200904302008Earnings Report.pdf

~~R~OUNTAIN r: t., ~C.,',,,r:.:..,,
,,¡¡fir, ii DR '" 0 Ãl'~ 9~ 4 1Ltnj~ t\l. t \ ".J
201 South Main, Suite 2300
Salt Lake City, Utah 84111
Apól 30, 2009
V1 OVERNIGHT DELIVERY
Idaho Public Utilties Commission
472 West Washington
Boise,Id 83702-5983
Attention:Jean D. Jewell
Commssion Secreta
RE:PAC-E-02-03
Rocky Mountan Power Anua Earngs Report
Pursuat to the Stipulation and Agreement between the paries, approved and included in the
Commission s Order in Docket No. P AC-E-02-03, Rocky Mounta Power agreed to file an
anua earngs report with the Commssion.
Tramitted herewith, please fid2 copies of Rocky Mounta Power's results of operations for
the Idaho junsdiction for the twelve month ended December 31, 2008. The report provides
actu and normalized results of operations, based upon the Revised Protocol Methodology.
Informational inquires may be directed to Ted Weston, Manager, Idaho Regulatory Affairs, at
[phone].
Sincerely,
Steven R. McDougal
Director, Revenue Requirement
Enclosure
.
A DIVISION OF PACIFICORP
Idaho Jurisdiction
RESULTS OF OPERATIONS.
For Period Ending
December 2008
'.
Page 1.0
ROCKY MOUNTAIN POWER
Stte of Idaho.Acl. Adusted & Noalizd Resul1 of Oprations. RevlSld Protocol
Resul of Oparatlons December 2008
(1)(2)(3)(41 (5)(6)(7)
Unadusted Type 1 Totl Adted Typa2 Totl Annualizd Type 3 Totl Noralizd
Resul1 Adustments Ac Resul1 Adjustmnts Actual Results Adjustmnts Resul1
1 Operatng Revenues:
2 General Business Renu 197.742.910 1377.178)197.365.732 197.365.732 4.740.542 202.106.275
3 Intedepartntal
4 Special Sales 49.491.559 49.491.559 49.491.559 10.095.239 59.586.798
5 Ot Opratng Rovnus 8.342.528 99.678 8.442.40 8.442.406 292.021 8.734.427
6 Total Operatng Rovenues 255.576.997 1277.301)255.29.697 255.299.697 15.127.802 270.427.499
7
8 Oprating Exnses:9 Steam Prodon 55.786.854 489.455 56.276.309 16.06 56.29.373 1.313.29 57.607.667
10 Nuar Prodcton
11 Hydro Prodcton 2.183.118 (2,338)2.180.780 2,788 2.183.56 53.711 2,237.279
12 Ot Power Suly 86.173.314 1.520.791 87.69.105 6,583 87.700.688 6.192.174 93.892.862
13 Transmission 10.128.99 10.128.995 3.612 10.132.606 627.859 10.760.465
14 DiStrbuon 10.308.289 10.308.289 18.210 10.326.499 361.29 10.667.79
15 Customer Accounting 4.367.346 4.367.346 7.526 4.374.872 144.99 4.519.871
16 Custor Serv 1.731.66 (15.418)1.716.271 1.213 1.717.48 23.376 1.740.860
17 Sele
18 Adistrati & General 7.316.82 3,82.074 10.898.957 12.861 10.711.818 (184.489)10.527.329
xx
19 Total O&M Expeses 177.99.486 5.374.565 183.371.051 70.858 183.441.909 8.532.223 191.974.132
xx
20 Depreciati 22.141.858 (1.051)22.140.807 1.84.889 23.983.69 1.006,834 24.99.530
21 Amorzation 2.809.686 (206.699)2.602,987 54.875 2.657.862 165.425 2.823.287
22 Taxs Oter Than Incom 4.904;875 4.904,875 4.904.875 507.354 5.412.22
23 Incom Taxs. Fedoral (3.367.907)(1.883.383)(5.251.29)(2,885.435)(8.136.724)(7.84.933)(15.977.657)
24 Incom Taxes. State (26.626)1164.314)(44.94)(63.60)(508.54)11.085.29)(1.593.8441
25 Inom Taxes. Dol Nel 14.871.613 1.09.656 15.96.269 (720.22)15.242.049 10.349.84 25.591.895
26 Invesimenl Tax Credl Ad.(219.739)(219.739)(219.739)(219.739)
27 Mlsc Revnue & Expnse (419,181)33.293 (385.889)(385,889)(385.889)
xx
28 Totl Opeating Expnses:218.457.064 4.223.067 222.68.131 (1.700.639)22.979.492 11.635.452 232,614.94
29
30 Operating Rev For Return:37.119.933 (4.500.3681 32.619.565 1.700.639 34.320.204 3.492.350 37,.12.554
31
32 Rale Base:
33 Electc Planlln Serve 967.94.712 10,586.845 978.533.557 45.074.788 1,23.608.34 30.475.998 1.054.064.342
34 Plani Hold for Futuro Use 750.560 (750.5601 (01 (01 (0)
35 MiSe Deferrd Debits 4.396.590 4.396.590 4.396.590 (48.929)4.347.661
36 Elec Planl Acq Adj 4.011.821 4.011.821 4.011.821 4.011.821.37 Nuclear Fuel
36 Prepaments 2.238.589 2.236.589 2.238.589 2.238.589
39 Fuel Sto 7.402.116 7.402.116 7.402.116 2.036.930 9.439.046
40 Malrial & Suppies 9.323.356 9.323.356 9.323.356 9.323.356
41 Working Capi 3.44.373 (599.5571 2.84.817 (37.211)2,03.605 1.46 2.805,71
42 Weathriztion Loans 5.070.752 5.070.752 5.070.752 5.070.752
43 MiSe Ra Basi 307,695 307,695 307.695 307.695
xx
44 Totl Electic Plant 1.004.888.565 9.236.728 1.014.125.292 45.037.576 1.059.162,869 32.465.485 1.091.628,333
45
46 Rete Base Deduios:
47 Acum Prov For Deprc (363.401.0521 27.441 (363.373610)(921.44)(364.295.055)(503.417)(364.798.472)
48 Acm Prov For Amor (21.228.818)19.272 (21.209.54)(27.438)(21.236983)(3.083)(21.240.066)
49 Accu De Incom Tax (90.024.207)1,44.648 (88.77.559)360.110 (18.419.44)(5.150.221)(93.569.66)
50 Unamortzed ITC (50.203)335.42 285.22 285.226 285,226
51 Custor Ad For Conl (338.399)(228.697)(567.296)(567.296)(567.29)
52 Custor Serv DepollS
53 Mise Rate Basi Deduon (3.151.2761 (3.363.468)(6.521.744)(6.521.744)(37.793)(6,559.537)
54
55 Tot Rate Bas Dedus (478.20.955)(1.96.574)(48.166.528)(588.772)(480.755.300)(5.694.514)(486.449.814)
56
57 Totl Rale Base:526,6871610 7.27U54 533.58 76 44.44 805 578.407.569 26 770 951 6ß5171,519
58
59 Retun on Rale Bas 7.048%6.109 5.934%6.48%
xx
80 Return on Equit 7,972 .1,855%6.116%-0.347%5,769%0,622%6.391%
61
62 TAX CALCULATIN:
63 Opeatng Revenue 48.143.274 (5.477.408)42.665.88 (1.96.622)40.697.244 4.915.986 45.613.20
64 Ot Deductons
65 Intresl (AFDCI (2.566.373)(2.566373)(2.56.373)(2.56.373)
66 Inteesl 16.582,560 (603.545)15.979.015 1.330.155 17.309.170 101.136 18.110.306
67 Schele "Y" Adons 37.509.917 (633.9161 36.876,001 1.897.764 38.773.765 1.338.093 40.111..58
68 Schele "M" Deducton 81.520.221 (1.447.993)80,072.229 10.072.229 28.60.697 101.681.25
69 Inc Boore Tax (9.883.2181 (4.059.7661 (13.943.004)(1.401,13)(15.34.017)(23.156,774)(36.500.791 )
70
71 Sta Income Taxes 126,626)(164.314)144.94)(63.606)(508.54)(1.015.298)(1.593,841
72 Taxabl Incom li622592j f3¡75.4721 I1Ù98.641 IP37407)114835.4711 122.07114761 !3U06I!l71
73
74 Fedral Income Taxes + Otr (3.387.907)(1.883.383)(5.251.291 (2,885.435)(1.136.724)(7.84.933)(15.977.657)
(1) Type 1 adjustmnts Inol noalization for ou of period adjustmnts and unusual Itms thaI occur durln9 the tesl period.
(2) Type 2 adjstments annualiz changes _ occurrd during th lesl period.
e.(3) Typ 3 adjustmnts ar knn and measurabl Itms that WILL occur In a fure period.
IDAHO SUMMARY OF ADJUSTMENTS TOTAL Page 1.1
Ne_Cool Ot.Reven Adjusmens O&M Adjusme Admon Deoáatio &Tax Adjusmen (Tab Mise Rae Bas Adjuments
Tota Adjusment (Tab 3) (Tab 4) (TabS)Amrtion (Tab 6)7)Adjumens (Tab 6)(Tab~)Othe (Tab 10)
1 Opegi Revenues:
2 . Ge Busi.. Rewen...4,383,38 4.383.304
3 Inteepñenlll
4 SpecilSaIN 10.09.238 10,08.239
5 Otei Opatig Reveue.391.899 288.135 105,784
6 T oi. Op.lig Renues 14,850.502 4,840,499 10.201,003
7
6 ()ägE.-".:
9 $1H Prolin 1,820.812 85.531 Oeull
10 Nudu Prducn
11 Hyd Prducti 54.182 51.499 (2.336)
12oø_S.pply 7.71fi.54 0.931.287 788.25113 Tra 831.470 6un 54.194
14 Dlti 370._378;s0
15 Cusm. Accotig 152.525 152.525
18 Cu Se & Info 8,171 V,171
,7 So16A-...._3.210.447 3.428.373 (21...26)
,.T..O&Me-13.877.848 1i.;o.183 2.070.801 (2.33.)
