCT 642,607 538 608 103 999 103 999
1179 DPW CIAC 878,139 225,423 652 716 652 716
1180 SCHMAT-SNP SNP 505,411 020 523 2,484 888 484,888
1181 TROJD 562 598 399,729 162 870 162 870
1182
1183 SCHMAT-688 072 129,003 559 069 376,498 935,566
1184 15,445,832 14,471 748 974 083 (86,849)887 235
1185 SCHMAT-GPS GPS (15,789 551)(14 861 358)(928 193)(928,193)
1186 SCHMAT-839 172)672 270)(166 902)(166 902)
1187 SCHMAT-SNP SNPD 122,090 168,149 953,941 953,941
1188 GUST 161 993 168 168
1189 DPW BAD DEBT
1190 BOOKDEPR SCHMDEXP 413,279,041 389 080,721 198 320 627,538 25,825,859
1191 622 007 385 587 998 496 008 889 944,349 35,953,238
1192
1193 TOTAL SCHEDULE - M ADDITIONS 640,045,616 605 179,341 34,866,275 891,894 758,169
1194
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Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1195 SCHMDF Deductions - Flow Through
196 SCHMDF
1197 SCHMDF DGP 6,423 6,423
1198 SCHMDF DGU
1199 .423 6,423
1200 SCHMDP Dedl.:ctions - Permanent
1201 SCHMDP
1202 785 742 19,417 695 368,047 (582 148)785,899
1203 PTD SNP 428,811 404 319 24,492 24,492
1204 SCHMDP IBT
1205 375 720 973 638 402,082 533 463 615
1206 SCHMDP-30,674 719 28,871,497 803 222 (468,695)334,527
1207 58,264 992 54,667 149 597 843 (989 310)608,533
1208
1209 SCHMDT Deductions - Temporary
1210 612 678 511 298 101 380 101 380
1211 DPW BADDEBT 768 251 953 795 814,455 814,455
1212 SCHMDT-SNP SNP 264 746 136,304 128 442 128,442
1213 GUST DGP (70 183)(70 183)
1214 667 139 25,846,182 820 957 172 909 993,866
1215 SCHMDT-362 309 771 880 590,429 (187 255)403 174
1216 SCHMDT.GPS GPS 738,154 60,932,503 805 651 805,651
1217 SCHMDT-29,571 621 833 245 738,376 738 376
1218 TAXDEPR TAXDEPR 476,219,081 448 335,495 883 586 088 884 972,470
1219 DPW SNPD 775 979 796 796
1220 676,173,570 637 288,497 885 073 074 538 959,611
1221
1222 TOTAL SCHEDULE - M DEDUCTIONS 734,444 985 691 962 068 482 916 085,228 46,568,144
1223
1224 TOTAl SCHEDULE - M ADJUSTMENTS (94,399,368)(86,782,727)616,641)(2,193,334)809,976)
1225
1226
1227
1228 40911 State Income Taxes
'229 IBT IBT 945,018 288,151 656 867 (61 906)594,961
230 IBT IBT
1231 IBT IBT
1232 IBT IBT
1233 Total State Tax Expense 945,018 288 151 656,867 (61,906)594,961
1234
1235
1236 Calculation of Taxable Income:
1237 Operating Revenues 745,309 919 553 591 476 191 718,442 116,488,122 308 206,564
1238 Operating Deductions:
1239 0 & M Expenses 2,458,466 997 332 768 189 125,698,808 110,909,078 236,607 886
1240 Depreciation Expense 391 176 792 368,272 603 904 189 678 342 582 531
1241 Amortization Expense 931 521 59,728,985 202 536 140 698 343 233
1242 Taxes Other Than Income 101 034 471 317 393 717,078 217 647 934,724
1243 Interest & Dividends (AFUDC-Equity)(23 612 825)(22 264,137)348 688)348 688)
1244 Misc Revenue & Expense (15,439,233)(14 415,638)023 595)855 123 (168,472)
1245 Total Operating Deductions 974 557 723 820,407 395 154 150,327 113 800,887 267 951 214
1246 Other Deductions:
1247 Interest Deductions 257 217,264 242 525 845 691,418 857,469 548,887
1248 Interest on PCRBS
1249 Schedule M Adjustments (94 399 368)(86 782 727)616 641)193 334)809 976)
1250
1251 Income Before State Taxes 419 135 565 403 875 509 15,260 056 363,568)896,488
1252
1253 State Income Taxes 945 018 288 151 656,867 (61 906)594 961
1254
1255 Total Taxable Income 401 190 547 386 587 358 603,189 301 662)13,301 526
1256
1257 Tax Rate 35.35.35.35.35.
1258
1259 Federal Income Tax - Calculated 140,416,691 135,305,575 111 116 (455 582)655,534
1260
1261 Adjustments to Calculated Tax:
1262 40910 EnergyCred,(787 256)(787 256)
1263 40910 DMD
264 FITOTH FrTTrue-tJP NUTIL OTH
1265 40910 IRS Settle LABOR
1266 Federal Income Tax Expense 140,416,691 135,305,575 111,116 (1,242,838)868,278
1267
1268 Total Operating EJCnenses 177,855 448 015,672,040 162,183,408 113,327,422 275,510 830
ROLLED-Page 9.21
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
1269 310 Land and land Rights
270 329 517 182,608 146,910 146 910
271 680 486 32,493 379 187 107 187 107
1272 642 756 827 384 815 373 815,373
1273
1274 238,960 160 825 134 134
1275 891 720 664 196 227 524 227 524
1276
1277 311 Structures and Improvements
1278 236 722 536 221 793,750 928,786 928 786
1279 328,619 328 307 895,118 20,724 210 724 210
1280 162 902,709 152 629 333 273 376 10,273,376
1281 396,937 43,470 937 925,999 925,999
1282 774 641 511 725 789,139 48,852 372 852 372
1283
1284 312 Boiler Plant Equipment
1285 745,671,241 698 645 864 025 377 025,377
1286 700 973,177 656 766 661 206,516 206,516
1287 989,822 653 927 399,992 422 661 62,422,661
1288 224 506 333 210 347 955 158,377 158,377
1289 660,973,404 2,493 160,473 167 812 931 167 812 931
1290
1291 314 Turbogenerator Units
1292 152 275,185 142 672,028 603,157 603,157
1293 154,459,967 144 719 028 740,939 740 939
1294 365 986 325 342 905,584 080,741 755,143 30,835,884
1295 299 098 000 882 298 216 298 216
1296 725 020 575 679,297 522 45,723,053 755 143 53,478,196
1297
1298 315 Accessory Electric Equipment
1299 88,535,143 951 719 583,424 583 424
1300 139 836 986 131 018 238 818 748 818,748
1301 55,820,744 300,437 520,307 520,307
1302 46,772 142 822,481 949 661 949 661
1303 330,965,015 310,092 875 20,872 140 20,872,140
304
305
1306
1307 316 Misc Power Plant Equipment
1308 5,450,462 106,732 343,731 343,731
1309 190,450 736 988 453,462 453,462
1310 714 164 10,038,480 675,683 675,683
1311 139,216 941 243 197 973 197 973
1312 494 291 823,442 670,849 670,849
1313
1314 317 Steam Plant ARO
1315
1316
1317
1318 Unclassified Steam Plant - Account 300
1319 530,469 307 822 222 647 222 647
1320 530,469 307 822 222 647 222,647
1321
1322
1323 Total Steam Production Plant 604,516,986 314,135,470 290,381,516 755,143 298,136,659
1324
1325
1326 Summary of Steam Production Plant by Factor
1327
1328 DGP
1329 DGU
1330 604 516 986 314,135 470 290 381 516 755,143 298,136 659
1331 SSGCH
1332 Total Steam Production Plant by Factor 604,516 986 314 135,470 290,381 516 755,143 298 136,659
1333 320 Land and land Rights
1334
1335
1336
1337
338 321 Structures and Improvements
339
1340
1341
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1342
343 322 Reactor Plant Equipment
344
1345
1346
1347
1348 323 Turbogenerator Units
1349
1350
1351
1352
1353 324 land and land Rights
1354
1355
1356
1357
1358 325 Misc. Power Plant Equipment
1359
1360
1361
1362
1363
1364 Unclassified Nuclear Plant - Acct 300
1365
1366
1367
1368
1369 Total Nuclear Production Plant
1370
1371
1372
1373 Summary of Nuclear Production Plant by Factor
1374 DGP
1375 DGU
1376
377
378 Total Nuclear Plant by Factor
1379
1380 330 land and land Rights
1381 610,163 941 039 669,125 669 125
1382 311 339 976 382 334 957 334,957
1383 081 722 887 375 194 347 (7)194 340
1384 635 700 595,610 090 40,090
1385 19,638,924 18,400,405 238,519 (7)238 511
1386
1387 331 Structures and Improvements
1388 822,424 446,204 376,220 376,220
1389 462 731 055 162 407 569 407 569
1390 264,144 283,455 980,689 (25 510)955 179
1391 608,150 254,475 353,675 353 675
1392 157 449 76,039 296 118,153 (25 510)092 643
1393
1394 332 Reservoirs, Dams & Waterways
1395 158 239 016 148 259 753 979 263 979 263
1396 880,011 20,500 159 379,852 379 852
1397 544 643 221 910 322 733 (28,519)294 214
1398 34,492 017 316,795 175,221 175 221
1399 283,155 686 265 298,618 17,857 069 (28 519)828,550
1400
1401 333 Water Wheel, Turbines, & Generators
1402 617 069 29,623 155 993,914 993 914
1403 006 605 375 543 631 061 631 061
1404 36,263 262 33,976 338 286,924 (41 646)245 278
1405 163 892 585,976 577 916 577 916
1406 050,827 561 011 5,489,816 (41 646)448,170
1407
1408 334 Accessory Electric Equipment
1409 920 654 547 271 373,383 373 383
1410 347 224 073,069 274 155 274 155
411 077 128 369 522 707 605 (12 849)694 757
412 661 297 3,430,399 230,898 230,898
1413 006,303 420,261 586 042 (12 849)573,193
1414
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1415
416
417 335 Misc. Power Plant Equipment
1418 1 ,548,634 1,450 970 664 664
1419 218,684 204 893 791 791
1420 053,298 986,873 66,426 (735)65,691
1421 63,474 59,471 003 003
1422 884 090 702 206 181 884 (735)181 149
1423
1424 336 Roads, Railroads & Bridges
1425 577 915 289,211 288,704 288,704
1426 843,537 790 340 197 197
1427 7,472 246 001 013 471 233 535)469,698
1428 550 271 515,568 703 34,703
1429 443,969 596 132 847 837 535)846 302
1430
1431 337 Hydro Plant ARO
1432
1433
1434
1435 Unclassified Hydro Plant - Acct 300
1436
1437
1438
1439
1440
1441
1442 Total Hydraulic Production Plant 528,337,249 495,017 929 33,319,319 (110,801)208,519
1443
1444 Summary of Hydraulic Plant by Factor
1445
1446 528 337 249 495,017 929 33,319,319 (110 801)208,519
1447 DGP
1448 DGU
1449 Total Hydraulic Plant by Factor 528 337 249 495 017 929 319 319 (110 801)208 519
450
.451 340 Land and Land Rights
1452 522 127 20,164 845 357 282 357 282
1453
1454
1455 522 127 164 845 357 282 357,282
1456
1457 341 Structures and Improvements
1458 716,059 022 192 693,866 693,866
1459 172,431 161 557 874 874
1460 233,108 966 149 266,959 266,959
1461 121 598 149 898 971 700 971 700
1462
1463 342 Fuel Holders, Producers & Accessories
1464 15,182 356 14,224 889 957,468 957 468
1465 121 339 113 687 652 652
1466 270 194 127 025 143,169 143,169
1467 573,889 16,465 600 108 288 108 288
1468
1469 343 Prime Movers
1470
1471 790,414 740 567 847 847
1472 352,435,391 330 209 232 226 158 22,226 158
1473 100 452 877 828 222 624 222 624
1474 404 326,256 378 827 627 25,498 629 25,498,629
1475
1476 344 Generators
1477
1478 394 856 538 538
1479 88,510,625 928 748 581 877 025,268 35,607 146
1480 873 643 872 580 001 063 001,063
1481 104,408,663 824 184 584 479 025,268 609 747
ROLLED-Page 9.
Beginning/Ending
FERC 8US PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
1482
~83 345 Accessory Electric Plant
484 28,928 280 103,933 824 347 824 347
1485 157 127 147 218 909 909
1486 005,055 689,414 315 641 315,641
1487 090,462 940 564 149,898 149 898
1488
1489
1490
1491 346 Misc. Power Plant Equipment
1492 668 992 3,437 609 231 383 231 383
1493 813 068 745 745
1494 680 805 448,677 232 128 232 128
1495
1496 347 Other Production ARO
1497
1498
1499
1500 Unclassified Other Prod Plant-Acet 300
1501
1502
1503
1504
1505 Total Other Production Plant 632,723,800 592,821,396 39,902,404 30,025,268 69,927,672
1506
1507 Summary of Other Production Plant by Factor
1508
1509 DGU
1510 632 723,800 592.821 396 902,404 025.268 927 672
1511 SSGCT
1512 Total of Other Production Plant by Factor 632,723 800 592,821 396 39,902 404 025 268 69,927 672
1513
1514 Experimental Plant
1515 103 Experimental Plant
1516
517 Total Experimental Production Plant
518
1519 Total Production Plant 765,578 034 401 974,795 363,603,239 37,669,610 401,272,849
1520 350 land and land Rights
1521 22.891 863 448,199 443,664 443,664
1522 957 004 45,869 555 087 448 087 448
1523 18,586 819 17,414 651 172 168 069)171 100
1524 90,435,685 732,405 703 280 069)702 212
1525
1526 352 Structures and Improvements
1527
1528 682 526 198,031 484 495 484,495
1529 268,880 116 762 152 118 152 118
1530 307 024 584 921 722 104 722 104
1531 258,430 49,899,714 358.716 358,716
1532
1533 353 Station Equipment
1534 135 538 265 126,990 613 547 652 547 652
1535 198 842 629 186 302 720 539 909 539 909
1536 597 305 678 559 636 900 668,778 (55.301 613,477
1537 931 686 572 872,930,234 756,339 (55,301)701 037
1538
1539 354 Towers and Fixtures
1540 156,406,453 146 542 760 863 693 863,693
1541 127 021 570 119,011 020 010,551 010 551
1542 301 738 86,480 776 820,962 (521)820,441
1543 375 729 761 352.034,555 695 206 (521)694 684
1544
1545 355 Poles and Fixtures
1546 318 178 64,946,662 371 516 371 516
1547 119 372 807 111 844 622 528 185 528,185
1548 315 931 877 296,007 794 19,924 083 507 038 27,431 120
1549 504 622 862 472 799 078 823 783 507 038 39,330,821
1550
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
1551 356 Clearing and Grading
552 208,026 202 194 907 135 13,119 066 13,119,066
553 158 802,308 148,787 522 014 787 014 787
1554 283 157 381 265 300 205 857 176 306)853 870
1555 649,985,891 608 994 862 991 029 306)40,987 723
1556
1557 357 Underground Conduit
1558 371 969 402 402
1559 162 746 152,483 10,264 264
1560 654,227 2,486,839 167 387 167 387
1561 823,344 645 292 178 053 178,053
1562
1563 358 Underground Conductors
1564
1565 018,663 954,421 241 241
1566 590 794 301 278 289 516 289,516
1567 609 457 255 700 353 758 353,758
1568
1569 359 Roads and Trails
1570 905 513 785 343 120,170 120 170
1571 501 203 469 595 608 608
1572 028,885 8,459,483 569,402 569 402
1573 435 602 10,714 422 721 180 721 180
1574
1575 Unclassified Trans Plant - Acet 300
1576 918,405 608 228 310,177 310 177
1577 918,405 608 228 310 177 310,177
1578
1579 TSO Unclassified Trans Sub Plant - AccI 300
1580
1581
1582
1583 Total Transmission Plant 630,506,009 464,614,489 165,891,520 446,841 173,338,361
1584 Summary of Transmission Plant by Factor
1585 DGP
586 DGU
587 630 506,009 464 614,489 165 891 520 446,841 173 338,361
1588 Total Transmission Plant by Factor 630,506,009 464 614 489 165 891 520 446 841 173,338,361
1589 360 Land and Land Rights
1590 DPW 40,648,572 442 208 206,363 206 363
1591 648 572 442 208 206 363 206,363
1592
1593 361 Structures and Improvements
1594 DPW 43,962,426 187 867 774 559 774 559
1595 962,426 187 867 774 559 774 559
1596
1597 362 Station Equipment
1598 DPW 638 753 714 619,309 573 444 141 19,444 141
1599 638,753,714 619 309,573 19,444 141 444 141
1600
1601 363 Storage 8attery Equipment
1602 DPW 371 688 371 688
1603 371 688 371 688
1604
1605 364 Poles, Towers & Fixtures
1606 DPW 787 587 752 736 361 036 226 716 614,249 55,840 965
1607 787 587 752 736,361 036 226 716 614 249 840 965