20 OeecÌlIi 2.848.872 (374)2.849.723 (6n)
21 Amon 13.001 (7.111)81,041 (40.32.)
22 Tax. Ot Than Income 507,354 507.35
23 Ine Tue: Fedal (12.808.750)1.58.312 (3.495.501 2.705,314 (.72,515)(U22.051 (6.467.308)
24 S..(1.333.218)212.202 (474.H1)387,807 (132.149)(152.704)(1.153.2841
25 De Inme Tax 10.720.282 (41.583)(82.803)1UlQ7 1.15ll.557 9.075.914
28 In..slml TM Crit Adj.
27 Mi Re""8 & Eina 33.293 83.028 (4..738)
26 Tota Opatig E.."..:14.157.880 1.818.050 7,847.09 5.157,234 1.50.100 (2.410.843)(57.7551
2.
30 Opg Rev For Ret:892.822 2.833.449 (7.847,09)5.043.789 (1.806.1-00)2.410.843 57.75S
31
32 RaBue:33 El Plt In Se ..137.030 (32.7"")80.170.418
34 PlIHe fo Fulure Use (750.580)(750.5801
35 Mi __ Deb;"(46.021)(5.842)53.205 (0...2)
38 EI Plt Acq Adj
37 Nuçlefue
38 Pra'fents
39Fue Sl 2.036.930 2,038._
40 u. & Suppli
41 WOrt9 Ca (.35.302)(.35.301.42 We.lherti Loans
43 MiRateB..is
44 T 0~i Ellf Plt:8l.739.769 (5.842)20.419 88.724.992
45
48 Oeuclina:
41 Acm PIv For De (1.38:7,420)1.312 (1.424.882)28,129
48 Accm Pr For Amort (11.248)19.212 (30.521)
49 Accm Oe Inoome Tii (3.54.483)1;041.838 314.581 195.452)(104..3.)(4,701,01)
50 Unamrt ire 335.429 335.428:
51 CullOM' Adv For Cosl (22..e7)(22...7)
52 Cv.Se Oeo.
53 Miel OeuÇtins (3.401,60)12.744,6.3)(100.146)(55"'21)
54
55 TotaOeuc (..24..11.)(1.703.051 314.581 (175.14)11,455,.2)230.491 (5.4eO.48)
58
57 TotRateB..:78,490,910 (1,70.05)30.938 1154.594)11,45.382)230.49'151.284.512
56
59
eo E..at Roe impaç -'.580%1.112%-2.951%1.897%-0.841%0.898"--1.843%0,00%0,00
61
62
63
84 TAX CACULATION:
65
68 o,g Reveue (2,530.084)4.se;470 (11.90.183)8.128,8S7 (2.010.764)(507,35)93.080
87 0l o.etini
6.in_IAFUDC)
09 Inte 1,521,748 1.527,740
70 Seul -M- Aditns 2.801,g41 315,0i (7.224)(517.570)2,811.429.
n Se "M- Oeetia 27,181,704 205,735 (1.43..04)24,388 62.38.28.307.239
13 Inme Befre Tax (28.17.573)4,078.041 (10.482.138)8,087.070 (2..'0.764)(2.615.OS.1 (25.402.730)
7478 Sti In Taq (1.333.21.)212.292 (474,.61)367,807 (132.14.)(152.704)(1.153.284)
77T....lnme (27,84,35)4,403.749 (...7,'58)7.729,488 (2.778.'6)(2.482.35)(24.49,44)
78
79 Fed'" Inco Taxs (12.609.750)1,5l2.312 (3.495.50)2.705.314 (On.51S)(3,.22.05)(8.487.30)
.
.
.
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Rocky Mountain Power
RESULTS OF OPERATIONS
Page 2.1
USER SPECIFIC INFORMATION
STATE:
PERIOD:
IDAHO
DECEMBER 2008
FILE:
PREPARED BY:
DATE:
TIME:
10 JAM Dec 2008 Results
Revenue Requirement Department
4/24/2009
4:14:07 PM
TYPE OF RATE BASE:
ALLOCATION METHOD:
Beginning/Ending
REVISED PROTOCOL
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%
4.54%
1.614
37.951%
CAPITAL STRUCTURE INFORMATION
CAPITAL
STRUCTURE
EMBEDDED
COST
WEIGHTED
COST
DEBT
PREFERRED
COMMON
49.00%
0.40%
50.60%
100.00%
6.11%
5.41%
10.25%
2.993%
0.022%
5.187%
8.201%
OTHER INFORMATION
REVISED PROTOCOL Page 2.2
Beginning/Ending
RESULTS OF OPERATIONS SUMMARY
UNADJUSTED RESULTS IDAHO
Description of Account Summa :Ref TOTAL OTHER IDAHO ADJUSTMENTS ADJ TOTAL
1 Operating Revenues
2 General Business Revenues 2.3 3.44.033.189 3.246.290.278 197.742.910 4.363.364 202.106.275
3 Interdpartmental 2.3 0 0 0 0 0
4 Speial Sales 2.3 860.950.758 811.459.199 49.491.559 10.095.239 59.586.798
5 Other Operating Revenues 2.4 189.602.040 181.259.511 8.342.528 391.899 8,734,427
6 Total Operating Revenues 2.4 4,494.585.986 4.239.008.989 255,576.997 14.850.502 270,427,499
7
8 Operating Expenses:
9 Steam Production 2.5 894.912.140 839.125.286 55.786.854 1.820.812 57.607.667
10 Nuclear Production 2.6 0 0 0 0 0
11 Hydro Production 2.7 37.594.583 35.411.466 2.183.118 54.162 2.237.279
12 Other Power Supply 2.9 1.322.716.164 1.236.542.850 86.173.314 7.719.548 93.892.862
13 Transmission 2.10 174.010.394 163.881.399 10.128.995 631,470 10.760.465
14 Distnbution 2.12 215.36.277 205.055.987 10.308.289 379.509 10.687.799
15 Customer Accounting 2.12 99.309.086 94.941.740 4.367.346 152.525 4.519.871
16 Customer Service & Infor 2.13 14.039.833 12.308.144 1.731.689 9.171 1.740.860
17 Sales 2.13 0 0 0 0 0
18 Administrative & General 2.14 170.044.138 162.727.255 7.316.882 3.210.447 10.527.329
19
20 Total 0 & M Expenses 2.14 2.927.990.614 2.749.994.128 177.996,486 13.977.646 191.974,132
21
22 Depreciation 2.16 408.039.444 385.897.586 22.141.858 2.848.672 24.990.530
23 Amortization 2.17 57.142.964 54.333.277 2.809.686 13.601 2.823.287
24 Taxes Other Than Income 2.17 112,424.490 107.519.615 4.904.875 507.354 5,412.229
25 Income Taxes. Federal 2.20 18.046.369 21.414.276 (3.367.907)(12.609.750)(15.977.657)
26 Income Taxes. State 2.20 1.883.876 2.144.502 (260.626)(1.333.218)(1.593.844)
27 Income Taxes. Def Net 2.19 261.104.676 246.233.063 14.871.613 10.720.282 25.591.895
28 Investment Tax Credit Adj.2.17 (1.874.204)(1.654,465)(219.739)0 (219.739)
29 Misc Revenue & Expense 2.4 (7.004.252)(6.585.071 )(419.181 )33.293 (385.889)
30
31 Total Operating Expenses 2.20 3.77.753.976 3.559.296.911 218.457.064 14.157.880 232.614.944
32.Operating Revenue for Return 716.832.011 679.712.078 37.119.933 692.622 37.812.554
Rate Base:
36 Electnc Plant in Service 2.30 17.252.000.564 16.284.053.852 967.946.712 86.137.630 1.054.084.342
37 Plant Held for Future Use 2.31 14.385.862 13.635.301 750.560 (750.560)(0)
38 Mise Deferred Debits 2.33 148.502.262 144.105.672 4.396.590 (48.929)4.347.661
39 Elec Plant Acq Adj 2.31 69.085.936 65.074.116 4.011.821 0 4.011.821
40 Nuclear Fuel 2.31 0 0 0 0 0
41 Prepayments 2.32 38.987.409 36.748.819 2.238.589 0 2.238.589
42 Fuel Stock 2.32 115.236.521 107.834.405 7.402.116 2.036.930 9,439.046
43 Matenal & Supplies 2.32 159.789.695 150.466.339 9.323.356 0 9.323.356
44 Working Capital 2.33 64.402.186 60.961.813 3.44.373 (635.302)2.805.071
45 Weathenzation Loans 2.31 15.127.554 10.056.802 5.070.752 0 5.070.752
46 Miscellaneous Rate Base 2.34 4.314.182 4.006.487 307.695 0 307.695
47
48 Total Electrc Plant 17.881.832.171 16.876.943.607 1.004.888.565 86.739.769 1.091.628.333
49
50 Rate Base Deductions:
51 Accum Prov For Depr 2.38 (6.250.117.933)(5.886.716.881 )(363.401.052)(1.397.420)(364.798,12)
52 Accum Prov For Amort 2.39 (406.297.379)(385.068.561 )(21.228.818)(11.248)(21.240.06)
53 Accum Def Income Taxes 2.35 (1,476.614.252)(1.386.590.045)(90.024.207)(3.545.463)(93.569.669)
54 Unamortzed ITC 2.35 (9.730.900)(9.680.697)(50.203)335.429 285.226
55 Customer Adv for COnst 2.34 (18.872.683)(18.534.285)(338.399)(228.897)(567.296)
56 Customer Service Deposits 2.34 0 0 0 0 0
57 Mise. Rate Base Deductions 2.34 (57.806.226)(54.647.950)(3.158.276)(3.401.260)(6.559.537)
58
59 Total Rate Base Deductions (8.219.439.373)(7.741.238.419)(478.200.955)(8.248.859)(466.449.814)
60
61 Total Rate Base 9.662.392.798 9.135.705.188 526.687.610 78.490.910 605.178.519
62
63 Return on Rate Base 7.419%7.048%6.248%
64
65 Retum on Equity 8.705%7.972%6.391%
66 Net Power Costs 1.107.954.703 72.234.265 65.405.233
67 100 Basis Points in Equity:.Revenue Requirement Impact 78.795.319 4.295.056 4.935.137
Rate Base Decrease (616.946.911 )(35.280.738)(45.337.997)
REVISED PROTOCOL Page 2.3
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
70 Sales to Ultimate Customers.44 Residential Sales
0 S 1.345.013.663 1.286.561.943 58.451.721 (27.456)58.424.265
74 Bl 1.345.013.663 1.286.561.943 58,451.721 (27.456)58.424.265
75
76 442 Commercial & Industrial Sales
77 0 S 2.060.710.026 1.921.886.078 138.823.948 4.390.820 143.214.768
78 P SE
79 PT SG
80
81
82 81 2.060.710.026 1.921.886.078 138.823.948 4.390.820 143.214.768
83
84 44 Public Street & Highway Lighting
85 0 S 19.865.594 19.398.352 467.242 467.242
86 0 SO
87 81 19.865.594 19.398.352 467.242 467.242
88
89 445 Other Sales to Public Authority
90 0 S 18.44.905 18.443.905
91
92 81 18,443.905 18.443.905
93
94 448 Interdepartmental
95 DPW S
96 GP SO
97 81
98
99 Total Sales to Ultimate Customers B1 3,44.033.189 3.246.290.278 197.742.910 4.363.36 202.106.275
100
101
102
103 447 Sales for Resale-Non NPG
104 WSF S 8.626.127 8.626.127
105 8.626.127 8.626.127.447NPG Sales for Resale-NPG
WSF SG 852.781.657 803.260.624 49.521.033 10.065.764 59.586.798
109 WSF SE (457.026)(427.552)(29.475)29,475 (0)
110 WSF SG
111 852.324.631 802.833.072 49,491.559 10.095.239 59.586.798
112
113 Total Sales for Resale 81 860.950.758 811,459.199 49.491.559 10.095.239 59.586.798
114
115 449 Provision for Rate Refund
116 WSF S
117 WSF SG
118
119
120 81
121
122 Total Sales from Electricity Bl 4,304.983.947 4,057.749.478 247,234.469 14,458.803 261.693.072
123 45 Forfeited Discounts & Interest
124 GUST S 7.486.736 7.028.154 458.582 45.582
125 CUST SO
126 81 7.486.736 7.028.154 458.582 458.582
127
128 451 Mise Electric Revenue
129 GUST S 7.051.612 6.892.092 159.520 159.520
130 GP SG
131 GP SO 28.158 26.578 1.580 1.580
132 81 7.079.770 6.918.670 161.100 161.100
133
134 453 Water Sales
135 P SG 26,405 24.872 1.533 1.533
136 81 26.405 24.872 1.533 1.533
137
138 454 Rent of Electric Propert
139 DPW S 11.890,427 11.579.610 310.817 310.817
140 T SG 5.426.451 5.111.337 315.114 315.114-GP SO 3.262.547 3.079.498 183.050 183.050
81 20.579.425 19.770.445 808.980 808.980
44
REVISED PROTOCOL Page 2.4
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
145.456 Other Electric Revenue
DMSC S 37.234.750 37.233.784 966 966
CUST CN
149 OTHSE SE 16.625.527 15.553.305 1.072.222 22.775 1.094.997
150 OTHSO SO 469,412 443.075 26.337 26.337
151 OTHSGR SG 100.100.013 94.287.205 5.812.808 369.123 6.181.931
152
153
154 61 154,429.703 147.517.370 6.912.333 391.899 7.304.232
155
156 Total Other Electric Revenues Bl 189.602.040 181.259.511 8,342,528 391.899 8.734.427
157
158 Total Electnc Operating Revenues B1 4.494.585.986 4.239.008.989 255.576.997 14,850.502 270.427.499
159
160 Summary of Revenues by Factor
161 5 3.516.322.840 3.317.650.046 198.672.795 4.363.364 203.36.159
162 CN
163 5E 16.168.501 15.125.754 1.042.747 52.250 1.094.997
164 SO 3.760.118 3.549.151 210.966 210.966
165 5G 958.334.527 902.684.038 55.650,489 10,434.887 66.085.376
166 DGP
167
168 Total Electric Operating Revenues 4.494.585.986 4.239.008.989 255.576.997 14.850.502 270.427,499
169 Miscllaneous Revenues
170 41160 Gain on Sale of Utilty Plant - CR
171 DPW S
172 T SG
173 G SO
174 T SG
175 P SG
176 61
177
178 41170 Loss on Sale of Utiity Plant
179 DPW S
180 T SG.61
4118 Gain from Emission Allowances
184 P S
185 P SE (4.889.027)(4.573.722)(315.306)109.571 (205.735)
186 61 (4.889.027)(4.573.722)(315.306)109.571 (205.735)
187
188 41181 Gain from Disposition of NOX Credits
189 P SE
190 61
191
192 4194 Impact Housing Interest Income
193 P SG
194 61
195
196 421 (Gain) / Loss on Sale of Utility Plant
197 DPW S (344.622)(344.622)(49.736)(49.736)
198 T 5G
199 T SG (378.094)(356.138)(21.956)(21.956)
200 PTD CN 2.169 2.085 84 84
201 PTD SO 516.915 487.913 29.002 (26.542)2,460
202 P SG (1.911.594)(1.800.587)(111.006)(111.006)
203 61 (2.115.225 )(2.011.349)(103.876)(76.278)(180.154)
204
205 Total Miscellaneous Revenues (7.004,252)(6,585,071)(419.181)33,293 (385.889)
206 Miscellaneous Expenses
207 4311 Interest on Customer Deposits
208 CUST S
209 61
210 Total Miscellaneous Expenses
211
212 Net Mlsc Revenue and Expense Bl (7,004.252)(6,585,071)(419,181)33,293 (385.889)
213.
REVISED PROTOCOL Page 2.5
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
214 500 Operation Supervision & Engineering"P SG 20,414.209 19.228.756 1.185.453 219.040 1.404.493
P SSGCH 1,424.208 1.343.562 80.646 (11)80.635
82 21.838,417 20.572.318 1.266.099 219.028 1,485.128
218
219 501 Fuel Related-Non NPC
220 P SE 13.030.759 12.190.372 840.386 3.346 843.733
221 P SE
222 P SE
223 P SSECT
224 P SSECH 2.171.201 2.038.989 132.213 132.213
225 B2 15,201.960 14.229.361 972.599 3.346 975.945
226
227 501NPC Fuel Related-NPC
228 P SE 562.030.147 525.783,408 36.246.739 400.597 36.647.336
229 P SE
230 P SE
231 P SSECT
232 P SSECH 47.679.955 44.776.544 2.903.411 567.472 3.470.882
233 B2 609.710.102 570.559.952 39.150.150 968.069 40.118.218
234
235 Total Fuel Related 624.912.062 584,789.313 40.122.749 971.415 41.094.164
236
237 502 Steam Expenses
238 P SG 32.863.919 30.955.511 1.908.408 1.908.408
239 P SSGCH 4.623.599 4.361.787 261.812 261.812
240 B2 37.487.518 35.317.298 2.170.220 2,170.220
241
242 503 Steam From Other Sources-Non-NPC
243 P SE
244 B2
245
246 503NPC Steam From Other Sources-NPC
247 P SE 3.371.385 3.153.956 217.429 (2.787)214.642
248 B2 3.371.385 3.153.956 217.429 (2.787)214.642
249
lI 505 Electric Expenses
P SG 2.737.130 2.578.184 158.945 158.945
P SSGCH 1.56.174 1.477.489 88.685 88.685
B2 4.303.303 4.055.673 247.630 247.630
254
255 506 Misc. Steam Expense
256 P SG 40.299.217 37.959.041 2.340.176 2.340.176
257 P SE
258 P SSGCH 3.273.208 3.087.862 185.346 185.346
259 B2 43.572.425 41.046.903 2.525.522 2.525.522
260
261 507 Rents
262 P SG 277.611 261,490 16.121 16.121
263 P SSGCH 3.770 3.557 213 213
264 B2 281.381 265.046 16.334 16.334
265
266 510 Maint Supervision & Engineering
267 P SG 3.996.072 3.764.020 232M2 489,455 721.506
268 P SSGCH 2.012.831 1.898.855 113.977 113.977
269 B2 6.008.903 5.662.875 346.029 489.455 835,83
270
271
272
273 511 Maintenance of Structures
274 P SG 23.718.380 22.341.053 1.377.326 1.377.326
275 P SSGCH 1.115.728 1.052.550 63.178 63.178
276 B2 24.834.108 23.393.603 1.44.505 1.440.505
277
278 512 Maintenance of Boiler Plant
279 P SG 80.611.372 75.930.270 4.681.103 144.837 4.825.940
280 P SSGCH 6.064.085 5.720,705 343.380 (1.135)342.244
281 B2 86.675,457 81.650.975 5.024.482 143.702 5.168.184
282
283 513 Maintenance of Electric Plant
284 P SG 27.262.127 25.679.015 1.583.112 1.583.112
285 P SSGCH 1.611.953 1.520.676 91.277 91.277.B2 28.874.080 27.199.691 1.674.389 1.674.389
514 Maintenance of Misc. Steam Plant
289 P SG 9.219.334 8.683.967 535.367 535.367
290 P SSGCH 3.533.767 3.333.667 200.100 200.100
291 B2 12.753.101 12.017.634 735.467 735,467
292
293 Total Steam Power Generation 82 894,912,140 839,125.286 55,786,854 1,820,812 57,607.661
REVISED PROTOCOL Page 2.6
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
294 517 Operation Super & Engineering.P SG
82
298 518 Nuclear Fuel Expense
299 P SE
300
301 82
302
303 519 Coolants and Water
304 P SG
305 82
306
307 520 Steam Expenses
308 P SG
309 82
310
311
312
313 523 Electric Expenses
314 P SG
315 82
316
317 524 Misc. Nuclear Expenses
318 P SG
319 B2
320
321 528 Maintenance Super & Engineering
322 P SG
323 B2
324
325 529 Maintenance of Structures
326 P SG
327 82
328
329 530 Maintenance of Reactor Plant.P SG
B2
333 531 Maintenance of Electric Plant
334 P SG
335 B2
336
337 532 Maintenance of Misc Nuclear
338 P SG
339 82
340
341 Total Nuclear Power Generation 82
342
343 535 Operation Super & Engineering
344 P DGP
345 P SG 7.893.949 7.435.547 458.402 26.761 485.162
346 P SG 932.247 878.112 54.136 21.949 76.085
347
348 B2 8.826.196 8.313.659 512.537 48.710 561.247
349
350 536 Water For Power
351 P DGP
352 P SG 292,471 275.487 16.984 16.984
353 P SG 8.916 8.399 518 518
354
355 B2 301.387 283.886 17.502 17.502
356
.