1608
1609 365 Overhead Conductors
1610 DPW 581 675,258 549 987 797 687 460 31,687,460
1611 581 675,258 549,987 797 687,460 687,460
1612
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
1613 366 Underground Conduit
614 DPW 250 961 848 244 772 061 189 786 189,786
615 250 961 848 244 772 061 189 786 189 786
1616
1617
1618
1619
1620 367 Underground Conductors
1621 DPW 592 668 229 572 224 822 20,443,407 20,443,407
1622 592,668 229 572 224 822 443,407 20,443,407
1623
1624 368 Line Transformers
1625 DPW 897 227 265 840,298,783 928,482 928,482
1626 897 227 265 840 298 783 928 482 928,482
1627
1628 369 Services
1629 DPW 442 862 777 421 180 979 681 798 681 798
1630 442 862 777 421 180,979 681 798 681 798
1631
1632 370 Meters
1633 DPW 188,162 806 174 381 139 781 667 781 667
1634 188 162 806 174,381 139 13,781 667 781 667
1635
1636 371 Installations on Customers' Premises
1637 DPW 898,145 739 190 158 955 158,955
1638 898 145 739,190 158,955 158 955
1639
1640 372 Leased Property
1641 DPW 49,658 785 873 873
1642 658 785 873 873
1643
1644 373 Street Lights
1645 DPW 56,240,012 55,687,459 552 554 552 554
1646 240 012 687,459 552 554 552 554
1647
648 Unclassified Dist Plant - Ace! 300
649 DPW 374 728 20,592 759 781 969 781 969
1650 374 728 20,592 759 781 969 781 969
1651
1652 DSO Unclassified Dist Sub Plant - Ace! 300
1653 DPW
1654
1655
1656
1657 Total Distribution Plant 552,444,877 327 582 146 224,862 731 614 249 229,476,980
1658
1659 Summary of Distribution Plant by Factor
1660 552 444 877 327 582 146 224 862 731 614 249 229,476 980
1661
1662 Total Distribution Plant by Factor 552,444 877 327 582 146 224 862 731 614 249 229 476 980
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
1663 389 Land and Land Rights
664 SITUS 298 224 100,585 197 639 197 639
,665 GUST 118 885 073 743 142 142
1666 DGU 332 311
1667 228 150
1668 PTD 598,055 268,972 329,083 329 083
1669 016 724 444 761 571 963 571 963
1670
1671 390 Structures and Improvements
1672 SITUS 101 809 664 318,549 9,491 114 491 114
1673 DGP 371 115 347 711 23,404 23,404
1674 DGU 579 602 479 985 99,617 99,617
1675 GUST 836,617 359,058 477 558 477 558
1676 667,456 3,436,169 231 286 231 286
1677 PTD 103,437 803 357 182 080,621 080,621
1678 222 702 257 206,298,656 403,601 16,403 601
1679
1680 391 Office Furniture & Equipment
1681 SITUS 16,605 637 572 126 033 510 033 510
1682 DGP 401,485 376,166 25,319 25,319
1683 DGU 446 050 417 920 130 130
1684 GUST 584 752 359,431 225,322 225,322
1685 151 163 763 243 387 920 387 920
1686 156,684 146 372 10,312 (496)817
1687 PTD 841 988 030 883 811 105 811 105
1688 313,570 293 795 19,775 19,775
1689 617 199 417 417
1690 111 507 945 104 966 135 541 811 (496)541 315
1691
1692 392 Transportation Equipment
1693 SITUS 66,822 762 088,229 734 533 734 533
1694 PTD 280 805 794 015 486,789 106,627 593,416
1695 14,014 786 130,951 883 835 883,835
1696 GUST 078 309 770 770
1697 DGU 202 151 126,338 813 75,813
398 752 964 703,406 558 49,558
,699 DGP 196 994 184 570 12,423 12,423
1700 355 057 332 665 391 22,391
1701 DGU 59,476 55,725 751 751
1702 704 072 85,434 208 269,864 106 627 376,491
1703
1704 393 Stores Equipment
1705 SITUS 990 910 375,408 615 502 615 502
1706 DGP 333 770 312 721 049 049
1707 DGU 864 628 810 100 527 527
1708 PTD 644 349 606,471 878 878
1709 393 137 242,215 150,922 150 922
1710 DGU 106 993 100 246 747 747
1711 13,333 787 447 161 886 626 886,626
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FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
1712
713 394 Tools, Shop & Garage Equipment
714 SITUS 29,768,034 278 323 489 711 1,489,711
1715 DGP 269,684 063,483 206,201 206,201
1716 16,101 265 15,085,847 015,418 69,486 084 904
1717 PTD 4,426 922 166 684 260 238 260 238
1718 933 831 102 102
1719 DGU 701 510 4,405,011 296,498 296,498
1720 178,813 041,407 137,406 137,406
1721 700 061 639 639
1722 535 860 124 647 3,411,212 69,486 480,699
1723
1724 395 Laboratory Equipment
1725 SITUS 065,523 943 603 121 920 121 920
1726 DGP 120,895 113,271 624 624
1727 DGU 857 087 803 035 052 052
1728 PTD 856,276 512,013 344,263 344,263
1729 42,438 39,645 793 793
1730 153,176 828 194 324 982 324 982
1731 180 809 169,407 11,403 11,403
1732 107,944 101 137 807 807
1733 384 150 35,510,305 873 844 873 844
1734
1735 396 Power Operated Equipment
1736 SITUS 209,471 065,383 144,089 144 089
1737 DGP 503 118 408,325 793 793
1738 25,095,951 513,287 582 663 582,663
1739 PTD 157 180 030,370 126 810 126 810
1740 DGU 661 168 2,493,343 167 825 167,825
1741 73,823 68,964 859 859
1742
1743 726,569 680,748 45,821 45,821
1744 118,427 280 110,260,420 166 860 166 860
1745 397 Communication Equipment
746 COM 108 359 363 102 051 907 307,456 307,456
747 COM 295,761 898 722 397 039 397 039
,748 COM 579,164 10,848,930 730,234 730,234
1749 COM 740 866 43,051 976 688 890 688 890
1750 COM 939,236 739 959 199,278 199 278
1751 COM 290,892 52,740,936 549 956 549,956
1752 COM 76,254 71,236 019 019
1753 COM 876 343 821 077 266 55,266
1754 COM 916 975 941 941
1755 234 172 796 220,238 717 934 079 934 079
1756
1757 398 Misc. Equipment
1758 SITUS 068,394 012 587 807 55,807
1759 DGP 708 078 630 630
1760 DGU 236,476 221 563 913 913
1761 CUST 175,429 168 352 078 078
1762 PTD 060 639 880 719 179 921 179 921
1763 869 614 255 255
1764 990,587 928,116 62,471 471
1765 650 2,483 167 167
1766 579 753 256 511 323 242 323,242
1767
1768 399 Coal Mine
1769 247 653,294 231 353 595 16,299 699 631 631 24,931 330
1770
1771 247 653,294 231,353,595 16,299 699 631 631 931 330
1772
1773 399L WIDCO Capital Lease
1774
1775
1776
1777 Remove Capital Leases
1778
1779
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FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
'780 1011390 General Capital Leases
781 SITUS 306,030 306 030
782 12,411 745 629 005 782 740 782 740
1783 PTD 943 593 065,130 878 463 878,463
1784 34,661 369 33,000,165 661 204 661 204
1785
1786 Remove Capital Leases (34 661 369)(33 000,165)661 204)661 204)
1787
1788
1789 1011346 General Gas Line Capital Leases
1790
1791
1792
1793 Remove Capital Leases
1794
1795
1796 Unclassified Gen Plant - Acet 300
1797 SITUS
1798 PTD 190 985 179 758 227 227
1799 CUST
1800
1801 DGP
1802 DGU
1803 190,985 179,758 227 227
1804
1805 399G Unclassified Gen Plant - Acet 300
1806 SITUS
1807 PTD
1808
1809 DGP
1810 DGU
1811
1812
1813 Total General Plant 158,208,903 083 514 874 74,694,029 807 249 83,501 277
814
115 Summary of General Plant by Factor
816 460,304 013 429,112,732 191 282 191 282
1817 DGP
1818 DGU
1819 183,921 539 172 322 621 598 918 69,486 668 404
1820 276 179,463 259 944 174 16,235,289 106 627 341 916
1821 248 791 259 232,416,662 16,374 596 631 135 25,005 732
1822 673 998 718 851 955 147 955,147
1823 DEU
1824 SSGCT
1825 SSGCH
1826 Less Capital Leases (34 661 369)(33,000,165)661 204)661 204)
1827 Total General Plant by Factor 158 208 903 083,514 874 694 029 807 249 501 277
1828 301 Organization
1829 SITUS 393,835 593,572 800 263 800 263
1830 PTD
1831
1832 393 835 593 572 800 263 800 263
1833 302 Franchise & Consent
1834 SITUS 000 000 000,000 000 000
1835 945,256 759,515 185 741 022 672 208,413
1836 069 672 966 086 103 586 103,586
1837 703,142 091 218 611 924 611 924
1838 DGP 844 878 665,467 179,411 179 411
1839 DGU 679,586 636,728 858 858
1840 242 534 119 015 123,519 022,672 146 191
1841
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FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
1842 303 Miscellaneous Intangible Plant
343 SITUS 643 236 251 858 391,378 391 378
844 887 617 236 964 650,653 609 723,262
1845 PTD 381 255 297 358 843 095 22,412 203 390,444 22,802 646
1846 583,553 413,512 170 041 170 041
1847 GUST 105,167 238 100 924 177 243 061 243,061
1848
1849 DGP
1850 548,536,942 517 669 607 867 336 463 053 330 389
1851 303 Less Non-Utility Plant
1852 SITUS
1853 548,536 942 517 669 607 867 336 463 053 330 389
1854 Unclassified Intangible Plant - Acet 300
1855 SITUS
1856
1857 DGU
1858 PTD
1859
1860
1861 Total Intangible Plant 639,173,311 601,382,194 37,791 117 485,725 39,276 843
1862
1863 Summary of Intangible Plant by Factor
1864 11,037 071 845,430 191 641 191 641
1865 DGP
1866 DGU
1867 139 130,152 130,355,979 774 172 095 282 869,454
1868 381 255,297 358,843 095 22,412 203 390 444 802 646
1869 105 167 238 100,924 177 243 061 243.061
1870 SSGCT
1871 SSGCH
1872 583 553 2,413 512 170,041 170,041
1873 Total Intangible Plant by Factor 639,173 311 601 382 194 791 117 485,725 39,276,843
1874 Summary of Unclassified Plant (Account 106)
1875 374,728 20,592 759 781 969 781 969
876 DSO
177 190 985 179 758 227 227
878
1879
1880
1881 918 405 608,228 310 177 310 177
1882 TSO
1883
1884
1885 530,469 307 822 222 647 222 647
1886 Total Unclassified Plant by Factor 014 588 688 568 326 020 326 020
1887
1888 Total Electric Plant In Service 745,911 135 13,879,068,499 866,842 636 60,023,674 926,866,310
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FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
1889 Summary of Electric Plant by Factor
890 023 785,962 765 540,308 258,245 653 614 249 262 859 902
1891 251 374 811 234,830,174 544,637 631 135 175,772
1892 DGU
1893 DGP
1894 719,135,734 169 267 885 549,867 849 46,281 219 596,149,068
1895 657,434 760 618,787 269 38,647,492 497 071 39,144 563
1896 128 841 237 123,643,028 198 209 198,209
1897 DEU
1898 SSGCH
1899 SSGCT
1900 Less Capital Leases (34,661 369)(33,000 165)661 204)(1,661 204)
1901 745 911 135 13,879,068,499 866 842,636 023 674 926 866 310
1902 105 Plant Held For Future Use
1903 DPW 245,855 245 855
1904 SNPPS
1905 SNPT 038 046 972 582 464 (65,464)
1906 SNPP
1907
1908 SNPG
1909
1910
1911 Total Plant Held For Future Use B10 283,901 218,437 65,464 (65,464)
1912
1913 114 Electric Plant Acquisition Adjustments
1914
1915 142 633 069 133,637 987 995 082 995 082
1916 560,711 642 447 918,264 918,264
1917 Total Electric Plant Acquisition Adjustment B15 157 193,780 147,280,434 913,346 913,346
1918
1919 115 Accum Provision for Asset Acquisition Adjustments
1920
1921 (67 239 448)(62 999,027)240,422)240,422)
1922 909 689)(9,284,740)(624 950)(624 950)
1923 B15 (77 149 138)(72 283,767)865,371)865,371)
:)24
.925 120 Nuclear Fuel
1926
1927 Total Nuclear Fuel B15
1928
1929 124 Weatherization
1930 DMSC 452,290 408 094 196 196
1931 DMSC 276 259
1932 816 452 565 6,408,353 212 212
1933
1934 182W Weatherization
1935 DMSC 675,315 953 328 721 987 721 987
1936 DMSC
1937 DMSC SGCT
1938 DMSC 059,564 997 277 287 287
1939 816 734,879 950 605 784 274 784 274
1940
1941 186W Weatherization
1942 DMSC
1943 DMSC
1944 DMSC GNP
1945 DMSC
1946 DMSC
1947 816
1948
1949 Total Weatherization B16 18,187,445 12,358,959 828,486 828,486
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FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
1950
951 151 Fuel Stock
1952 DEU
1953 790 938 394 986 395,953 301 369 697 322
1954
1955 640 026 2,466 269 173,758 173 758
1956 Total Fuel Stock B13 69,430,965 64,861,254 569,710 301,369 871 079
1957
1958 152 Fuel Stock - Undistributed
1959
1960
1961
1962 25316 DG&T Working Capital Deposit
1963 (339,000)(316 688)(22,312)(22 312)
1964 613 (339 000)(316,688)(22,312)(22 312)
1965
1966 25317 DG&T Working Capital Deposit
1967 206 328)126 932)(79,396)(79,396)
1968 613 206,328)126 932)(79,396)(79,396)
1969
1970 25319 Provo Working Capital Deposit
1971
1972
1973
1974 Total Fuel Stock 613 885 637 63,417 634 468,002 301 369 769 371
1975 154 Materials and Supplies
1976 MSS 63,329,283 59,724 785 604,498 604 498
1977 MSS 177 491 040,169 137 322 137 322
1978 MSS 636,544 397 199 239,345 239 345
1979 MSS 235 754 482 482
1980 MSS SNPPS 59,073 262 347 837 725,425 725 425
1981 MSS SNPPH (21 081)(19,751)329)329)
1982 MSS SNPD (5,512 045)263 103)(248,942)(248 942)
1983 MSS SNPT
1984 MSS
385 MSS
986 MSS SNPPS
1987 MSS SNPP
1988 MSS SNPPS 086,129 017 633 68,496 496
1989 Total Materials and Supplies B13 123,845,819 116,316,522 529,297 529,297
1990
1991 163 Stores Expense Undistributed
1992 MSS
1993
1994 613
1995
1996 25318 Provo Working Capital Deposit
1997 MSS SNPPS (273 000)(255 783)(17 217)(17 217)
1998
1999 613 (273 000)(255,783)(17,217)(17 217)
2000
2001 Total Materials & Supplies 613 123,572 819 116 060 739 512 081 512 081
2002
2003 165 Prepayments
2004 DMSC 586 356 2,429,054 157 302 157 302
2005 GPS 038 995 566,420 472,575 472 575
2006 103,341 970 695 132 646 132,646
2007 942 463 748 800 193,663 193 663
2008 PTD 934,112 114 991 819 121 819 121
2009 Total Prepayments B15 29,605,268 27,829,961 775,307 775,307
2010
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FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
?011 182M Mise Regulatory Assets
012 DDS2 185,217 522 733 (337 517)(27,938)(365,455)
~013 DEFSG 604 276 604 276
2014 SGCT 440 211 652,580 787 631 787 631
2015 DEFSG
2016 DEFSG
2017 928,327 867 228 099 169,259 230,358
2018 DDS02 162 816 859,318 303,498 303,498
2019 B11 69,716 570 68,901 859 814 711 745,597 560 308
2020
2021 186M Mise Deferred Debits
2022 LABOR 334,457 334,457
2023
2024
2025 DEFSG 816 416 936,059 880 357 880 357
2026 LABOR 287 023 270 150 873 16,873
2027 911 072 390,392 520,680 520 680
2028 SNPPS
2029 EXCTAX
2030 Total Misc. Deferred Debits B11 42,348,968 931,058 417,910 417,910
2031
2032 Working Capital
2033 CWC Cash Working Capital
2034 CWC 46,773 223 874 111 899,112 531 490 430 602
2035 CWC
2036 CWC
2037 B14 773 223 874 111 899,112 531,490 3,430 602
2038
2039 OWC OtherWorIt Cap.
2040 131 Cash SNP 397 250 974,743 422 507 (422 507)(0)
2041 135 Working Funds 197 629 185,166 463 463
2042 141 Notes Receivabl GP 997 447 938,812 635 635
2043 143 Other AIR 002 724 709,287 293,436 293 436
2044 232 AlP PTD
"045 232 AlP PTD 705 940)605,656)(100,284)(100 284)
)46 232 AlP 198 869)119 964)(78,906)(78,906)
047 253 Deferred Hedge P
2048 2533 Other Msc, Df, CId, P
2049 2533 OtherMsc, Df, CIII, P (5,408,401)(5,052,438)(355,963)(355,963)
2050 230 Asset Relir, Obl;g,860,504)738 052)(122,452)(122,452)
2051 230 Asset Retir, Obl;g,
2052 254105 ARO Reg Liabiity
2053 254105 ARO Reg Liabiity (406 339)(379,595)(26,744)(26,744)
2054 2533 CI"oIa Reclam...,n P
2055 B14 014 997 912 303 102,694 (422,507)680,187
2056
2057 Total Working Capital B14 66,788,220 63,786,414 001 806 108,983 110,789
2058 Miscellaneous Rate Base
2059 18221 Unree Plant & Reg Study Costs
2060
2061
2062 B15
2063
2064 18222 Nuclear Plant - Trojan
2065 575 378)575 378)
2066 TROJP 767 609 528,432 239 177 239,177
2067 TROJD 484 223 135 665 348,557 348 557
2068 B15 676,454 088,719 587 735 587 735
2069
2070
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FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
~071
072 1869 Misc Deferred Debits-Trojan
L073
2074 SNPPN
2075 815
2076
2077 Total Miscellaneous Rate Base B15 676,454 088,719 587,735 587 735
2078
2079 Total Rate Base Additions B15 509,109,924 477,590,448 31,519,476 090,485 34,609 961
2080 235 Customer Service Deposits
2081 CUST
2082 CUST
2083 Total Customer Service Deposits B15
2084
2085 2281 Prop Ins PTD 004 415)(945,370)(59 045)(59 045)
2086 2282 Inj & Dam PTD 248 079)057 140)(190,939)(190,939)
2087 2283 Pen & 8en PTD (63,443 389)(59,713,851)(3,729,538)(3,729 538)
2088 2283 Pen & 8en PTD
2089 254 Ins Prov PTD 892 363)722 334)(170,028)(170,028)
2090 815 (70 588 245)(66,438,695)149,550)149,550)
2091
2092 22844 Accum Hydro Relicensing Obligation
2093
2094
2095 815
2096
2097 22842 Prv-Trojan TROJD 676 847)506,716)(170 131)(170 131)
2098 230 ARO TROJP 347,494)198,469)(149 025)(149,025)
2099 254105 ARO TROJP (890 548)(834,014)(56,534)(56,534)
2100 254
2101 815 (5,914 889)(5,539 199)(375 690)(375 690)
2102
2103 252 Customer Advances for Construction
2104 DPW 266 338 (324 976)591 314 (591 619)(305)
?105 DPW
106 (258 980)(258 980)
::107 DPW
2108 CUST 713 184)361 643)(351 541)351 541
2109 Total Customer Advances for Construction B19 446,845)686,619)239,773 (499,058)(259,285)
2110
2111 25398 S02 Emissions
2112 350 891)350 891)
2113 819 (2,350 891)350 891)
2114
2115 25399 Other Deferred Credits
2116 (5,493 257)(5,414 274)(78 984)(78 984)
2117 (532 374)(501 078)(31 296)070 174)101,469)
2118 707 768)158,617)(549,151)(549,151)
2119 714 113)601 296)(112 817)(112 817)
2120 819 (16 447 512)(15 675,265)(772 247)070 174)842,421)
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FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
?121
122 190 Accumulated Deferred Income Taxes
L123 840 389 735,750 104 639 612 121 251
2124 156 138 340 816 816
2125 LABOR 140 932 91,430,475 710,458 710,458
2126 DGP 939 939
2127 GUST BADDEBT 943 562 616,587 326,974 326,974
2128 TROJD 27,485 738 747 747
2129 890,878 582,437 308 441 (62 619)245 822
2130 649 652 146,178 503,474 892 163 395 637
2131 PTD SNP 49,438 614 824 824
2132 DPW SNPD 683,432 155 771 527 661 527 661
2133
2134 Total Accum Deferred Income Taxes B19 150,374,863 142,882,829 492 034 846,156 338,191
2135
2136 281 Accumulated Deferred Income Taxes
2137
2138 DGP (467 329)(467 329)
2139 SNPT
2140 B19 (467 329)(467 329)
2141
2142 282 Accumulated Deferred Income Taxes
2143 (983 530)(983 530)
2144 ACCMDIT DITBAL 244 206 738)162 595,266)(81 611,472)(735 529)(82 347 002)
2145 DGP
2146 LABOR 636 666 540,454 212 212
2147 PTD SNP (464,975)(438,417)(26 558)(26,558)
2148 976 157)648,643)(327 514)(327 514)
2149 15,387 275 14,416 884 970,391 970,391
2150 B19 233,607,459)152 708,518)(80 898 941)(735 529)(81 634,471)
2151
2152 283 Accumulated Deferred Income Taxes
2153 (32 382 955)(32 251 156)(131 798)(131 798)
2154 (9,932,688)306 288)(626 400)596 (593,804)
?155 (14 933,734)(13,950,846)(982 888)112 302 (870 585)
156 LABOR (19,425 930)(18 283 971)141 959)141 959)
.:157 GPS (16,528 878)(15,557 223)(971 655)(971 655)
2158 PTD SNP (12 017 507)(11 331 106)(686,401)(686,401)
2159 TROJD 512,210)(1,416 100)(96,111)(96 111)
2160 PTD SNPD
2161 SGCT
2162 828 685)587 231)(241 454)(241,454)
2163 B19 (110,562,586)(105 683 921)878,665)144 898 733 767)
2164
2165 Total Accum Deferred Income Tax B19 (1,194,262,511)115,976,938)(78,285,573)255,525 (78,030,048)
2166 255 Accumulated Investment Tax Credit
2167 PTD (2,067 067)067 067)
2168 PTD ITC84 (3,781 541)781 541)
2169 PTD ITC85 (5,419 804)(5,419,804)
2170 PTD ITC86 342 943)342,943)
2171 PTD ITC88 (325 944)(325 944)
2172 PTD ITC89 (692 950)(692 950)
2173 PTD ITC90 (416 622)(358,372)(58 250)(58 250)
2174 PTD DGU
2175 Total Accumlated ITC B19 (12 979,804)(12 921,554)(58 250)067 067)125 317)
2176
2177 Total Rate Base Deductions (1,308,639,807)225,238 270)(83,401,537)(5,731,665)(89 133,203)
2178
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FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
'179
:180
2181 108SP Steam Prod Plant Accumulated Depr
2182
2183 (814 307 951)(762,954 035)(51 353,916)(51 353,916)
2184 (908,917 121)(851 596,726)(57 320 395)(57,320,395)
2185 (396,213,930)(371 226,901)(24 987 029)(182 811)(25,169 841)
2186 (208,389,028)(195 247 080)(13 141 948)(13 141 948)
2187 817 327 828.030)181,024 742)(146,803,288)(182 811)(146 986,099)
2188
2189 108NP Nuclear Prod Plant Accumulated Depr
2190
2191
2192
2193 817
2194
2195
2196 108HP Hydraulic Prod Plant Accum Depr
2197
2198 (151,478,467)(141 925,555)(9,552 912)(9,552 912)
2199 (28 310 690)(26 525 291)785,399)785 399)
2200 (38,673 513)(36,234,587)(2,438 925)195,266 (2,243,659)
2201 (12 392 382)(11 610 863)(781 519)(781 519)
2202 817 (230,855,052)(216 296,296)(14 558 756)195,266 (14 363,490)
2203
2204 1080P Other Production Plant - Accum Depr
2205
2206 079,955)948 784)(131 171)(131 171)
2207
2208 (56,480,589)(52 918 669)561 920)(508 328)070,248)
2209 (11 757 005)(11 015 555)(741,450)(741,450)
2210 817 (70,317 548)(65,883,008)(4,434,540)(508 328)942 869)
2211
2212 108EP Experimental Plant - Accum Depr
213
214
2215
2216
2217 Total Production Plant Accum Depreciation B17 (2,629,000,630)(2,463,204 046)(165,796,584)(495,874)(166,292,458)
2218
2219 Summary of Prod Plant Depreciation by Factor
2220
2221 DGP
2222 DGU
2223 (2,629,000 630)(2,463 204 046)(165 796,584)(495 874)(166,292 458)
2224 SSGCH
2225 SSGCT
2226 Total of Prod Plant Depreciation by Factor 629,000,630)(2,463 204 046)(165,796 584)(495 874)(166 292.458)
2227
2228
2229 108TP Transmission Plant Accumulated Depr
2230 (356 751 195)(334 252 863)(22,498,332)(22,498,332)
2231 (357,468,535)(334 924 965)(22 543 571)(22 543 571)
2232 (284 718 132)(266,762,528)(17 955 604)(51 779)(18 007 383)
2233 Total Trans Plant Accum Depreciation B17 (998,937,863)(935,940,356)(62 997,507)(51,779)(63 049,286)
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
'.J234 108360 Land and Land Rights
235 DPW (5,002,571)802 259)(200,311)(200 311)
L236 B17 002 571)802 259)(200 311)(200,311)
2237
2238 108361 Structures and Improvements
2239 DPW (14 553 770)(14 032 854)(520 916)(520 916)
2240 B17 (14 553,770)(14 032 854)(520,916)(520,916)
2241
2242 108362 Station Equipment
2243 DPW (160 920,994)(153,596 282)324 712)324 712)
2244 B17 (160 920,994)(153,596 282)324 712)324 712)
2245
2246 108363 Storage Battery Equipment
2247 DPW (33,717)(33 717)
2248 B17 (33 717)(33,717)
2249
2250 108364 Poles, Towers & Fixtures
2251 DPW (402,808 979)(380,590,240)(22 218 739)(62 283)(22 281 022)
2252 B17 (402 808 979)(380 590,240)(22,218,739)(62 283)(22 281 022)
2253
2254 108365 Overhead Conductors
2255 DPW (229,955 968)(218,907 786)(11 048 182)(11 048,182)
2256 B17 (229 955,968)(218 907 786)(11 048,182)(11 048 182)
2257
2258 108366 Underground Conduit
2259 DPW (103,782,652)(100 681 324)(3,101 329)101 329)
2260 B17 (103 782 652)(100 681,324)(3,101 329)101 329)
2261
2262 108367 Underground Conductors
2263 DPW (215,289 506)(205,120,332)(10,169,174)(10 169,174)
2264 B17 (215 289 506)(205 120 332)(10,169,174)(10,169 174)
2265
2266 108368 Line Transformers
2267 DPW (335 780 073)(309 547,408)(26,232 665)(26,232 665)
?268 B17 (335 780 073)(309,547 408)(26,232 665)(26 232,665)
269
L270 108369 Services
2271 DPW (135,503,433)(125,431 141)(10 072 291)(10 072,291)
2272 B17 (135 503 433)(125 431 141)(10 072,291)(10,072 291)
2273
2274 108370 Meters
2275 DPW (87 177,195)(81 687 590)(5,489 605)489,605)
2276 B17 (87 177 195)(81 687,590)(5,489,605)(5,489 605)
2277
2278
2279
2280 108371 Installations on Customers' Premises
2281 DPW 848 265)712 338)(135,927)(135,927)
2282 B17 (5,848,265)(5,712 338)(135 927)(135,927)
2283
2284 108372 Leased Property
2285 DPW (42,329)(37 535)794)794)
2286 B17 (42 329)(37 535)794)794)
2287
2288 108373 Street Lights
2289 DPW (19 690 579)(19 431 814)(258 765)(256,765)
2290 B17 (19 690 579)(19,431 814)(258 765)(258,765)
2291
2292 108DOO Unclassified Dist Plant - Acct 300
2293 DPW
2294 B17
2295
2296 108DS Unclassified Dist Sub Plant - Acet 300
2297 DPW
2298 B17
2299
2300 108DP Unclassified Dist Sub Plant - Acet 300
2301 DPW
'.J302 B17
303
L304
2305 Total Distribution Plant Accum Depreciation B17 716,390,030)619,612,621)(96,777 410)(62,283)(96,839,693)
2306
2307 Sumrn"ry of Distribution Plant Depr by Factor
2308 716 390,030)619 612,621)(96,777,410)(62 283)(96 839,693)
2309
2310 Total Distribution Depreciation by Factor B17 716 390 030)619 612 621)(96,777,410)(62 283)(96 839 693)
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
~311 108GP General Plant Accumulated Depr
312 SITUS (145 055,671)(133,660,396)(11 395 274)(11 395 274)
L313 DGP 742 509)(8,191 167)(551 342)(551 342)
2314 DGU (17 221 109)(16,135 068)086,040)086,040)
2315 (38,377 157)(35 956 921)(2,420,236)249)(2,421,485)
2316 GUST (5,584 890)359 563)(225 327)(225 327)
2317 PTD (93 286 976)(87 803 074)483 902)791)(5,487 693)
2318 (517 715)(483 640)(34 074)(34,074)
2319 (43,455)(40 714)(2,740)740)
2320 881 702)699,969)(181 733)(181 733)
2321 817 (311 711 182)(290,330 513)(21 380,669)040)(21 385 710)
2322
2323
2324 108MP Mining Plant Accumulated Depr.
2325
2326 (145,270 106)(135 708,921)(9,561 185)985 509 200)
2327 817 (145,270 106)(135,708,921)561 185)985 (9,509,200)
2328 108MP Less Centralia Situs Depreciation
2329
2330 817 (145,270,106)(135 708,921)(9,561 185)985 (9,509,200)
2331
2332 1081390 Accum Depr - Capital Lease
2333 PTD 817
2334
2335
2336 Remove Capital Leases
2337 817
2338
2339 1081399 Accum Depr - Capital Lease
2340
2341 817
2342
2343
2344 Remove Capital Leases
"345 817
346
L347
2348 Total General Plant Accum Depreciation B17 (456,981,288)(426 039,434)(30,941 854)46,945 (30,894,910)
2349
2350
2351
2352 Summary of General Depreciation by Factor
2353 (145 055 671)(133,660,396)(11 395 274)(11 395,274)
2354 DGP
2355 DGU
2356 (145,787 821)(136 192.561)(9,595,260)985 (9,543 275)
2357 (93,286,976)(87 803,074)483,902)791)487,693)
2358 584 890)(5,359,563)(225 327)(225,327)
2359 (67 265 931)(63,023,840)242 092)249)243 341)
2360 DEU
2361 SSGCT
2362 SSGCH
2363 Remove Capital Leases
2364 Total General Depreciation by Factor (456,981 288)(426 039 434)(30,941 854)945 (30 894 910)
2365
2366
2367 Total Accum Depreciation - Plant In Service B17 (5,801 309,811)(5,444,796,456)(356,513,355)(562,991)(357,076,347)
2368 111SP Accum Prov for Amort-Steam
2369
2370 (209 674)(196,451)(13,223)(13 223)
2371 818 (209 674)(196,451)(13 223)(13,223)
2372
2373
2374 111GP Accum Prav for Amort-General
2375 SITUS (15 908,720)(15 908 720)
2376 GUST 755 807)684 967)(70,840)(70 840)
2377 (288 652)(270 448)(18 204)(18,204)
2378 PTD (5,860 848)516 316)(344,532)(344 532)
'2379
380 818 (23,814 027)(23 380 452)(433,575)(433,575)
L381
ROLLED-Page 9.
Beginning/Ending
FERC BUS PITA UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
"382
383 111HP Accum Prov for Amort-Hydro
L384 (344 258)(322 548)(21 710)(21 710)
2385
2386 (937)(878)(59)(59)
2387 (255 706)(239,580)(16 126)(16,126)
2388 618 (600 901)(563.006)(37 896)(37 896)
2389
2390
2391 1111P Accum Prov for Amort-Intangible Plant
2392 SITUS (9,179 394)(7,714 504)464 890)(1,464 890)
2393 DGP 802,651)(2,625,904)(176 748)(176 748)
2394 DGU (311 935)(292 263)(19,672)(19,672)
2395 (674 811)(630 397)(44,414)(44 414)
2396 (30 055 084)(28,159,676)895,409)(24 182)919 590)
2397 881 800)258 610)(623,191)(623,191)
2398 445 587)(2,291 357)(154 230)(154 230)
2399 GUST (72 612,464)(69,682 853)929,611)(2,929,611)
2400
2401 (11 314)(10,600)(713)(713)
2402 PTD (219,509 204)(206,605 292)(12 903,912)(14 148)(12 918 060)
2403 618 (347 484,244)(327 271,455)(20 212 789)(38,330)(20 251 119)
2404 1111P Less Non-Utility Plant
2405 NUTIL OTH
2406 (347 484,244)(327 271,455)(20 212,789)(38 330)(20 251,119)
2407
2408 111390 Accum Amtr - Capital Lease
2409 SITUS
2410
2411 PTD
2412
2413
2414 Remove Capital Lease Amtr
2415
"416 Total Accum Provision for Amortization B18 (372,108,846)(351,411,364)(20,697 482)(38,330)(20,735 812)
~17
L418
2419
2420
2421 Summary of Amortization by Factor
2422 (25,088 114)(23,623,224)(1,464 890)464 890)
2423 DGP
2424 DGU
2425 (674 811)(630 397)(44,414)(44 414)
2426 (225,370 052)(212,121 608)(13 248,443)(14 148)(13,262,592)
2427 (74 368 270)(71 367 820)(3,000 451)000,451)
2428 SSGCT
2429 SSGCH
2430 (46 607 599)(43,668 315)939,284)(24,182)963 466)
2431 Less Capital Lease
2432 Total Provision For Amortization by Factor (372 108,846)(351 411 364)(20,697 482)(38 330)(20 735 812)
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,
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9
8
%
48
4
0
%
00
0
0
%
12
.
29
5
6
%
39
.
68
3
2
%
74
3
0
%
69
4
0
%
37
6
1
%
Se
a
s
o
n
a
l