REVISED PROTOCOL Page 2.7
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
357 537 Hydraulic Expenses.p DGP
P SG 3.695.558 3.480.957 214.601 214.601
P SG 394.896 371.964 22.932 22.932
361
362 B2 4.090,454 3.852.922 237,533 237,533
363
364 538 Electric Expenses
365 p DGP
366 P SG
367 P SG
368
369 B2
370
371 539 Misc. Hydro Expenses
372 p DGP
373 P SG 11.978.982 11.283.363 695.620 (2.338)693.282
374 P SG 5.866.793 5.526.108 340.685 340.685
375
376
377 B2 17.845.775 16.809,471 1.036.304 (2.338)1.033.967
378
379 540 Rents (Hydro Generation)
380 P DGP
381 P SG 141.883 133.644 8.239 8.239
382 P SG (645)(607)(37)(37)
383
384 B2 141,238 133.037 8.202 8.202
385
386 541 Maint Supervision & Engineering
387 P DGP
388 P SG 2.681 2.525 156 156
389 P SG
390
391 B2 2.681 2.525 156 156
392.542 Maintenance of Structures
P DGP
P SG 1.136.789 1.070.775 66.013 66.013
396 P SG 88.380 83.248 5.132 5.132
397
398 B2 1.225.169 1.154.023 71.146 71.146
39940
401
402
403 543 Maintenance of Dams & Waterways
404 P DGP
405 P SG 992.623 934.981 57.642 57.642
406 P SG 44.661 418.840 25.821 25.821
407
408 B2 1.437.284 1.353.821 83.463 83,463
409
410 544 Maintenance of Electric Plant
411 P DGP
412 P SG 1.056.967 995.589 61.378 61.378
413 P SG 515.650 485.706 29.944 29.944
414
415 B2 1.572.616 1.481.295 91.322 91.322
416
417 545 Maintenance of Misc. Hydro Plant
418 P DGP
419 P SG 1.44.329 1.364.225 84.104 5.548 89.652
420 P SG 703.452 662.602 40.849 2.242 43.091
421
422 B2 2.151.781 2.026.827 124.954 7.790 132.743
423
424 Total Hydraulic Power Generation B2 37.594.583 35.411.466 2.183.118 54.162 2.237.279
.'
REVISED PROTOCOL Page 2.8
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
425.546 Operation Super & Engineering
P SG 218.466 205.780 12.686 12.686
P SSGCT
429 62 218,466 205.780 12.686 12.686
430
431 547 Fuel.Non-NPC
432 P SE
433 P SSECT
434 62
435
436 547NPC Fuel-NPC
437 P SE 431.973.414 404.114.361 27.859.053 3.338.094 31.197.148
438 P SSECT 34.989.341 32.329.867 2.659.474 (1.048.195)1.611.279
439 62 466.962.755 436.444.227 30.518.527 2.289.899 32.808,26
44
441 548 Generation Expense
442 P SG 13.283.098 12.511.749 771.350 16.271 787.620
443 P SSGCT 4.561.937 4.280.008 281.929 (180.501)101,428
444 62 17.845.036 16.791.757 1.053.278 (164.230)889.049
445
446 549 Miscellaneous Other
447 P SG 10.943.849 10.308.340 635.509 821.118 1,456.627
44 P SSGCT
449 62 10.943.849 10.308.340 635.509 821.118 1,456.627
450
451
452
453
454 550 Rents
455 P SG 2.156.539 2.031.308 125.230 125.230
456 P SSGCT 4.583.304 4.300.055 283.249 (283.249)0
457 62 6.739.843 6.331.363 408,480 (283.249)125.230
458
459 551 Maint Supervision & Engineering
460 P SG.62
552 Maintenance of Structures
464 P SG 1.000.631 942.524 58.107 58.107
465 P SSGCT 279.717 262.431 17.287 (10.276)7.011
466 62 1.280.348 1.204.955 75.393 (10.276)65.117
467
468 553 Maint of Generation & Electric Plant
469 P SG 5.023.341 4.731.636 291.705 349.260 640.965
470 P SSGCT 887.917 833.043 54.874 (10.195)44.679
471 62 5.911.258 5.564.679 346.579 339.065 685.644
472
473 554 Maintenance of Misc. Oter
474 P SG 140.290 132.143 8.147 8.147
475 P SSGCT 342.636 321.461 21.175 (7.664)13.511
476 62 482.926 453.604 29.322 (7.664)21.657
477
.478 Total Other Power Generation 82 510.384.480 477.304.705 33.079.775 2,984.663 36.064.438
479
480
481 555 Purchased Power-Non NPC
482 DMSC S (4.878.060)(5.431.791)553.731 (553.731)
483 (4.878.060)(5.431.791)553.731 (553.731)
484
485 555NPC Purchased Power-NPC
486 P SG 650.037.045 612.289.392 37.747.653 1.796.968 39.544.621
487 P SE 109.030.864 101.999.189 7.031.675 (2.790.023)4.241.652
488 Seasonal Co P SSGC 458.888 458.888
489 DGP
490 759.067.909 714.288.581 44.779.328 (534.167)44.245.161
491
492 Total Purchased Power 62 754.189.849 708.856.790 45.333.059 (1.087.898)44.245.161
493
494 556 System Control & Load Dispatch
495 P SG 1.997.891 1.881.873 116.018 116.018
'I 62 1.997.891 1.881.873 116.018 116.018
REVISED PROTOCOL Page 2.9
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
500.557 Other Expenses
p S (183.792)(150.819)(32.973)6.005.556 5.972.582
P SG 55.161.624 51.958.389 3.203.236 (180.192)3.023.044
504 P SGCT 1.122.425 1.056.994 65.431 65.431
505 P SE
506 P SSGCT 43.687 40.987 2.700 (2.580)119
507 P TROJP
508
509 62 56.143.944 52.905.551 3.238.393 5.822.784 9.061.177
510
511 Embedded Cost Differentials
512 Company Owned Hyd P DGP (65.382.628)(65.382.628)
513 Company Owed Hyd P SG 65.382.628 61.585.859 3.796.769 3.796.769
514 Mid-C Contract P MC (50.941,480)(49.992.201)(949.279)(949.279)
515 Mid-e Contract P SG 50.941.480 47.983.308 2.958.172 2.958.172
516 Existing OF Contracts P S 40,697.259 39.733.563 963.696 963.696
517 Existing OF Contracts P SG (40.697.259)(38.333.969)(2.363.290)(2.363.290)
518
519 (4.406.069)4.406.069 4.406.069
520
521 Total Other Power Supply B2 812.331.684 759,238.146 53,093.539 4.734;885 57.828,424
522
523 Total Prouction Expense B2 2,255.222.887 2,111,079.602 144.143.285 9.594.523 153.737.808
524
525
526 Summary of Production Expense by Factor
527 S 35.635,407 34.150.952 1.484.454 5,451.825 6.936.279
528 SG 1.094.583.576 1.031.021.105 63.562.472 3.710.918 67.273.389
529 SE 1.119,436.569 1.047.241.286 72.195.283 949.227 13.144.510
530 SNPPH
531 TROJP
532 SGCT 1.122.425 1.056.994 65.431 65.431
533 DGP (65.382.628)(65.382.628)
534 DEU
535 DEP.SNPPS
SNPPO
DGU
539 MC (50.941.480)(49.992.201)(949.279)(949.279)
540 SSGCT 10.699.198 10.037.985 661.213 (494.465)166.748
541 SSECT 34.989.341 32.329.867 2.659.474 (1.048.195)1.611.279
542 SSGC 458.888 458.888
543 SSGCH 25.229.323 23.800.709 1,428.614 (1,147)1.427,468
544 SSECH 49.851.156 46.815.533 3.035.623 567.472 3.603.095.
545 Total Production Expense by Factor 62 2.255.222.887 2.111.079.602 144.143.285 9.594.523 153.737.808
546 560 Operation Supervision & Engineering
547 T SG 7.808.710 7.355.258 453.452 57.536 510.988
548
549 62 7.808.710 7.355,258 453.452 57.536 510.988
550
551 561 Load Dispatching
552 T SG 8.536.145 8.040.451 495.694 (4.722)490.972
553
554 62 8.536.145 8.040,451 495.694 (4.722)490.972
555 562 Station Expense
556 T SG 1.869.851 1.761.268 108.582 108.582
557
558 62 1.869.851 1.761.268 108.582 108.582
559
560 563 Overhead Line Expense
561 T SG 93.337 87.917 5,420 5,420
562
563 62 93.337 87.917 5.420 5.420
564
565 564 Underground Line Expense
566 T SG
567
568 62
569.