S
y
s
t
e
m

E
n
e
r
g
y

C
h
o
l
l
a
10
,
21

S
S
E
C
H
73
8
9
%
27
,
91
2
5
%
33
9
0
%
00
0
0
%
14
.
01
2
4
%
39
.
60
8
8
%
10
5
1
%
93
6
2
%
34
7
3
%
Se
a
s
o
n
a
l

S
y
s
t
e
m

G
e
n
e
r
a
t
i
o
n

C
h
o
l
i
a
10
,
16

S
S
G
C
H
84
7
9
%
29
,
35
8
0
%
44
7
8
%
00
0
0
%
12
,
72
4
6
%
39
,
68
4
8
%
83
3
5
%
75
4
6
%
36
8
9
%
Se
a
s
o
n
a
l

S
y
s
t
e
m

C
a
p
a
c
i
t
y

P
u
r
c
h
a
s
e
s
10
,
18

S
S
C
P
65
1
8
%
26
,
45
6
0
%
02
2
0
%
00
0
0
%
11
,
53
9
4
%
43
,
19
0
0
%
17
3
2
%
49
0
4
%
47
7
1
%
Se
a
s
o
n
a
l

S
y
s
t
e
m

E
n
e
r
g
y

P
u
r
c
h
a
s
e
s
10
,
22

S
S
E
P
69
2
2
%
25
,
48
2
3
%
71
8
7
%
00
0
0
%
13
.
02
4
8
%
42
,
00
0
6
%
87
6
2
%
79
5
3
%
40
9
8
%
Se
a
s
o
n
a
l

S
y
s
t
e
m

G
e
n
e
r
a
t
i
o
n

C
o
n
t
r
a
c
t
s
10
,
18

S
S
G
C
68
1
9
%
26
.
21
2
6
%
94
6
2
%
00
0
0
%
11
.
91
0
8
%
42
.
89
2
7
%
34
9
0
%
56
8
6
%
46
0
3
%
Se
a
s
o
n
a
l

S
y
s
t
e
m

G
e
n
e
r
a
t
i
o
n

C
o
m
b
u
s
U
o
n

T
u
r
b
i
n
e
10
,
17

S
S
G
C
T
70
4
6
%
26
,
38
0
9
%
90
5
4
%
00
0
0
%
11
,
74
2
5
%
42
,
62
9
2
%
67
9
1
%
50
3
8
%
45
4
8
%
MId
-
C
o
l
u
m
b
i
a
10
,
19

M
C
52
9
0
%
71
,
49
7
9
%
10
,
32
3
8
%
00
0
0
%
61
9
0
%
11
,
60
6
3
%
81
5
9
%
49
5
0
%
11
3
2
%
Di
v
i
s
i
o
n

N
e
t

P
l
a
n
t

D
l
s
t
r
i
b
u
U
o
n
10
,
SN
P
D
83
6
2
%
30
,
62
4
7
%
06
0
1
%
00
0
0
%
54
3
9
%
44
,
85
4
9
%
51
6
3
%
54
3
9
%
00
0
0
%
Div
i
s
i
o
n
a
l

G
e
n
e
r
a
t
i
o
n

-

H
u
n
t
i
n
g
t
o
n
10
,
15

D
G
U
H
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
62
,
72
2
3
%
12
,
94
2
9
%
52
8
2
%
80
6
5
%
Div
i
s
i
o
n
a
l

E
n
e
r
g
y

-

H
u
n
t
i
n
g
t
o
n
10
,
15

D
E
U
H
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
81
.
88
9
3
%
13
,
44
0
8
%
92
6
7
%
74
3
2
%
81
a
n
k
Do

N
o
t

U
s
e
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
Sy
s
t
e
m

N
e
t

P
l
a
n
t

M
i
n
i
n
g
10
,
SN
P
M
75
7
6
%
27
,
26
5
8
%
14
0
3
%
00
0
0
%
13
,
84
6
6
%
40
.
09
9
3
%
58
1
7
%
92
2
8
%
36
3
9
%
Bla
n
k
Do

N
o
t
U
s
e
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
Bl
a
n
k
Do

N
o
t

U
s
e
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
Bl
a
n
k
Do

N
o
t

U
s
e

00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
Bi
a
n
k
Do

N
o
t

U
s
e

00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
Bl
a
n
k
Do

N
o
t
U
s
e
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
Bl
a
n
k
Do

N
o
t
U
s
e
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
Sy
s
t
e
m

N
e
t

H
y
d
r
o

P
l
a
n
t
-
Pa
c
.

P
o
w
e
r
10
,
SN
P
P
H
-
83
7
1
%
26
,
59
8
4
%
27
1
4
%
00
0
0
%
12
,
56
8
0
%
40
.
30
6
5
%
30
6
4
%
71
9
1
%
39
3
0
%
Sy
s
t
e
m

N
e
t

H
y
d
r
o

P
l
a
n
t
-
RM
,
10
,
SN
P
P
H
-
83
7
1
%
26
,
59
8
4
%
27
1
4
%
00
0
0
%
12
.
56
8
0
%
40
,
30
6
5
%
30
6
4
%
71
9
1
%
39
3
0
%
Cu
s
t
o
m
e
r

-

S
y
s
t
e
m
10
,
67
5
2
%
32
,
66
7
5
%
43
9
5
%
00
0
0
%
84
1
3
%
45
.
45
3
0
%
03
4
6
%
88
8
9
%
00
0
0
%
00
%
00
%
Cu
s
t
o
m
e
r

-

P
a
c
,

P
o
w
e
r
10
,
CN
P
00
0
0
%
69
,
58
1
9
%
15
.
84
6
2
%
00
0
0
%
14
,
57
1
9
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
%
00
%
Cu
s
t
o
m
e
r

-

R
M
,
10
,
CN
U
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
90
.
22
6
6
%
00
8
9
%
76
4
5
%
00
0
0
%
00
%
00
%
Wa
s
h
i
n
g
t
o
n

B
u
s
i
n
e
s
s

T
a
x
WB
T
A
X
00
0
0
%
00
0
0
%
10
0
,
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
%
00
%
Bla
n
k
Do

N
o
t

U
s
e

00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
Bla
n
k
Do

N
o
t

U
s
e

00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
ex
c
i
s
e

T
a
x

-

s
u
p
e
r
f
u
n
d
10
.
10

E
X
C
T
A
X
1.2
5
7
9
%
42
,
19
6
4
%
75
7
1
%
00
0
0
%
13
.
19
1
1
%
25
,
29
3
0
%
20
3
0
%
02
3
5
%
18
4
9
%
75
8
8
%
00
0
1
%
In
t
e
r
e
s
t
10
,
IN
T
54
6
1
%
29
,
36
0
6
%
89
5
0
%
00
0
0
%
10
,
76
2
1
%
41
.
75
1
7
%
71
3
0
%
69
0
0
%
24
1
5
%
00
0
0
%
CI
A
C
10
.
CI
A
C
83
6
2
%
30
.
62
4
7
%
06
0
1
%
00
0
0
%
54
3
9
%
44
,
85
4
9
%
51
8
3
%
54
3
9
%
00
0
0
%
Id
a
h
o

S
t
a
t
e

I
n
c
o
m
e

T
a
x
10
,
ID
S
I
T
00
%
00
%
00
%
00
%
00
%
00
%
10
0
.
00
%
00
%
00
%
00
0
0
%
Bla
n
k
DO
N
O
T
U
S
E
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
Ba
d

D
e
b
t

E
x
p
e
n
s
e
10
,
BA
D
D
E
8
T
15
6
3
%
35
.
14
1
4
%
11
,
48
4
6
%
00
0
0
%
72
5
5
%
36
,
79
7
6
%
26
8
3
%
40
6
1
%
00
0
0
%
00
0
0
%
00
0
0
%
Bla
n
k
DO
N
O
T
U
S
E
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
81
a
n
k
DO
N
O
T
U
S
E
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
00
0
0
%
Ac
c
u
m
u
l
a
t
e
d

I
n
v
e
s
t
m
e
n
t

T
a
x

C
r
e
d
i
t

1
9
8
4
IT
C
8
4
29
%
70
,
96
%
14
,
18
%
00
%
10
,
95
%
61
%
Ac
c
u
m
u
l
a
t
e
d

I
n
v
e
s
t
m
e
n
t

T
a
x

C
r
e
d
i
t

1
9
6
5
IT
C
6
5
42
%
87
.
69
%
13
.
36
%
00
%
11
,
61
%
92
%
Ac
c
u
m
u
l
a
t
e
d

I
n
v
e
s
t
m
e
n
t

T
a
x

C
r
e
d
i
t

1
9
8
6
IT
C
6
6
79
%
64
.
61
%
13
.
13
%
00
%
15
,
50
%
96
%
Ac
c
u
m
u
l
a
t
e
d

I
n
v
e
s
t
m
e
n
t

T
a
x

C
r
e
d
i
t

1
9
8
8
IT
C
8
8
27
%
61
.
2
0
%
14
.
96
%
00
%
18
.
71
%
86
%
Ac
c
u
m
u
l
a
t
e
d

I
n
v
e
s
t
m
e
n
t

T
a
x

C
r
e
d
i
t

1
9
6
9
IT
C
8
9
88
%
56
,
36
%
15
,
27
%
00
%
20
,
68
%
82
%
Ac
c
u
m
u
l
a
t
e
d

I
n
v
e
s
t
m
e
n
t

T
a
x

C
r
e
d
i
t

1
9
9
0
IT
C
9
0
50
%
15
.
94
%
91
%
00
%
81
%
46
,
94
%
13
.
98
%
13
.
54
%
39
%
Ot
h
e
r

E
l
e
c
t
r
i
c
OT
H
E
R
00
%
00
%
00
%
00
%
00
%
00
%
00
%
00
%
00
%
10
0
,
00
%
00
%
No
n
-
U
U
l
i
t
y
NU
T
I
L
00
%
00
%
00
%
00
%
00
%
00
%
00
%
00
%
00
%
00
%
10
0
,
00
%
Sy
s
t
e
m

N
e
t

S
t
e
a
m

P
l
a
n
t
10
,
SN
P
P
S
83
7
9
%
28
,
65
3
7
%
28
4
3
%
00
0
0
%
12
,
57
9
5
%
40
,
25
9
7
%
27
2
0
%
72
1
7
%
39
1
2
%
Sy
s
t
e
m

N
e
t

T
r
a
n
s
m
i
s
s
i
o
n

P
l
a
n
t
10
,
SN
P
T
83
7
1
%
28
,
59
8
4
%
27
1
4
%
00
0
0
%
12
,
56
8
0
%
40
,
30
6
5
%
30
6
4
%
71
9
1
%
39
3
0
%
Pa
g
e

1
0
,
BE
G
I
N
N
I
N
G
/
E
N
D
I
N
G

A
V
E
R
A
G
E

F
A
C
T
O
R
S
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Rocky Moulntaln Power
Idaho General Rate Case
December 2006
COINCIDENTAL PEAKS
Month Day TIme --cA
Jan-o6 1800
Feb-O6 900
Mar-o6 800
Apr-o6 800
May-O6 1600
Jun-06 1600
Jul-O6 1500
Aug-o6 1700
Sep-Q6 1700
Oct-O6 800
Nov-o6 1800
Dec-D6 1800
Month
Jan-
Feb-O6
Mar-QB
Apr-
May-
Jun-
Ju~06
Aug-O6
Sep-06
Oct-O8
Nov-O6
Dec-o6
Month
Jan-o6
Feb-O6
Mar-o6
Apr-o6
May-06
Jun-QB
Jul-O6
Aug-O6
Sep-Q6
Oct-o6
Nov-O6
Dec-O6
Month
Jan-o6
Feb-06
Mar-o6
Apr-o6
May-
Jun-o6
Jul-O6
Aug-
Sep-06
Oct-o6
Nov-QB
Dec-O6
Month
Jan-
Feb-06
Mar-
Apr-
May-
Jun-
Jul-O6
Aug-
Sep-06
Oct-
Nov-
Dec-
Day
Day
Day
Day
Time
1800
900
800
800
1600
1600
1500
1700
1700
800
1800
1800
METERED LOADS (CP
Non-FERC FERC
Total UT NET UT Total
149 2,430 668 960 081 416 136 056 839
152 613 786 015 898 451 140 874 055
157 553 656 955 651 425 136 626 532
144 170 536 903 569 381 119 642 922
170 067 715,884 610 547 126 575 118
157 500 768 911 900 666 111 863 010
156 684 816 978 011 561 116 972 322
137 135 704 970 140 512 131 099 728
129 229 752 931 825 492 127 787 485
153 493 743 945 720 351 116 696 521
149 507 803 033 521 460 144 490 617
168 595 773 043 494 465 148 464 686
821 28,974 8718 528 40519 727 1550 375 144 835
OR WA NET UT Total
(75)
(83)
(101)
(90)
(75)(75)
(83)(83)
(101)(101)
(71)(90)(161)
(71)(71)
(71)(71)
212)(349)(562349
equals
TIme
1800
900
800
800
1600
1600
1500
1700
1700
800
1800
1800
COINCIDENTAL PEAK SERVED FROM COMPANY RESOURCES
Non-FERC FERC
NET UT Total
149 430 668 960 081 416 136 056 839
152 613 786 015 898 451 140 874 055
157 553 656 955 651 425 136 626 532
144 170 536 903 669 381 119 642 922
170 067 715 884 610 547 126 575 118
157 500 766 911 825 666 111 768 935
156 684 816 978 928 561 116 890 239
137 135 704 970 039 512 131 998 627
129 229 752 931 735 421 127 698 324
153 493 743 945 720 351 116 696 521
149 507 803 033 521 389 144 490 546
168 595 773 043 494 394 148 3,464 615
1821 974 718 11528 170 514 550 375 795 274
TIme
1800
900
800
800
1600
1600
1500
1700
1700
800
1800
1800
OR WA UT ID W,TotaNET UT
354 354
equals
Time
1800
900
800
800
1600
1600
1500
1700
1700
800
1800
1800
LOADS FOR JURISDICTIONAL ALLOCATION (CP)
Non-FERC FERC
E. WY NET UT Total
149 2,430 668 960 081 416 136 056 839
152 613 786 015 898 451 140 874 055
157 553 656 955 651 425 136 626 532
144 170 536 903 669 381 119 642 922
170 067 715 884 610 547 126 575 118
157 500 766 911 825 666 111 788 935
156 684 816 978 928 632 116 890 310
137 135 704 970 039 583 131 998 698
129 229 752 931 735 492 127 698 395
153 2,493 743 945 720 351 116 696 521
149 507 803 033 521 460 144 490 617
168 595 773 043 494 485 148 464 686
821 974 718 528 170 868 1550 375 795 628
Page 10,
Rocky Moulntaln Powor
Idaho Genoral Rate Caso
December 2006
ENERGY
Year
2006
2006
2006
2006
2006
2006
2006
2006
2006
2006
2006
2006
Year
2006
2006
2006
2006
2006
2006
2006
2006
2006
2006
2006
2006
Year
2006
2006
2006
2006
2006
2006
2006
2006
2006
2006
2006
2006
Year
2006
2006
2006
2006
2006
2006
2006
2000
2000
2006
2006
2006
Year
2000
2006
2006
2006
2006
2000
2000
2006
2006
2006
2000
2000
Month
Jan-06
Feb-06
MaroOO
AproOO
May-O6
Jun-06Ju~
AIJII-O6
Sep-O6
QctoOO
Nov~6
De0-06
METERED LOADS MWHI
Non-FERC FERC
Total UT NetUT Total
87,708 425,718 426,674 692,486 930 168 290582 94.619 16.159 914.008 947954
524 1,284,505 386.071 620 642 734,164 264 603 048 14.321 719,843 453.556
164 368.782 372.358 664 082 777 630 273 101 029 038 761 592 633.146
888 138 459 329.000 616 482 629.720 248,773 743 733 614 987 121 066
427 151 018 338 906 613 705 823 956 311,230 88,037 695 807 261 413,279
92.700 155 900 350 398 609 372 999410 386.312 619 19,200 980,210 680 716
92,228 330745 413.214 663.307 325,592 451,549 88.579 21,527 304,006 365,214
82.536 302,141 392.337 660.340 191 124 373 430 89.674 20,987 170.138 091.583
70.078 197,336 360.834 598 623 817.284 286,300 87.149 16.798 800,486 417.609
74.520 1,233,242 375.092 670 286 759,336 258,100 501 15.461 743875 460084
344 324.952 403.362 653 763 878.665 237,261 542 15,218 863446 664890
90,291 477,570 465,710 707.915 091,211 296,755 101.396 16,875 074.336 5,230.846
990407 15390 374 613.954 771 003 22.958,260 678.008 077 936 204 012 22.754,248 56.479.943
(less)
Month
Jan-06
Feb-06
MaroOO
AproOO
MayoOO
Jun-06Ju~
Aug-06
Sep-06
OctoOO
NovoOO
DecoOO
Adjustments for Curtailments, Buy-Throughs and Load Ng Lonaor Served (Roductfonsto Load)
Non-FERC FERC
NETUT Total
(4.359)359)359)
(5.860)(841)860)701)
115)115)115)
066)(547)(6.006)613)
(4,253)(1.821)(4,253)074)
(1,261)(1,261)
601)884)601)(11,485)
31,255 10,353 31,255)(41.608
equals
Month
Jan-06
Feb-06
Mar~6
AproOO
May-O6
Jun-O6Ju~
Aug-06
Sep-O6
Oct-06
NovoOO
DecoOO
LOADS SERVED FROM COMPANY RESOURCES (NPC)
Non-FERC FERC
NetUT Total
87.708 1.425 718 426674 692.486 925 808 290 582 94.619 159 909,649 943,594
74.524 1,284 505 386071 620.642 734,164 264 603 048 14.321 719,843 453.556
83.164 368 782 372,358 664.082 630 273 101 94.029 16.038 761.592 633.146
888 138,459 329,000 616 482 629720 248,773 81.743 733 614.987 121 006
86.427 151.018 338.906 613 705 823.956 311,230 037 695 807,261 413,279
700 155,906 350.398 609.372 993.550 385,471 86.619 19,200 974,349 674015
92,228 330.745 413,214 663 307 320.477 451,549 579 21.527 298 951 360099
82,536 302.141 392.337 660 340 185,058 372.884 674 987 164.072 084970
078 197.336 360.834 598 623 813.031 284.484 149 798 796,233 411 535
520 1,233,242 375.092 670,286 759 336 258,106 501 15.461 743875 460084
344 324 952 403.362 653 763 878.665 236.001 542 15,218 863446 663 630
90,291 477 570 465 710 707 915 085,609 290871 101.396 16,875 068735 219.361
990407 15.390 374 613.954 7771.003 22.927.005 3667 655 1 077 936 204.012 22.722.993 56.438 335
plus
Month
Jan-06
Feb-06
Mar~6
Apr~6
MayoOO
Jun-06Ju~
AugoOO
Sep-O6
OctoOO
NovoOO
DecoOO
Adjustments for Ancilary Services Contracts Including Rose"",s IAddlllonsto Load)
Non-FERC FERC INCLUDING FERC REQUIRED 8Y JAM INPUT
NetUT Total
779 609 779 388
921 606 921 527
556 135 556 692
308 323 308 631
613 223 613 836
129 410 129 539
875 406 875 11,281
856 599 B56 10.455
491 526 491 017
632 407 632 039
224 467 224 691
562 825 562 386
946 536 946 44.482
equals
Month
JanoOO
Feb-06
MaroOO
AproOO
May-06
Jun-O6
Jul~6
AugoOO
Sep-06
Oct~6
Nov~6
DecoOO
LOADS FOR JURISDICTIONAL ALLOCATION (MWH)
Non-FERC FERC INCLUDING FERC (REQUIRED BY JAM INPUT
Total
708 425 718 426 674 692.486 926 587 291 191 94.619 159 910428 944 983
524 1,284 505 386 071 620.642 735 085 265,209 89.048 321 720764 455 083
164 388 782 372,358 664,082 778 186 273237 94,029 16,038 762 148 633.838
888 138 459 329 000 616.482 630 028 249.096 743 14.733 615,295 121 697
427 151 018 338 906 613705 824 569 311.453 88.037 16.695 807874 414 115
92.700 155 906 350 398 609.372 994,678 386881 86.619 19,200 975,478 676 554
92.228 330 745 413,214 663.307 321,352 461 955 579 21.527 2,299.826 371 379
538 302.141 392.337 660.340 185.914 382,483 674 987 164928 095 425
078 197 336 360 834 598 623 813.522 288011 149 798 796,724 415.552
74.520 233,242 375,092 670286 759,969 258513 501 15.461 744.507 461 123
79.344 324 952 403 362 653763 878,889 237,468 87.542 218 863.671 665 321
291 1.477 570 465,710 707 915 086 171 298696 101.396 16.875 069296 5,227 748
990.407 390 374 4613,954 7771 003 22.934,951 704,191 1 077,936 204.012 22,730.939 482.817
Page 10.
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0
,
00
%
19
9
20
0
20
1
20
2
Pa
g
e