REVISED PROTOCOL Page 2.10
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
570 565 Transmission of Electricity by Others.T SG
T SE
574
575 565NPC Transmission of Electncity by Others-NPC
576 T SG 117.397,550 110.580.273 6.817.276 775.200 7.592,476
577 T SE 3.769.633 3.526.520 243,113 (230.006)13.107
578 121.167.183 114.106.793 7.060.389 545.194 7.605.583
579
580 Total Transmission of Electncity by Others 62 121.167.183 114.106.793 7.060,389 545.194 7.605.583
581
582 566 Misc. Transmission Expense
583 T SG 1.795.131 1.690.888 104.243 104.243
584
585 62 1.795.131 1.690.888 104.243 104.243
586
587 567 Rents - Transmission
588 T SG 822.667 774.894 47.772 47.772
589
590 62 822.667 774.894 47.772 47.772
591
592 568 Main! Supervision & Engineering
593 T SG 9.822 9.252 570 570
594
595 62 9.822 9.252 570 570
596
597 569 Maintenance of Structures
598 T SG 4.128.899 3.889.134 239.765 239.765
599
600 62 4.128.899 3.889,134 239.765 239.765
601
602 570 Maintenance of Station Equipment
603 T SG 11.093.119 10.44.941 644.177 644.177
604
605 62 11.093.119 10,448.941 644.177 644.177
4 571 Maintenance of Overhead Lines
T SG 16.204.998 15.263.974 941.024 33.463 974,487
610 62 16.204.998 15.263.974 941.024 33,463 974,487
611
612 572 Maintenance of Underground Lines
613 T SG
614
615 62
616
617 573 Maint of Misc. Transmission Plant
618 T SG 48.533 452.628 27.905 27.905
619
620 62 480.533 452.628 27.905 27.905
621
622 Total Transmission Expense B2 174.010.394 163.881.399 10.128.995 631.470 10.760.465
623
624 Summary of Transmission Expense by Factor
625 SE 3.769.633 3.526.520 243.113 (230.006)13.107
626 SG 170.240.761 160.354.879 9.885.881 861,477 10.747.358
627 SNPT
628 Total Transmission Expense by Factor 174.010.394 163.881.399 10.128.995 631,470 10.760,465
629 580 Operation Supervision & Engineenng
630 DPW S 176.450 219.560 (43.110)62.828 19.718
631 DPW SNPD 20.120.363 19.182.315 938.049 131,478 1.069.527
632 62 20.296.814 19.401.875 894.939 194.306 1.089.245
633
634 581 Load Dispatching
635 DPW S
636 DPW SNPD 12.782.671 12.186.719 595.952 (4.165)591.787
637 62 12.782.671 12.186.719 595.952 (4.165)591.787
638
639 582 Statin Expense64DPW S 4.548.284 4.294.351 253.933 253.933
641 DPW SNPD 25.883 24.676 1.207 1.207.62 4.574.167 4.319.027 255.140 255.140
REVISED PROTOCOL Page 2.11
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DE SCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
Ii 583 Overhead Line Expenses
DPW S 5.378.951 5.216.983 161.967 161.967
DPW SNPD 13.397 12.772 625 625
47 82 5.392,347 5.229.756 162.592 162.592
648
649 584 Underground Line Expense
650 DPW S 403 403
651 DPW SNPD
652 62 403 403
653
654 585 Street Lighting & Signal Systems
655 DPW S
656 DPW SNPD 222.030 211.679 10.351 10.351
657 62 222.030 211.679 10.351 10.351
658
659 586 Meter Expenses
660 DPW S 6.033.669 5.690.925 342.745 342,745
661 DPW SNPD ,1.171,018 1.116,423 54.595 54.595
662 62 7.204.688 6.807.348 397.340 397,340
663
664 587 Customer Installation Expenses
665 DPW S 11.063.638 10.354.314 709.324 709.324
666 DPW SNPD
667 62 11.063.638 10.354.314 709.324 709.324
668
669 588 Misc. Distribution Expenses
670 DPW S 2.878.136 2.764.905 113.231 113.231
671 DPW SNPD 5.511.145 5.254.206 256.940 256.940
672 62 8.389,281 8.019.111 370.170 370.170
673
674 589 Rents
675 DPW S 2.775.451 2.760.505 14.946 14.946
676 DPW SNPD 262.718 250,470 12.248 12.248
677 62 3.038.169 3.010.975 27.195 27.195
678
679 590 Maint Supervision & Engineering.DPW S 655.797 621.844 33.953 33.953
DPW SNPD 5.766.096 5.497.270 268.826 3.274 272.100
62 6.421.892 6.119.114 302.779 3.274 306.052
683
684 591 Maintenance of Structures
685 DPW S 1.794.408 1.686.481 107.927 107.927
686 DPW SNPD 235.753 224.762 10.991 10.991
687 62 2.030.161 1.911.243 118.918 118.918
688
689 592 Maintenance of Station Equipment
690 DPW S 9.638.957 9.063.789 575.168 575.168
691 DPW SNPD 1.908.269 1.819.302 88.967 6.413 95.380
692 62 11.547.226 10.883.091 664.135 6.413 670.547
693 593 Maintenance of Overhead Lines
694 DPW S 83,473.495 79.010.806 4.462.689 148.506 4.611.195
695 DPW SNPD 1.527.842 1.456.611 71.231 31.176 102.407
696 62 85.001.337 80,467.417 4.533.920 179.682 4.713.602
697
698 594 Maintenance of Underground Lines
699 DPW S 23.522.169 22.876.326 645.843 645.843
700 DPW SNPD 17.740 16.913 827 827
701 62 23.539.909 22.893.239 646.670 646,670
702
703 595 Maintenance of Line Transformers
704 DPW S
705 DPW SNPD 1.116.622 1.064.563 52.059 52.059
706 62 1.116.622 1.064.563 52.059 52.059
707
708 596 Maint of Street Lighting & Signal Sys.
709 DPW S 4.138.856 3.975.816 163.040 163.040
710 DPW SNPD
711 62 4.138.856 3.975.816 163.040 163.040
712.
REVISED PROTOCOL Page 2.12
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
713 597 Maintenance of Meters.DPW S 4.232.548 3.960.506 272.042 272,02
DPW SNPD 979.626 933.954 45.672 45.672
82 5.212.174 4.894,460 317.714 317.714
717
718 598 Maint of Misc. Distribution Plant
719 DPW S 3.853.384 3.745.816 107.568 107.568
720 DPW SNPD (461.493)(439.978)(21.516)(21.516)
721 82 3.391.891 3.305.839 86.052 86,02
722
723 Total Distribution Expense B2 215.364.277 205.055.987 10.308.289 379.509 10.687.799
724
725
726 Summary of DislnbulionExpense by Factor
727 S 164.164.596 156.243.331 7.921.265 211.334 8.132.599
728 SNPD 51.199.681 48.812.657 2.387.024 168.175 2.555.200
729
730 Total Distribution Expense by Factor 215.364.277 205.055.M7 10.308.289 379.509 10.687.199
731
732 901 Supervision
733 CUST S 168.874 166.227 2.647 2.647
734 CUST CN 2.309.075 2.219.510 89.565 89.565
735 62 2.477.949 2.385.737 92.212 92.212
736
737 902 Meter Reading Expense
738 CUST S 23.763.080 22.015.137 1.747.942 1.747.942
739 CUST CN 1.526.632 1.467.417 59.215 59.215
740 62 25.289.712 23.482.554 1.807.158 1.807.158
741
742 903 Customer Receipts & Collections
743 CUST S 6.381.549 6.175.307 206.242 80.928 287.170
744 CUST CN 50.255.601 48.306.279 1.949.322 71.597 2.020,919
745 62 56.637.149 54,481.586 2.155.564 152.525 2.308.089
746
747 904 Uncollectible Accounts
748 CUST S 14.663.103 14.359.698 303,406 303.406.P SG
CUST CN 11.611 11.161 450 450
62 14.674,714 14.370.858 303.856 303,856
752
753 905 Misc. Customer Accounts Expense
754 CUST S 8.966 8.966
755 CUST CN 220.595 212.039 8.556 8.556
756 82 229.561 221.005 8.556 8.556
757
758 Total Customer Accounts Expense 82 99.309.086 94.941.740 4.367.346 152,525 4.519.871
759
760 Summary of Customer Accts Exp by Factor
761 S 44.985.572 42.725.334 2.260.237 80.928 2.341.165
762 CN 54.323.514 52.216.406 2.107.108 71.597 2.178.706
763 SG
764 Total Customer Accounts Expense by Factor 99.309,086 94.941.40 4.367.346 152.525 4.519.811
765
766 907 Supervision
767 CUST S
768 CUST CN 247.987 238.368 9.619 9.619
769 62 247.987 238.368 9.619 9.619
770
771 908 Customer Assistance
772 CUST S 7.089.335 5.622.341 1.466.994 18.741 1.485.734
773 CUST eN 2.537.065 2.438.657 98.408 5.849 104,257
774
775
776 62 9.626,400 8.060.998 1.565.402 24.589 1.589.991
777
.
REVISED PROTOCOL Page 2.13
Beginning/Ending
FERC BUS t.UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
778 909 Informational & Instructional Adv.CUST 5 127.723 127.670 53 3.165 3.218
CUST CN 3.973.866 3.819.727 154.139 (18.583)135.556
62 4.101.589 3.947.397 154,192 (15,418)138.774
782
783 910 Misc. Customer Service
784 CUST S
785 CUST CN 63.857 61.380 2,477 2,477
786
787 62 63.857 61.380 2.477 2,477
788
789 Total Customer Service Expense B2 14.039.833 12.308.144 1,731.689 9.171 1.740.860
790
791
792 Summary of Customer Service Exp by Factor
793 S 7.217.058 5.750.011 1.467.046 21.906 1.488.952
794 CN 6.822.775 6.558.132 264.643 (12.735)251.908
795
796 Total Customer Service Expense by Factor 62 14.039.833 12.308.144 1.731.689 9.171 1.740.860
797
798
799 911 Supervision
800 CUST 5
801 CUST CN
802 62
803
804 912 Demonstration & Sellng Expense
805 CUST 5
806 CUST CN
807 B2
808
809 913 Advertising Expense
810 CUST 5
811 CUST CN
812 62
813.916 Misc. Sales Expense
CUST 5
CUST CN
817 B2
818
819 Total Sales Expense 62
820
821
822 Total Sales Expense by Factor
823 S
824 CN
825 Total Sales Expense by Factor
826
827 Totl Customer Service Exp Including Sales B2 14.039.833 12.308.144 1,731.689 9,171 1.740.860
828 920 Administrative & General Salaries
829 PTD S 1.567.043 3.295.617 (1.728.574)2.370.439 641.864
830 CU5T CN
831 PTD SO 65.633.747 61.951.277 3.682.470 496.868 4.179.338
832 82 67.200.789 65.246.894 1.953.895 2.867.307 4.821.203
833
834 921 Offce Supplies & expenses
835 PTD 5 (1.003.755)(1.003.905)150 150
836 CUST CN
837 PTD SO 12.474.744 11.774.831 699.912 (5.447)694,465
838 82 11,470.988 10.770.926 700.062 (5.447)694,615
83984 922 A&G Expenses Transferred
841 PTD S
842 CUST CN
843 PTD SO (21.538.493)(20.330.046)(1.208.446)(1,208.446)
844 62 (21.538,493)(20.330,046)(1.208.446)(1.208,446)
84
.