1
0
,
20
3
20
4

T
H
I
S

S
E
C
T
I
O
N

O
F

T
H
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F
A
C
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I
N
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T

D
E
A
l
S

W
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T
H

T
H
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D
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M
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O
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C
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L
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I
V
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A
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20
5
20
6
20
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Pa
c
,

P
o
w
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r
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P
o
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Pa
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P
o
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P
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M
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M
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M
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M
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20
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I
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To
t
a
l
Pr
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o
r
t
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G
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W
A
S
H
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T
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N
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20
9
Ja
n
-
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7
69
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48
5
37
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,
18
0
13
,
59
%
19
.
31
8
,
92
.
13
1
,
41
6
,
57
,
18
,
21
0
Fe
b
-
0
6
13
5
72
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0
20
4
75
0
52
%
11
,
19
2
,
51
,
71
.
20
9
,
32
,
10
,
21
1
Ma
r
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24
0
55
4
24
0
,
55
4
83
%
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,
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5
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54
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22
8
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37
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1
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52
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29
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3
Ma
y
-
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6
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8
.
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29
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23
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38
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12
9
,
23
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21
4
Ju
n
-
21
0
,
87
9
(1
3
7
,
80
0
)
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,
07
9
68
%
56
.
16
,
24
,
94
,
17
,
21
5
Ju
l
-
25
0
94
3
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4
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.
54
0
)
10
8
,
40
3
98
%
96
,
27
,
38
,
14
3
,
25
,
21
6
Au
g
-
25
9
63
3
(1
4
2
,
41
0
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7
22
3
30
%
87
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28
,
41
.
15
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24
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21
7
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p
-
23
8
,
38
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8
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81
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57
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38
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57
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21
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.
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t
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25
4
,
49
9
78
,
07
5
33
2
57
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12
,
21
%
17
,
28
8
,
79
,
11
3
,
32
6
,
41
.
14
,
21
9
No
v
-
24
8
,
4
4
1
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8
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16
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38
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60
8
14
,
20
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20
,
34
6
,
98
,
14
2
,
47
8
,
62
.
20
,
22
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De
e
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24
9
,
58
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14
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,
83
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39
2
,
21
6
14
,
40
%
23
,
35
2
,
10
7
,
14
7
,
49
1
,
64
,
21
,
22
1
22
2
72
2
,
71
3
75
0
72
3
,
46
3
10
0
,
00
%
14
6
32
0
68
0
95
6
08
5
44
6
13
2
22
3
22
4

S
S
C
C
H

F
a
c
t
o
r
1.8
8
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29
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84
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8.4
8
%
00
%
12
.
30
%
39
,
68
%
74
%
69
%
38
%
10
0
,
00
%
22
5
22
6

S
S
G
C
H

F
a
c
t
o
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85
%
29
,
36
%
45
%
00
%
12
.
72
%
39
,
66
%
83
%
75
%
37
%
10
0
,
00
%
22
7
22
8
22
9
23
0
23
1
23
2
23
3

T
H
I
S

S
E
C
T
I
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N

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F

T
H
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F
A
C
T
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R

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N
P
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T

D
E
A
l
S

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I
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H

T
H
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M
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N
D

O
F

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L

P
U
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C
H
A
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E

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N
T
R
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C
T
S
23
4
23
5
23
6
Pa
c
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P
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w
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r
Pa
c
,

P
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w
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r
Pa
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w
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Pa
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w
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Pa
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P
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w
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,
R.
M
,
23
7
MO
N
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To
t
a
l
Pr
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o
r
l
l
o
n
CA
L
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N
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A
OR
E
G
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A
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N
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N
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A
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M
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FE
R
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23
8
Ja
n
-
23
9
Fe
b
-
0
6
24
0
Ma
r
-
24
1
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r
-
24
2
Ma
y
-
0
6
24
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Ju
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-
56
,
80
0
13
,
19
5
,
57
,
84
.
32
8
,
62
,
10
.
24
4
Ju
l
-
20
7
,
20
0
34
%
49
.
82
7
.
23
6
.
32
6
,
12
2
8
,
21
8
.
39
,
13
,
24
5
Au
g
-
22
0
80
0
36
%
48
,
73
9
,
23
8
.
6
34
7
,
12
8
6
,
20
9
.
46
,
15
,
24
6
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p
-
0
6
12
2
,
40
0
20
%
24
,
40
1
,
12
3
,
18
5
.
68
9
.
99
.
25
,
24
7
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t
-
24
8
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v
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24
9
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e
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25
0
25
1
60
7
,
20
0
10
0
%
13
5
16
4
65
6
94
4
53
3
58
7
12
2
25
2
25
3

S
S
C
P

F
a
c
t
o
r
65
%
26
,
46
%
02
%
00
%
11
,
54
%
43
,
19
%
17
%
49
%
48
%
10
0
,
00
%
25
4
25
5

S
S
G
C

F
a
c
t
o
r
68
%
28
,
21
%
95
%
00
%
11
.
91
%
42
,
89
%
35
%
57
%
46
%
10
0
,
00
%
Pa
g
e

1
0
.
25
6
25
7
25
8
25
9
28
0

T
H
I
S

S
E
C
T
I
O
N

O
F

T
H
E

F
A
C
T
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R

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N
P
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D
E
A
L
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I
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T
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M
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N
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R
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C
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S
28
1
Pa
c
,

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o
w
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r
Pa
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,

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o
w
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Pa
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w
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r
Pa
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w
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r
Pa
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w
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,
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RM
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26
2

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n
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L
OR
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26
3

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67
0
72
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5
21
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5
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,
94
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,
45
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,
03
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37
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99
9
25
4
,
19
4
28
4

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R
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4
32
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82
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5

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m
55
3
87
2
18
0
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5
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,
08
8
28
6

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n
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r
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24
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,
56
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28
7

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t
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,
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47
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35
,
15
1
35
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1
26
9

0
27
0

T
o
t
a
l
87
0
44
2
,
16
1
20
8
23
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72
,
99
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23
4
,
10
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38
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82
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98
5
28
3
01
7
,
06
9
27
1
27
2

M
C

F
a
c
t
o
r
52
9
0
%
71
,
49
7
9
%
10
,
32
3
8
%
00
0
0
%
61
9
0
%
11
,
60
6
3
%
81
5
9
%
49
5
0
%
11
3
2
%
00
0
0
%
10
0
,
00
0
0
%
27
3
27
4
27
5
27
6
27
7

T
H
I
S

S
E
C
T
I
O
N

O
F

T
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F
A
C
T
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N
P
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T
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F
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27
8
27
9
28
0
28
1
28
2
28
3

J
u
r
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s
d
i
c
t
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o
n
a
l

C
o
n
t
r
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b
u
t
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n

t
o

F
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m

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y
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m

R
e
t
a
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l

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e
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k
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(l
n
p
u
l
l
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v
e
l
)
.
28
4
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a
h
FE
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C
28
5
Pa
c
,

P
o
w
e
r
Pa
c
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P
o
w
e
r
Pa
c
,

P
o
w
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r
Pa
c
.

P
o
w
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r
Pa
c
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P
o
w
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,
RM
.
RM
,
RM
.
MT

B
o
r
d
e
r
Pa
c
,

P
o
w
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r
Ju
r
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s
Ju
r
i
s
28
6
MO
N
T
H
CA
L
OR
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WA
S
H
MO
N
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UT
A
H
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A
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a
d
s
Di
v
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s
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Div
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s
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In
p
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t
In
p
u
t
28
7
28
8
Ja
n
-
87
,
70
8
42
5
71
8
42
6
,
87
4
89
2
,
48
6
91
0
42
8
29
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,
19
1
94
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9
15
9
63
2
58
5
31
2
.
39
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92
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58
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16
.
15
9
28
9
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b
-
52
4
28
4
50
5
38
6
.
07
1
62
0
64
2
72
0
76
4
26
5
,
20
9
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,
04
8
14
,
32
1
36
5
,
74
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08
9
.
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73
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,
08
5
14
.
32
1
29
0
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r
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83
,
16
4
36
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,
78
2
37
2
,
35
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65
4
08
2
76
2
,
14
8
27
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,
23
7
94
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02
9
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8
48
8
,
38
6
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45
2
77
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18
6
16
,
03
8
29
1
Ap
r
-
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,
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8
13
8
,
45
9
32
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,
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0
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,
48
2
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5
,
29
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24
9
,
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6
81
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73
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16
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83
0
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86
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63
0
02
8
73
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29
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y
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4
2
7
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1
.
01
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33
8
90
6
61
3
,
70
5
80
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,
87
4
31
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45
3
88
,
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7
69
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19
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05
6
22
4
,
05
9
82
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,
56
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,
69
5
29
3
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-
92
,
70
0
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5
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90
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35
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,
39
8
60
9
37
2
97
5
47
8
38
6
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1
88
,
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20
0
20
8
,
37
6
46
8
.
17
8
99
4
67
8
20
0
29
4
Ju
l
-
92
,
22
8
33
0
,
74
5
41
3
21
4
66
3
,
30
7
29
9
82
8
48
1
,
95
5
88
,
57
9
21
,
52
7
49
9
,
4
9
4
87
1
88
6
32
1
,
35
2
21
,
52
7
29
5
Au
g
-
82
,
53
6
30
2
,
14
1
39
2
,
33
7
68
0
,
34
0
18
4
,
92
8
38
2
,
48
3
89
,
67
4
20
,
98
7
43
7
,
35
4
65
8
,
07
1
18
5
.
91
4
20
.
98
7
29
6
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p
-
07
8
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7
,
33
6
38
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,
83
4
59
8
,
62
3
79
8
72
4
28
8
,
01
1
87
,
14
9
79
8
22
8
,
87
0
18
8
,
68
2
81
3
52
2
16
.
79
8
29
7
Oc
t
-
74
,
52
0
23
3
24
2
37
5
,
09
2
67
0
,
28
8
74
4
,
50
7
25
8
,
51
3
89
,
50
1
15
,
4
8
1
35
3
,
14
0
10
7
98
3
75
9
,
98
9
15
,
46
1
29
8
No
v
-
79
,
34
4
32
4
,
95
2
40
3
,
36
2
85
3
,
76
3
86
3
,
67
1
23
7
,
46
8
87
,
54
2
15
,
21
8
46
1
,
4
2
2
20
3
,
89
9
87
8
,
88
9
15
,
21
8
29
9
De
c
-
90
,
29
1
47
7
57
0
46
5
,
71
0
70
7
,
91
5
06
9
29
6
29
8
.
69
6
10
1
39
6
87
5
74
1
48
5
48
6
,
28
2
08
8
17
1
16
,
87
5
30
0

T
o
t
a
l

I
n
p
u
t

99
0
,
40
7
15
,
39
0
37
4
61
3
95
4
77
1
,
00
3
22
.
73
0
,
93
9
70
4
,
19
1
07
7
93
6
20
4
,
01
2
28
,
76
5
73
9
71
7
07
8
22
,
93
4
,
95
1
20
4
.
01
2
30
1
30
2

L
o
a
d

C
u
r
t
a
i
l
m
e
n
t
30
3
Pa
g
e

1
0
.
30
4

T
e
m
p
e
r
a
t
u
r
e

A
d
j
u
s
t
m
e
n
t
Ut
a
h
FE
R
C
30
5
Pa
c
,

P
o
w
e
r
Pa
c
,

P
o
w
e
r
Pa
c
,

P
o
w
e
r
Pa
c
,

P
o
w
e
r
Pa
c
,

P
o
w
e
r
R.M
,
R.M
,
R.M
,
R.
M
,
MT

B
o
r
d
e
r
Pa
c
,

P
o
w
e
r
Ju
r
i
s
Ju
r
i
s
30
6
MO
N
T
H
CA
L
OR
E
WA
S
H
MO
N
WY
O
UT
A
H
ID
A
WY
O
FE
R
C
Lo
a
d
s
Div
i
s
i
o
n
Di
v
i
s
i
o
n
In
p
u
t
In
p
u
t
30
7
30
8
Ja
n
-
91
9
21
,
26
8
19
,
4
5
7
17
2
09
6
65
9
66
5
50
,
81
6
42
0
25
,
09
6
30
9
Fe
b
-
0
6
(2
0
4
)
04
9
)
(4
,
50
1
)
(2
,
81
2
)
87
3
)
(2
,
83
3
)
(2
9
)
(8
,
56
6
)
(8
,
73
6
)
87
3
)
31
0
Ma
r
-
(1
,
09
1
)
(2
1
32
6
)
48
4
)
11
2
91
5
)
61
0
)
(1
5
4
)
(2
6
,
78
8
)
68
0
)
(4
,
91
5
)
31
1
Ap
r
-
(2
0
3
)
37
5
07
6
)
(9
5
7
)
(2
,
70
1
)
56
4
14
1
(3
,
86
0
)
99
6
)
(2
,
70
1
)
31
2
Ma
y
-
0
6
(8
7
5
)
(1
5
,
81
0
)
(3
,
84
5
)
(3
,
77
4
)
(5
4
87
0
)
(2
,
29
5
)
(8
4
)
(2
4
,
30
4
)
(5
7
,
24
9
)
(5
4
,
87
0
)
31
3
Ju
n
-
(1
,
21
4
)
(2
5
,
94
0
)
(4
,
92
8
)
38
6
)
(6
5
,
43
5
)
(1
,
87
2
)
(1
4
3
)
(3
7
,
46
9
)
(6
7
44
9
)
(6
5
,
4
3
5
)
31
4
Ju
l
-
(1
,
88
5
)
(3
8
16
0
)
(1
7
,
03
7
)
(5
,
95
4
)
(1
0
6
14
1
)
(3
,
68
2
)
(3
3
1
)
(8
3
03
5
)
(1
1
0
,
15
4
)
(1
0
6
14
1
)
31
5
Au
g
-
(1
9
8
)
74
0
)
27
8
)
(2
,
20
8
)
(2
6
08
3
)
(4
,
52
9
)
(1
1
9
)
(1
5
,
42
4
)
(3
0
71
1
)
(2
6
06
3
)
31
6
Se
p
-
05
1
)
(2
4
39
3
)
(8
,
17
5
)
(3
6
1
)
25
5
)
(2
,
15
2
)
(9
0
)
(3
3
,
98
1
)
(7
,
49
8
)
(5
,
25
5
)
31
7
Oc
t
-
(2
0
2
)
(3
,
45
4
)
54
8
)
(2
,
37
9
)
77
9
)
(1
,
73
7
)
(1
9
1
)
(1
0
,
58
4
)
(1
0
70
7
)
77
9
)
31
8
No
v
-
64
8
10
,
99
9
(4
,
93
9
)
71
2
18
8
87
5
22
0
41
9
28
3
18
8
31
9
De
c
-
23
6
12
,
15
8
(1
0
18
8
)
30
6
26
0
10
3
50
9
43
3
26
0
32
0

T
o
t
a
l

A
d
j
.
(5
,
12
1
)
(9
4
07
3
)
(5
0
54
2
)
(7
,
52
9
)
(2
5
1
48
8
)
(1
4
,
54
4
)
(1
1
)
(1
5
7
26
6
)
(2
6
6
,
04
4
)
(2
5
1
,
48
8
)
32
1

N
e
t

E
n
e
r
g
y
98
5
28
6
15
,
29
6
,
30
1
56
3
,
41
2
76
3
47
4
22
,
4
7
9
,
45
1
68
9
,
64
7
07
7
92
5
20
4
,
01
2
28
,
60
8
,
47
3
45
1
,
03
5
22
,
68
3
,
46
3
20
4
,
01
2
32
2

I
n
p
u
t

R
a
n
g
e

f
o
r

E
x
p
e
c
t
e
d

O
w
n
e
d
In
p
u
t

R
a
n
g
e

f
o
r

F
i
r
m

O
f
f
-
s
y
s
t
e
m
32
3

H
y
d
r
o

P
e
a
k

a
t

t
i
m
e

o
f

s
y
s
t
e
m

p
e
a
k
sa
l
e
s

f
o
r

r
e
s
a
l
e

p
e
a
k

a
t

s
y
s
t
e
m
32
4
pe
a
k
Hv
d
r
o

D
a
t
a

I
n
D
u
t
Fir
m

O
f
f
-
s
v
s
t
e
m

D
a
t
a
32
5
Ro
l
l
e
d
-
P,

O
f
f

S
y
s
Da
y
s

i
n
32
6
MO
N
T
H
Pa
c
,

P
o
w
e
r
R.M
,
MO
N
T
H
Pa
c
,

P
o
w
e
r
R.M
,
Da
t
a

I
n
p
u
t
Pa
c
,

P
o
w
e
r
R.
M
,
Pa
c
,

P
o
w
e
r
R.M
,
10
0
%

L
F
Mo
n
t
h
s
32
7
32
8
Ja
n
-
Ja
n
-
32
9
Fe
b
-
0
8
Fe
b
-
0
8
33
0
Ma
r
-
Ma
r
-
33
1
Ap
r
-
Ap
r
-
33
2
Ma
y
-
0
6
Ma
y
-
0
6
33
3
Ju
n
-
Ju
n
-
33
4
Ju
l
-
Ju
l
-
33
5
Au
g
-
Au
g
-
33
6
Se
p
-
Se
p
-
0
6
33
7
Oc
t
-
Oc
t
-
33
8
No
v
.
No
v
-
33
9
De
c
-
De
c
-
34
0
34
1

T
o
t
a
l
P
k
To
t
a
l

P
k
34
2
34
3
34
4
34
5
34
6
Pa
g
e

1
0
,
34
7
34
6

T
H
I
S

S
E
C
T
I
O
N

O
F

T
H
E

F
A
C
T
O
R

I
N
P
U
T

D
E
A
L
S

W
I
T
H

T
H
E

E
N
E
R
G
Y

O
F

T
H
E

C
O
M
B
U
S
T
I
O
N

T
U
R
B
I
N
E
S
34
9
35
0
35
1
Pa
c
,

P
o
w
e
r
Pa
c
,

P
o
w
e
r
Pa
c
,

P
o
w
e
r
Pa
c
,

P
o
w
e
r
Pa
c
,

P
o
w
e
r
R.M
,
R.M
,
R.
M
,
35
2
MO
N
T
H
To
t
a
l
Pr
o
p
o
r
t
i
o
n
CA
L
I
F
O
R
N
I
A
OR
E
G
O
N

W
A
S
H
I
N
G
T
O
N
MO
N
T
A
N
A
WY
O
M
I
N
G
UT
A
H
ID
A
H
O
WY
O
M
I
N
G
FE
R
C
35
3
Ja
n
-
D
6
00
%
35
4
Fe
b
-
00
%
35
5
Ma
r
-
00
%
35
6
Ap
r
-
00
%
35
7
Ma
y
-
0
6
00
%
35
8
Ju
n
-
12
,
14
6
20
,
86
%
91
9
23
3
,
67
3
44
2
12
4
90
2
39
4
,
99
1
61
9
66
3
97
1
35
9
Ju
l
-
28
,
10
0
47
,
64
%
43
,
22
3
61
8
,
4
1
0
18
9
,
54
2
31
4
,
4
9
6
04
9
,
52
1
21
9
,
25
0
42
,
22
0
29
9
36
0
Au
g
-
48
8
31
,
48
%
91
6
40
7
13
0
12
2
,
15
1
20
7
,
16
4
67
3
,
26
1
11
8
,
97
0
28
,
19
0
60
6
36
1
Se
p
-
0
6
00
%
36
2
Oc
t
-
00
%
36
3
No
v
-
00
%
36
4
De
e
-
00
%
38
5
36
6
73
4
10
0
,
00
%
86
,
06
0
25
9
.
21
3
38
3
,
13
5
64
6
,
56
2
11
7
,
77
3
41
7
.
83
9
29
3
20
,
87
6
36
7
36
6

S
S
E
C
T

F
a
c
t
o
r
75
%
25
,
06
%
83
%
00
%
12
,
88
%
42
,
17
%
32
%
76
%
42
%
10
0
,
00
%
36
9
37
0
37
1
37
2
37
3
37
4
37
5

T
H
I
S

S
E
C
T
I
O
N

O
F

T
H
E

F
A
C
T
O
R

I
N
P
U
T

D
E
A
L
S

W
I
T
H

T
H
E

D
E
M
A
N
D

O
F

C
H
O
L
L
A

I
V
I
A
P
S
37
6
37
7
37
8
MW
H
Pa
c
,

P
o
w
e
r
Pa
c
,

P
o
w
e
r
Pa
c
.