REVISED PROTOCOL Page 2.14
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
846 923 Outside Services.PTD S 2.442 2.442
CUST CN
PTD SO 11.888.434 11.221.417 667.017 (13.203)653.814
850 62 11.890.876 11.223.859 667.017 (13.203)653.814
851
852 924 Property Insurance
853 PTD SO 31.882.383 30.093,579 1.788.804 1.788.804
854 62 31.882.383 30.093.579 1.788.804 1.788.804
855
856 925 Injunes & Damages
857 PTD SO 9.475.122 8.943.507 531.614 28.310 559.924
858 62 9,475.122 8.943.507 531.614 28.310 559.924
859
860 926 Employee Pensions & 6enefits
861 LABOR S
862 CUST CN
863 LABOR 50
864 B2
865
866 927 Franchise Requirements
867 DM5C 5
868 DM5C 50
869 B2
870
871 928 Regulatory Commission Expense
872 DMSC S 9.727.505 9.294.502 433.003 (11.285)421.718
873 CUST CN
874 DMSC SO 2.819 2.661 158 158
875 FERC SG 1.899.938 1.789.609 110.329 110.329
876 B2 11.630.262 11.086.771 543,491 (11.285)532.206
877
878 929 Duplicate Charges
879 LABOR 5
880 LABOR SO (3.987.182)(3.763,476)(223.706)(223.706)
881 62 (3.987.182)(3.763.476)(223.706)(223,706).930 Misc General Expenses
PTO 5 5.465.839 5.459.839 6,00 (44.549)(438.549)
885 CU5T CN 4.500 4.325 175 175
886 LABOR 50 13.105.319 12.370.027 735.292 790.365 1.525.657
887 B2 18.575.658 17.834.191 741.466 345.817 1.087.283
888
889 931 Rents
890 PTO 5 934.44 934.443
891 PTO SO 5.384.260 5.082.169 302.091 (1.052)301.039
892 B2 6.318.703 6.016.612 302.091 (1.052)301.039
893
894 935 Maintenance of General Plant
895 G 5 23.039 23.039
896 CU5T CN
897 G SO 27.101.992 25.581.398 1.520.594 1.520.594
898 B2 27.125.031 25.604.437 1.520.594 1.520.594
89990 Total Administrative & General Expense B2 170,044.138 162,727,255 7,316,882 3,210.447 10.527.329
901
902 Summary of A&G Expense by Factor
903 5 16.716.555 18.005.977 (1.289,421 )1.914.605 625.184
904 SO 151,423.144 142.927.344 8.495.799 1.295.842 9.791.641
905 SG 1.899.938 1.789.609 110.329 110.329
906 CN 4.500 4.325 175 175
907 Total A&G Expense by Factor 170.044.138 162.72.255 7.316.882 3.210.441 10.527.329
908
909 Total O&M Expense B2 2,927.990.614 2,749.994,128 17,99.486 13.977.646 191,974.13
.
REVISED PROTOCOL Page 2.15
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DE SCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
910 403SP Steam Depreciation.P 5G 23,444.765 22.083.327 1.361,438 1.361.438
P 5G 26.153.806 24.635,055 1.518.752 1.518.752
P 5G 48.167.206 45.370.136 2.797.070 117.388 2.914.458
914 P 55GCH 7.258.124 6.847.132 410.992 59.720 470.713
915 83 105.023.901 98.935,650 6.088.251 177.109 6.265.360
916
917 403NP Nuclear Depreciation
918 P 5G
919 83
920
921 403HP Hydro Depreciation
922 P 5G 3.842.758 3.619.609 223.149 223.149
923 P SG 1.032.617 972.652 59.964 59.964
924 P SG 7.010.380 6.603.287 407.093 31.235 438.327
925 P SG 3.092.147 2.912.586 179,561 9.883 189.444
926 83 14.977.901 14.108.135 869.767 41.118 910.884
927
926 4030P Other Production Depreciation
929 P SG 125.965 116.651 7.315 7.315
930 P SG 51.340.909 48.359.542 2.981,367 2.419.739 5.401.106
931 P SSGCT 2.521.119 2.365.313 155.806 155.806
932 P SSGCH
933 83 53.987.993 50.843.506 3.144.487 2.419.739 5.564.227
934
935 403TP TransmiSsion Depreciation
936 T SG 11.375.581 10.715.001 660.580 660.580
931 T SG 12.624:038 11.890.960 733.078 733.078
938 T SG 34.235.508 32.247,452 1.988.056 190.822 2.178.878
939 83 58.235.127 54.853,413 3.381.714 190.822 3.572.536
940
941
942
943 403 Distribution Depreciation
944 360 Lend & Land Rig"" DPW S 276.131 261.874 16.257 16.257
945 361 sir DPW S 906.304 893.399 12.904 12.904
4 362 Stl;o Equpmi DPW S 16.347.160 15.728.098 619.062 619.062
363 _ogB8ltyE..DPW S 91.113 91.113
364 Pol.. & Tower DPW S 32.093.095 30.172.791 1.920.304 1.920.304
365 OH Coctrs DPW S 18.328.255 17.390.184 938.072 938.072
950 366 UGCondl DPW S 7.213.537 7.062.392 151.145 151.145
951 367 UG Conr DPW S 16.692.267 16.233.432 458.835 458.835
952 368 Line Tra DPW 5 25.531.690 24.172.626 1.359.064 1.359.064
953 369 Serce DPW 5 10.936.723 10.448.593 488.130 488.130
954 370 Meter DPW S 6,445.250 6.003.031 442.219 442.219
955 371 Ins CUlt Prem DPW S 497.587 490.081 7.505 7.505
956 372 Le Propey DPW 5 162 146 16 16
957 373 Sl80Ligng DPW 5 2.192.792 2.164.319 28.474 28,474
958 83 137.554.066 131.112.080 6.441.986 6.441.986
959
96 403GP Genera! Depreciation
961 G-SITUS S 13.352.607 12.521.151 831.456 7.336 838.192
962 PT SG 573.517 540.213 33.304 33.304
963 PT SG 1.211.376 1.141.032 70.345 70.345
964 P SE 34.771 32.528 2.242 2.242
965 CUST CN 1.549.132 1.489.044 60.088 574 60.662
966 G-SG SG 4.889.513 4.605.579 283.934 707 284.641
967 PTD SO 16.468.319 15.544.342 923.977 8.794 932.772
966 G-SG SSGCT 8.619 8.087 533 (374)159
969 G-SG 5SGCH 172.600 162.827 9.774 9.774
970 83 38.260,455 36.044.803 2.215.652 17.037 2.232.689
971
972 403GVO General Vehicles
973 G-SG SG
974 83
975
976 403MP Mining Depreciation
977 P SE 2.848 2.846
976 83 2.848 2.848
979.
REVISED PROTOCOL Page 2.16
BeginningfEnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
980 403EP Experimental Plant Depreciation.P SG
P SG
63
984 4031 ARO Depreciation
985 P S
986 63
987
988
989 Total Depreciation Expense 63 408.039.44 385.897.586 22.141.858 2,848.672 24,990.530
990
991 Summary S 150.906.673 143.633.232 7.273,442 7.336 7.280.777
992 DGP
993 DGU
994 SG 229.120.086 215.815.082 13.305.004 2.769.774 16.074.778
995 SO 16.468.319 15.544.342 923.977 8.794 932.772
996 CN 1.549.132 1.489.044 60.088 574 60.662
997 SE 34.771 32.528 2.242 2.848 5.091
998 SSGCH 7.430.725 7.009.959 420.766 59.720 480.486
999 SSGCT 2.529.738 2.373.400 156.338 (374)155.964
1000 Total Depreciation Expense 6y Factor 408.039.444 385.897.586 22.141.858 2.848.672 24.990.530
1001
1002 404GP Amort of L T Plant - Capital Lease Gen
1003 I-SITUS S 1.220.394 1.220.394
1004 I-5G SG
1005 PTD SO 1.097.914 1.036.314 61.600 61.600
1006 P SG
1007 CUST CN 234.320 225.231 9,089 9.089
1008 P SG
1009 64 2.552.628 2,481.939 70.689 70.689
1010
1011 404SP Amort of L T Plant - Cap Lease Steam
1012 P SG
1013 P SG
1014 64
1015.!4041P Amort of L T Plant - Intangible Plant
1-5ITUS S 71.714 45.542 26.171 26.171
P SE 10.380 9.710 669 669
1019 I-5G SG 8.136.385 7.663.905 472.480 12.750 485.230
1020 PTD SO 21.539.117 20.330.636 1.208,481 15.729 1.224.210
1021 CUST CN 5.843.372 5.616.719 226.654 226.654
1022 I-5G SG 2.073.941 1.953.507 120,434 191.821 312.255
1023 I.SG SG 309.688 291.704 17.984 17.984
1024 P SG
1025 I-5G SSGCT
1026 I-5G SSGCH 21.850 20.613 1.237 1.237
1027 P SG 16.678 15.709 968 968
1028 64 38.023.124 35.948.046 2.075.078 220.300 2.295.379
1029
1030 404MP Amort.of L TPlant - Mining Plant
1031 P SE
1032 64
1033
1034 4040P Amort of L T Plant - Other Plant
1035 P SSGCT 115.060 107.949 7.111 (7,111 )0
1036 64 115.060 107.949 7.111 (7.111 )0
1037
1038
1039 404HP Amortization of Other Electric Plant
1040 P SG 2.279 2.147 132 132
1041 P SG 39.066 36.797 2.269 2.269
1042 P SG
1043 64 41.345 38.944 2.401 2.401
1044
1045 Total Amortzation of Limited Term Plant B4 40.732.157 38,576,878 2,155.279 213,189 2,368.468
1046
1047
1048 405 Amortization of Other Electric Plant
1049 GP S
1050
~~
B4
REVISED PROTOCOL Page 2.17
BeginninglEnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref .TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
C 406 Amortization of Plant Acquisition Adj
P S
P 5G
056 P 5G
1057 P 5G 5,79.353 5.161.167 318.186 318.186
1058 P 50 -
1059 B4 5,479.353 5.161.167 318.186 318.186
1060 407 Amort of Prop Losses. Unrec Plant. etc
1061 DPW 5 5.175.354 5.175.354
1062 GP 50
1063 P 5G-P 3.437.028 3.237,440 199.588 (199.588)0
1064 P 5E
1065 P 5G 305.346 287.615 17.731 17.731
1066 P TROJP 2.013.725 1.894.824 118.902 118.902
1067 B4 10.931.454 10.595.233 336.221 (199.588)136.633
1068
1069 Total Amortization Expense B4 57.142.964 54.333.277 2,809.686 13,601 2,823.287
1070
1071
1072
1073 5ummary of Amortization Expense by Factor
1074 5 6.467.462 6,441.291 26.171 26.171
1075 5E 10.380 9.710 669 669
1076 TROJP 2.013.725 1.894.824 118.902 118,902
1077 DGP
1078 DGU
1079 50 22.637.031 21.366.950 1.270.081 15.729 1.285.810
1080 55GCT 115.060 107.949 7.111 (7.111 )0
1081 55GCH 21.850 20.613 1.237 1.237
1082 5G.P 3.437.028 3.237,440 199.588 (199.588)0
1083 CN 6.077.693 5.841.950 235.742 235.742
1084 5G 16.362.735 15,412.551 950.184 20.571 1.154.755
1085 Total Amortization Expense by Factor 57,14.964 54.333.277 2.809.686 13.61 2.823.287
1086 408 Taxes Other Than Income
1087 DMSC 5 25.128.171 25.128.171
1088 GP GP5 77.529.279 73.179.395 4.349.885 507.354 4.857.239
.~GP 50 8.932.612 8.431.436 501.176 501.176
P 5E 834.427 780.613 53.814 53.814
P 5G
1092 DM5C OPRV-ID
1093 GP EXCTAX
109 GP 5G
1095
1096
1097
1098 Total Taxes Other Than Income B5 112.424.490 107.519.615 4,904.875 507.354 5.412.229
1099
1100
1101 41140 Deferred Investment Tax Credit - Fed
1102 PTD DGU (1.874.204)(1.654,465)(219.739)(219.739)
1103
1104 B7 (1.874.204)(1.654,465)(219,739)(219.739)
1105
1106 41141 Deferred Investment Tax Credit. Idaho
1107 PTD DGU
1108
1109 B7
1110
1111 Total Deferred ITC B7 (1,874.204)(1,654.465)(219,739)(219.739)
1112
.
REVISED PROTOCOL Page 2.18
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DE SCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
ll'11:
427 Interest on Long- Term Debt
GP 5 1.527.746 1.527.746
GP 5NP 313.572.989 296.309.850 17.263.139 17.263.139
1117 B6 313.572.989 296.309.850 17.263.139 1.527.746 18.790,885
1118
1119 428 Amortization of Debt Disc & Exp
1120 GP 5NP 7.295.949 6.894.285 401.664 401.664
1121 B6 7.295.949 6.894.285 401.664 401.664
1122
1123 429 Amortization of Premium on Debt
1124 GP 5NP (2.718)(2.569)(150)(150)
1125 B6 (2.718)(2.569)(150)(150)
1126
1127 431 Other Interest Expense
1128 NUTIL OTH
1129 GP SO
1130 GP 5NP 14.625.063 13.819.909 805.154 805,154
1131 B6 14.625.063 13.819.909 805.154 805.154
1132
1133 432 AFUDC . Borrowed
1134 GP 5NP (34.280.545)(32.393.297)(1.887.247)(1.887.247)
1135 (34.280,545)(32.393.297)(1.887.247)(1.887.247)
1136
1137 Total Elec. Interest Deductions for Tax B6 301.210.738 284.628.177 16.582.560 1,527.746 18.110.306
1138
1139 Non-Utility Portion of Interest
1140 427 NUTIL NUTIL
1141 428 NUTIL NUTIL
1142 429 NUTIL NUTIL
1143 431 NUTIL NUTIL
1144
1145 Total Non-utilty Interest
1146
1147 Total Interest Deductions for Tax B6 301.210.738 284.628,177 16.582.560 1.521.746 18.110.306
1148.419 Interest & Dividends
GP 5
1152 GP SNP
146.616.392)144.050.019)
(2.566.373)(2.566.373)
1153 Total Operating Deductions for Tax B6 ~6.616.392)44.050.019)(2.566.373)(2.566.373)
1154
1155
1156 41010 Deferred Income Tax - Federal-DR
1157 GP S 518.758.661 490.992.868 27.765.794 (27.645.563)120.231
1158 P TROJD
1159 PT DGP 368 368
1160 LABOR SO 33,483.751 31.605.100 1.878.651 (928.471)950.180
1161 GP SNP 1.554.611 1.554.611
1162 P 5E 14.696.870 13.749.032 947.838 194.456 1.142.295
1163 PT SG 11.550.960 10.880.196 670.764 9,416.263 10.087.028
1164 GP GPS 70.380 66.431 3.949 1.734.876 1.738.825
1165 TAXEPR TAXEPR 24.453.431 24.453.431
1166 P SSGCH (1.361)(1.361)
1167 CUST CN 23.817 22.893 924 (218)706
1168 P IBT 214.379 244.037 (29.658)29.658 (0)
1169 DPW SNPD 85.117 81.148 3.968 3.968
1170 B7 578.884.303 547.642.073 31.242.230 8.807.683 40.049.913
1171
.
REVISED PROTOCOL Page 2.19
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1172.41110 Deferred Income Tax - Federal-CR
GP S (271.085.647)(257.386.834)(13.698.813)12.893,414 (805.399)
1176 P SE (13.365.892)( 12.503.892)(862.000)(30.844)(892.844)
1177 P SSGCH 23.942 23.942
1178 GP SNP (1.602.752)(1.514.516)(88.236)(1.274.786)(1.363.023)
1179 PT SG (3.849.639)(3.626.091 )(223.549)309.482 85.934
1180 DPW CIAC (1.154.455)(1,154.455)
1181 LABOR SO (26.337.587)(24.859.881 )(1,477.706)1.216.879 (260.827)
1182 PT SNPD (38.860)(38.860)
1183 CUST BADDEBT (334.769)(327.837)(6.932)(6.932)
1184 P SGCT (356.220)(335.455)(20.766)(20.766)
1185 BOOKDEPR SCHMDEXP (9.991.873)(9.991.873)
1186 P TROJD (555.830)(522.915)(32.915)(32.915)
1187 P IBT (291.290)(331.589)40.299 (40.299)0
1188
1189
1190 B7 (317.779.627)(301.409.010)(16.370.617)1.912.599 (14.458.018)
1191
1192 Total Deferred Income Taxes B7 261.104.676 246.233.063 14.871.613 10.720.282 25.591.895
1193 SCHMAF Additions - Flow Through
1194 SCHMAF S
1195 SCHMAF SNP
1196 SCHMAF SO
1197 SCHMAF SE
1198 SCHMAF TROJP
1199 SCHMAF SG
1200 B6
1201
1202 SCHMAP Additions - Permanent
1203 P S
1204 P SE 84.185 78.756 5.429 5,429
1205 LABOR SNP
1206 SCHMAP-SO SO 9.298.119 8.776,436 521.683 521.683
1207 SCHMAP SG.DPW BADDEBT
B6 9.382.305 8.855.192 527.113 527.113
1211 SCHMAT Additions - Temporary
1212 SCHMA T .SITUS S 81.206.348 80,412.557 793.791 7.336 801.127
1213 P SSGCH (3.366)(3.366)
1214 DPW CIAC 65.247.545 62.205.584 3.041.962 3.041.962
1215 SCHMAT-SNP SNP 65.237.720 61.646.186 3.591.533 3.591.533
1216 P TROJD 1.464.600 1.377.869 86.731 86.731
1217 P SGCT 54.717 54.717
1218 SCHMAT-SE SE 31.701.999 29.657.457 2.044.542 310.930 2.355.472
1219 P SG 3.959.859 3.729.910 229.949 2.265.235 2.495.184
1220 CUST CN 574 574
1221 SCHMAT-SO SO 12.249,451 11.562.179 687.272 24.523 711.795
1222 SCHMAT-SNP SNPD 2.196.309 2.093.913 102.396 102.396
1223 DPW BADDEBT 882.108 863.843 18.265 18.265
1224 P SSGCT 938.632 880.625 58.08 (58.008)(0)
1225 BOOKDEPR SCHMDEXP 485.189.989 458.861.634 26.328.356 26.328.356
1226 B6 750.274.561 713.291.757 36.982.804 2.601.941 39.584,745
1227
1228 TOTAL SCHEDULE - M ADDITONS B6 759.656.866 722.146.949 37.509.917 2.601.941 40.111,858
1229
.