P
o
w
e
r
Pa
c
,

P
o
w
e
r
Pa
c
,

P
o
w
e
r
R.
M
,
R.
M
,
R.
M
,
R.
M
,
37
9
MO
N
T
H
Ch
o
l
l
a

I
V
AP
S
To
t
a
l
Pr
o

o
r
t
l
o
n
CA
L
I
F
O
R
N
I
A
OR
E
G
O
N
WA
S
H
I
N
G
T
O
N
MO
N
T
A
N
A
WY
O
M
I
N
G
UT
A
H
ID
A
H
O
WY
O
M
I
N
G
FE
R
C
38
0
Ja
n
-
22
7
69
5
14
2
,
48
5
37
0
,
16
0
13
,
59
%
12
,
04
6
19
6
67
8
80
,
63
9
95
,
37
1
26
3
,
08
1
40
,
21
3
12
.
95
1
19
6
36
1
Fe
b
-
0
6
13
5
72
0
69
,
03
0
20
4
,
75
0
52
%
58
7
49
0
28
,
66
8
46
,
4
4
9
12
8
,
92
6
19
,
72
5
69
2
07
7
38
2
Ma
r
-
24
0
,
55
4
24
0
55
4
83
%
24
9
11
9
,
01
6
49
3
58
,
86
8
15
5
,
21
0
23
,
99
2
29
2
41
7
38
3
Ap
r
-
21
1
,
52
4
21
1
.
52
4
77
%
95
6
88
,
45
0
25
,
31
4
47
,
60
6
12
5
,
24
6
39
0
36
0
14
4
38
4
Ma
y
-
0
6
19
4
86
2
(7
6
,
08
0
)
11
8
,
78
2
29
%
66
6
67
8
36
7
26
,
15
4
75
,
16
9
13
,
25
7
77
1
71
6
38
5
Ju
n
.
21
0
,
87
9
(1
3
7
,
80
0
)
73
,
07
9
68
%
45
5
32
1
27
0
16
,
20
7
51
,
25
3
33
1
32
0
51
5
36
6
Ju
l
-
25
0
,
94
3
(1
4
2
,
54
0
)
10
8
40
3
96
%
59
6
51
,
44
9
15
,
78
9
26
,
16
5
67
,
31
6
18
,
24
1
51
3
65
7
38
7
AU
9
-
25
9
63
3
(1
4
2
,
4
1
0
)
11
7
,
22
3
30
%
54
4
55
,
67
0
16
,
70
3
26
,
32
7
92
,
08
1
16
,
26
6
85
5
90
3
38
8
Se
p
-
23
8
,
36
0
(6
8
,
81
0
)
16
9
,
57
0
23
%
29
8
73
,
03
0
21
,
95
7
37
,
24
9
11
1
,
54
1
17
,
79
8
5,4
2
1
04
6
38
9
Oc
t
-
25
4
,
4
9
9
78
,
0
7
5
33
2
,
57
4
12
,
21
%
07
5
15
0
,
17
5
45
,
24
9
81
,
58
1
21
1
,
95
8
31
,
35
8
90
6
88
8
39
0
No
v
-
24
8
,
4
4
1
13
6
16
5
38
6
,
60
8
14
,
20
%
11
,
35
5
18
9
,
64
3
56
,
55
8
93
,
16
9
26
5
,
00
6
33
,
63
4
12
,
45
8
16
0
39
1
De
e
-
24
9
58
1
14
2
,
63
5
39
2
,
21
6
14
,
40
%
03
7
21
4
,
54
1
65
,
60
1
10
2
,
57
0
29
6
,
04
5
43
,
02
6
14
,
61
7
43
0
39
2
39
3
72
2
71
3
75
0
72
3
46
3
10
0
,
00
%
86
7
31
4
,
14
3
39
2
,
60
7
65
9
71
4
88
4
,
61
3
28
7
,
4
3
1
91
,
15
6
16
.
35
0
39
4
39
5

S
S
E
C
H

F
a
c
t
o
r
74
%
27
,
91
%
34
%
00
%
14
,
01
%
39
,
61
%
11
%
94
%
35
%
10
0
,
00
%
39
6
39
7
39
6
39
9
40
0
40
1
40
2
Pa
g
e

1
0
.
40
3
40
4

T
H
I
S

S
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ANNUAL EMBEDDED COSTS
REVISED PROTOCOL
AVERAGE BALANCE
Company Owned Hydro. West
Account Description Amount Mwh $/Mwh Differential Reference
535 - 545 Hydro Operation & Maintenance Expense 26,204,111 Page 2.7. West only
403HP Hydro Depreciation Expense 10,175,350 Page 2,, West only
4O4IP Hydro Relicensing Amortization 823 859 Page 2,, West only
Total West Hydro Operating Expense 203 321
330 - 336 Hydro Electric Plant in Service 427,202,550 Page 2,23, West only
Powerdale Hydroelectric Facility 581,876 Powerdale Ad) (Tab 8)
302 & 186M Hydro Rellcenslng 84,130,843 Page 2,29, West only
108HP Hydro Accumulated Depreciation ReseNe (190,275,866)Page 2,, West only
1111P Hydro Relicensing Accumulated ReseNe (13,026,176)Page 2., West only
154 Materials and Supplies (21.081)Page 2.32, West only
Wes1 Hydro Net Rate Base 317,592 147
Pre-tax Retum 11,85%
Rate Base Revenue Requirement 37,631,245
Annual Em- Cost
West HydrcH:lec1rIc Resources 77,834,567 879 369 20.(88268 590) MWh from GRID
Mid C Contracts
Account Description Amount Mwh $/Mwh Differential Reference
555 Annual Mld-C Contracts Costs 702,372 017,069 22,(40,662,595) GRID
Grant Reasonable Portion 018,909)018 909 GRID
683,463 (48 681 503)
Qualified Facilities
Account Descrlp11on Amount Mwh $/Mwh Differential Reference
555 Utah Annual Qualified Facilities Costs 274,970 405,634 77,906,922
555 Oregon Annual Qualified Facilities Costs 36,658,605 272,894 134,24,974 109
555 tdaho Annual Qualified Facilities Costs 927,560 612 50.604,429
555 WYU Annual Qualified Facilities Costs
555 WYP Annual Qualified Faciiities Costs 643,362 11,474 56,152,059
555 California Annual Qualified Faciiities Costs 214.411 36,939 114,632.775
555 Washington Annual Qualified Facilities Costs 153.122 20,286 106,284,516
Total Qualified Facliities Costs 872,029 824,840 95,554,810 GRID
All Other Generation Resources
(Exct. West Hydro. Mid C, and QF)
Accoun1 Description Amount Mwh SIMwh Reference
500 - 514 Steam Operation & Maintenance Expense 802.788327 Page 2,
535 - 545 East Hydro Operation & Maintenance Expense 10,656,121 Page 2,7, East only
546 - 554 Other Generation Operation & Maintenance Expense 308,098,838 Page2,
555 Other Purchased Power Contracts 794.298,182 GRID less QF and Mld-C
40910 Renewable Energy Credit (19,305,667)Page 2,
4118 S02 Emission Allowances (2,626,736)Page 2.
James River Little Mountain Offset (5,076,241)James River Adj (Tab 5)
4038P Steam Depreciation Expense 145,169,150 Page 2.
403HP East Hydro Depreciation Expense 578 341 Page 2,15, East only
4030P Other Generation Depreciation Expense 839 144 Page 2,15
403MP Mining Depreciation Expense 379,568 Page 2,15
4O4IP East Hydro Relicensing Amortization 416 006 Page 2.16, East only
406 Amortization of Plant Acquisition Costs 479,353 Page 2,
Total All Other Operattng Expenses 079,694,387
310 - 316 Steam Electric Plant in Service 727 488,610 Page 2,
330 - 336 East Hydro Electric Plant In SeNice 99,377,759 Page 2,23, East only
302 & 186M East Hydro Relicensing 382,727 Page 2.29, East only
340 - 346 Other Electric Plant in SeNice 108 827 992 Page2.
399 Mining 378 799999 Page 2,28
10BSP Steam Accumulated Depreciation Reserve (2.330.726,830)Page 2,
1080P Other Generation Accumulated Depreciation Reserve (78,378,002)Page 2,
108MP Other Accumulaled Depreciation Reserve (144,480,260)Page 2,38. East only
108HP East Hydro Accumulated Depreciation ReseNe (37,482,896)Page 2., East only
1111P East Hydro Relicensing Accumulated Reserve (2.757,522)Page 2,39, East only
114 Electric Plant Acquisition Adjustment 157,193,780 Page 2,
115 Accumulated Provision Acquisition Adjustment (77 149,138)Page 2,
151 Fuel Stock 203,619 Page 2,
253.16-253,Joint Owner WC Deposit (1.818.328)Page 2,
253.S02 Emission Allowances (35.718.817)Page 2.
154 Materials & Supplies 073262 Page 2.
154 East Hydro Materials & Supplies
Total Net Rate Base 921 835955
Pre-tax Retum 11,85%
Rate Base Revenue Requirement 464 695,279
Annual Embedded Cost
All Other Generation Resources 544,389,865 82,779 856 42.MWh from GRID
Total Annual Embedded Costs 738,779 724 89,501,134 41.
Page 10,
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J: 3,Case No. PAC-O7-
Exhibit No. 12
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BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Direct Testimony of Steven R" McDougal
Regulatory Lag
June 2007
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BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Direct Testimony of Steven R. McDougal
Capital Investment Revenue Requirement
June 2007
Rocky Mountain Power
New Generation Resource
Idaho GRC Revenue Requirement Impact
lake Side
Resource:
Additional Capacity :
In-Service Date:
Months In Test Period:
Maintenance Costs:
Net Power Cost Savings:
Depreciation Expense:
Property Taxes:
Capital Investment :
Weighted for Months In-Service
Monthly Weighted Investment
Depreciation Reserve:
Accumulated DIT Balance:
Net Rate Base
Interest Synch
Rev. Req. on Change of Interest Exp
CWC and Bad Debt Impact
Return on Investment
Test Period Revenue Requirement
Idaho Revenue Requirement
Idaho ECD Impact
Total Impact to Idaho
lake Side e Ref.
534 MW Nominal Rating
June 30, 2007 8.8.4
Six
039 000
(28 500 000)
726 072
300,452
330,841 583
50%
165,420 792
363 036)
369,162)
161 688 594
969 758)
044 046)
P72 587)
230,921
(620 188
(39 112)
(5,845)
(44 957)
10.
estimate
estimate
8.4
Rocky Moun1ain Power
Exhibit No. \3 page 1 of
CASE NO. PAC-E-O7-
Witness Steven R, McDougal
Rocky Mountain Power
New Generation Resource
Idaho GRC Revenue Requirement Impact
Marengo
Resource:
Additional Capacity :
In-Service Date:
Months In Test Period:
Maintenance Costs:
Net Power Cost Savings:
Depreciation Expense:
Property Taxes:
Capital Investment:
Weighted for Months In-Service
Monthly Weighted Investment
Depreciation Reserve:
Accumulated DIT Balance:
Net Rate Base
Interest Synch
Renewable Energy Tax Credit
Rev. Req. on Interest Exp Tax Cr
CWC and Bad Debt Impact
Return on Investment
Test Period Revenue Requirement
Idaho Revenue Requirement
Idaho ECD Impact
Total Impact to Idaho
Maren e Ref"
140.4 MW Nominal Rating
August 1 2007 8.4
Five
168 000
(11 100 000)
309 023
822 796
258 541 351
41.67%
107 725,563
154 512)
270,634
102 300,417
144 367)
(3,406 502)
424 073)
(191 330)
065 510
649 926
167 116
516
174 632
10.
estimate
estimate
Rocky Mountain Power
Exhibit No.13 page 2 of5
CASE NO. PAC-O7-
Witness Steven R, McDougal
Rocky Mountain Power
New Generation Resource
Idaho GRC Revenue Requirement Impact
Leaning Juniper
Resource:
Additional Capacity :
In-Service Date:
Months In Test Period:
Maintenance Costs:
Net Power Cost Savings:
Depreciation Rate
Annualized Depreciation Expense:
Property Taxes:
Capital Investment :
Weighted for Months In-Service
Monthly Weighted Investment
Depreciation Reserve:
Accumulated DIT Balance:
Net Rate Base
Interest Synch
Renewable Energy Tax Credit
Rev. Req. on Interest Exp Tax Cr
CWC and Bad Debt Impact
Return on Investment
Test Period Revenue Requirement
Idaho Revenue Requirement
Idaho ECD Impact
Total Impact to Idaho
Leanin Juniper Pa e Ref.
100.5 MW Nominal Rating
Sept 14, 2006 8.
Twelve
304 000
(14 000 000)
00%
017 370
320 377
175 434 259
100%
175 434 259
532 052)
(6,736,234
164,165,973
045,904)
922 846
(12 650,176)
(214 290)
22,571 542
348 823
463,450
773
485,223
(1) Estimated based on -$4,771,499 from page 8.6 annualized for 12 months
10.
estimate
estimate
(1)
Rocky Mountain Power
Exhibit No.13 page 3 of 5
CASE NO. PAC-O7-
Witness Steven R. McDougal
Rocky Mountain Power
New Generation Resource
Idaho GRC Revenue Requirement Impact
Goodnoe Hills
Resource:
Additional Capacity :
In-Service Date:
Months In Test Period:
Maintenance Costs:
Net Power Cost Savings:
Depreciation Expense:
Property Taxes:
Capital Investment:
Weighted for Months In-Service
Monthly Weighted Investment
Depreciation Reserve:
Accumulated DIT Balance:
Net Rate Base
Interest Synch
Renewable Energy Tax Credit
Rev. Req. on Interest Exp Tax Cr
CWC and Bad Debt Impact
Return on Investment
Test Period Revenue Requirement
Idaho Revenue Requirement
Idaho ECD Impact
Total Impact to Idaho
Goodnoe Hills Page Ref.
94 MW Nominal Rating
Nov 15, 2007 8.8.4
One and a half
154 121
300,000)
982 862
187 675
196,572,406
13%
571 551
(491 431)
(746 012)
334 108
(717 211)
(546 454)
321 280)
(29 788)
208 258
881 847
613
700
313
10.
estimate
estimate
8.4
Kocky Mounlain Power
Exhibit No.13 page 4 of5C~SE NO. PAC-E-D7-Witness Steven R. McDougal
Rocky Mountain Power
New Generation Resource
Idaho GRC Revenue Requirement Impact
Huntington Scrubber
Resource:
Additional Capacity :
I n-Service Date:
Months In Test Period:
Maintenance Costs:
Net Power Cost Savings:
Depreciation Expense
Annualized Depreciation Expense:
Property Taxes:
Capital Investment :
Weighted for Months In-Service
Monthly Weighted Investment
Depreciation Reserve:
Accumulated DIT Balance:
Net Rate Base
Interest Synch
Rev. Req. on Change of Interest Exp
CWC and Bad Debt Impact
Return on Investment
Test Period Revenue Requirement
Idaho Revenue Requirement
Idaho ECD Impact
Total Impact to Idaho
Rocky Mountlin Power
Exhibit No,I3 page 5 of 5
CASE NO, PAC-O7-
Witness Steven R, McDougal
Huntington
Scrubber e Ref"
Dec 7 2006
Twelve
498 666 10.
276%
860,345
929 175
117 837 160
100%
117 837 160
091 020)
(219,394)
115 526 745
(3,550 899)
174 976)
530 640
884 027
$ 22 527 877
420 709
520
$ 1 499 229
(1) Estimated based on -$210 253 from page 8.6 annualized for 12 months
estimate
(1)