REVISED PROTOCOL Page 2.20
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1230 SCHMDF Deductions. Flow Through.SCHMDF S
SCHMDF DGP
SCHMDF DGU
1234 S6
1235 SCHMDP Deductions. Penn anent
1236 SCHMDP S
1237 P SE 2.592.202 2.425.024 167.178 167.178
1238 PTD SNP 381.063 360.084 20.979 20.979
1239 SCHMDP 1ST
1240 P SG (0)(0)(0)(0)
1241 SCHMDP.SO SO 12.093.788 11.415.250 678.538 678.538
1242 S6 15.067,053 14.200.358 866.695 866.695
1243
1244 SCHMDT Deductions. Temporary
1245 GP S 62.893.744 62.385.765 507.978 (809.956)(301.978)
1246 DPW SADDEST
1247 SCHMDT-5NP SNP 74.407.631 70.311.266 4.096.365 4.096.365
1248 SCHMDT CN 62.756 60.322 2.434 2,434
1249 SCHMDT SSGCH 56.133 56.133
1250 CUST DGP 970 970
1251 P SE 45.523.602 42.587.670 2.935.932 76.836 3.012.768
1252 SCHMDT.SG SG 18.480.740 17.407.564 1.073.177 28.321.668 29.394.845
1253 SCHMDT.GPS GPS 81.662.106 77.080.343 4.581.762 4.581.762
1254 SCHMDT-SO SO 53.669.546 50.658.344 3.011.202 (482.977)2.528.225
1255 TAXEPR TAXDEPR 1.095.617.890 1.031.183.670 64,434.220 64,434.220
1256 DPW SNPD 224.280 213.824 10,456 10,456
1257 S6 1.432.543.265 1.351.889.738 80.653.527 27.161.704 107.815.231
1258
1259 TOTAL SCHEDULE. M DEDUCTIONS S6 1.447.610,318 1.366.090.096 81.520.221 27.161.704 108,681.925
1260
1261 TOTAL SCHEDULE. M ADJUSTMENTS B6 (687.953.452)(643,94.148)(44.010.304)(24.559.763)(68.570.068)
1262
1263
1264
1265 40911 State Income Taxes41ST 1ST 1.883.876 2.144.502 (260.626)(1.299.238)(1.559.864)
1ST SE
REC P SG (33.980)(33.980)
1ST 1ST
1270 Total State Tax Expense 1.883.876 2,144.502 (260.626)(1,333.218)(1.593.844)
1271
1272
1273 Calculation of Taxable Income:
1274 Operating Revenues 4,494.585.986 4.239.008.989 255.576.997 14.850.502 270,427.499
1275 Operating Deductions:
1276 o & M Expenses 2.927.990.614 2.749.994.128 177.996.486 13.977.646 191.974.132
1277 Depreciation Expense 408.039.44 385.897.586 22.141.858 2.84.672 24.990.530
1278 Amortization Expense 57.142.964 54.333.277 2.809.686 13.601 2.823.287
1279 Taxes Other Than Income 112,424.490 107.519.615 4.904.875 507.354 5.412.229
1280 Interest & Dividends (AFUDC-Equity)(46.616.392)(44.050.019)(2.566.373)(2.566.373)
1281 Misc Revenue & Expense (7.004.252)(6.585.071 )(419.181)33.293 (385.889)
1282 Total Operating Deductions 3,451.976.867 3.247.109.517 204.867.351 17.380.566 222.247.917
1283 Other Deductions:
1284 Interest Deuctions 301.210.738 284.628.177 16.582.560 1.527.746 18.110.306
1285 Interest on PCRSS
1286 Schedule M Adjustments (687.953.452)(643.943.148)(44.010.304)(24.559.763)(68.570.068)
1287
1288 Income Sefore State Taxes 53.44.929 63.328.147 (9.883.218)(28.617.573)(38.500.791)
1289
1290 State Income Taxes 1.883.876 2.144.502 (260.626)(1.333.218)(1.593.844)
1291
1292 Total Taxable Income 51.561,053 61.183.645 (9.622.592)(27.284.355 )(36.906.947)
1293
1294 Tax Rate 35.0%35.0%35.0%35.0%35.0%
1295
129 Federal Incme Tax. Calculated 18.046.369 21,414.276 (3.367.907)(9.549.524)(12.917,431 )
1297
1298 Adjustments to Calculated Tax:
1299 40910 PMI P SE
1300 40910 REC P SG (3.060.226)(3.060.226)
1301 40910 P SO.40910 IRS sell.LASOR S
Federal Income Tax Expense 18.046.369 21,414.276 (3,367,907)(12.609,750)(15.971.657)
1305 Total Operating Expenses 3,777.753.976 3.559,296,911 218.457,064 14,157.880 232.614.944
REVISED PROTOCOL Page 2.21
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1306 310 Land and Land Rights.P SG 2.329.517 2.194.242 135.275 135.275
P SG 34.798.44 32.777.700 2.020.746 2.020.746
P SG 54.572.394 51,403.375 3.169.019 3.169.019
1310 P S
1311 P SSGCH 1.830.732 1.727.067 103.665 103.665
1312 B8 93.531.089 88.102.384 5,428.705 5,428.705
1313
1314 311 Structures and Improvements
1315 P SG 234.971.513 221.326.717 13.644.796 13.644.796
1316 P SG 327.274.883 308.270.030 19.004.853 19.004,853
1317 P SG 193.191.542 181.972.909 11.218.633 11.218.633
1318 P SSGCH 54.198.086 51.129.111 3.068.975 3.068.975
1319 B8 809.636.024 762.698.766 46.937.258 46.937.258
1320
1321 312 Boiler Plant Equipment
1322 P SG 722.926.960 680.946.589 41.980.371 41,980.371
1323 P SG 666.159.969 627,476.058 38.683.911 38.683.911
1324 P SG 1.248.663,407 1.176.153.519 72.509.888 5.007.342 77.517.230
1325 P SSGCH 272.747.792 257.303.408 15,444.384 5.014.507 20.458.891
1326 B8 2.910,498.128 2.741.879.574 168.618.554 10.021.849 178.640,403
1327
1328 314 Turbgenerator Units
1329 P SG 145,478.089 137,030.176 8.447.913 8.447.913
1330 P SG 144.735.461 136.330.672 8.404.789 8.404.789
1331 P SG 430.173.624 405.193.441 24.980.184 24.980.184
1332 P SSGCH 59.113.516 55.766.204 3.347.312 3.347.312
1333 B8 779.500.690 734.320,493 45.180.197 45.180.197
1334
1335 315 Accessory Electric Equipment
1336 P SG 88.074.089 82.959.626 5.114.463 5.114.463
1337 P SG 139.182.485 131.100.158 8,82.327 8.082.327
1338 P SG 69.328,410 65.302.509 4.025.901 4.025.901
1339 P SSGCH 55.948.683 52.780.580 3.168.102 3.168,102
1340 B8 352.533.666 332.142.872 20.390.793 20.390.793
1341.316 Misc Power Plant Equipment
1345 P SG 4.917.199 4.631.657 285.542 285.542
1346 P SG 5.311.573 5.03.130 308.443 308.443
1347 P SG 12.798.588 12.055.374 743.214 743.214
1348 P SSGCH 3.153.831 2.975.244 178.586 178.586
1349 B8 26.181.190 24.665,405 1.515.785 1.515.785
1350
1351 317 Steam Plant ARO
1352 P S
1353 88
1354
1355 SP Unclassified Steam Plant - Account 300
1356 P SG 3.141.303 2.958.888 182.415 182,415
1357 88 3.141.303 2.958.888 182.415 182,415
1358
1359
1360 Total Steam Production Plant 88 4.975.022.090 4,686.768,382 288.253,708 10.021,49 298.275.557
1361
1362
1363 Summary of Steam Production Plant by Factor
1364 S
1365 DGP
1366 DGU
1367 SG 4.528.029.451 4.265.086.767 262.942.684 5.007.342 267.950,026
1368 SSGCH 446.992.639 421.681.615 25.311.024 5.014.507 30.325.531
1369 Total Steam Production Plant by Factor 4.1i75.022.o9õ 4,86.768.382 288.253.708 10.021.849 298.275.557
1370 320 Land and Land Rights
1371 P SG
1372 P SG
1373 88
1374
1375 321 Strctures and Improvements
1376 P SG
.~P SG 88
REVISED PROTOCOL Page 2.22
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1379.!322 Reactor Plant Equipment
P SG
P SG
1383 88
1384
1385 323 Turbgenerator Units
'1386 p SG
1387 P SG
1388 88
1389
1390 324 Land and Land Rights
1391 P SG
1392 P SG
1393 88
1394
1395 325 Misc. Power Plant Equipment
1396 P SG
1397 P SG
1398 88
1399
1400
1401 NP UnclasSified Nuclear Plant - Acct 300
1402 P SG
1403 88
1404
1405
1406 Total Nuclear Production Plant B8
1407
1408
1409
1410 Summary of Nuclear Production Plant by Factor
1411 DGP
1412 DGU
1413 SG
1414.Total Nuclear Plant by Factor
330 Land and Land Rights
1418 P SG 10.626.875 10.009.773 617.103 617.103
1419 P SG 5.307.562 4.999.351 308.210 308.210
1420 P SG 3.122.555 2.941.228 181.327 181.327
1421 P SG 635.700 598.785 36.915 36,15
1422 88 19.692.691 18.549.136 1.143.555 1.143.555
1423
1424 331 Strctures and Improvements
1425 P SG 21.453.996 20.208.163 1.245.834 1.245.834
1426 P SG 5.321.263 5.012.257 309.006 309.006
1427 P SG 51.364.477 48.381.742 2.982.735 2.982.735
1428 P SG 7.247.543 6.826.678 420.865 420.865
1429 88 85.387.280 80.428.840 4.958,440 4.958.440
1430
1431 332 Reservoirs. Dams & Waterways
1432 P SG 151.599.706 142.796.310 8.803,395 8.803.395
1433 P SG 20.314.745 19.135.068 1.179.677 1.179.677
1434 P SG 81.431.400 76.702.678 4.728.722 1.433.757 6.162.478
1435 P SG 34.719,453 32.703.294 2.016.159 362.032 2.378.191
1436 88 288.065.303 271.337.350 16.727.953 1.795.789 18.523.742
1437
1438 333 Water Wheel. Turbines. & Generators
1439 P SG 32.865.646 30.957.138 1.908.508 1.908.508
144 P SG 9.119.942 8.590.347 529.595 529.595
1441 P SG 35.766.382 33.689,428 2.076.954 2.076.954
1442 P SG 18.966.583 17.865.194 1.101.390 1.101.390
1443 88 96.718.553 91.102.107 5.616,447 5.616.447
1444
1445 334 Accessory Electric Equipment
1446 P SG 4.884.346 4.600.712 283.634 283.634
1447 P SG 3.929.298 3.701.123 228.174 228.174
144 P SG 34.265.028 32.275.257 1.989.770 1.989.770
1449 P SG 4.595.701 4.328.828 266.872 266.872
.~88 47.674.372 44.905.921 2.768,451 2.768,451
REVISED PROTOCOL Page 2.23
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTALIi335Misc. Power Plant Equipment
455 P SG 1.272.609 1.198.709 73.900 73.900
1456 P SG 196.141 184.751 11.390 11.390
1457 P SG 988.829 931.407 57,421 57,421
1458 P SG 13.718 12.922 797 797
1459 B8 2.471.296 2.327.788 143.508 143.508
1460
1461 336 Roads. Railroads & Bridges
1462 P SG 4.663.151 4.392.362 270.789 270.789
1463 P SG 828.976 780.837 48.139 48.139
1464 P SG 8.179.286 7,704.315 474.971 474.971
1465 P SG 608,436 573.104 35.332 35.332
1466 B8 14.279.848 13.450.617 829.231 829,231
1467
1468 337 Hydro Plant ARO
1469 P S
1470 B8
1471
1472 HP Unclassified Hydro Plant - Acct 300
1473 P S
1474 P SG
1475 P SG
1476 P SG
1477 B8
1478
1479 Total Hydraulic Production Plant B8 554,289.344 522.101.760 32.187.584 1.795,789 33.983.373
1480
1481 Summary of Hydraulic Plant by Factor
1482 S
1483 SG 554.289.344 522.101.760 32.187.584 1.795.789 33.983.373
1484 DGP
1485 DGU
148 Total Hydraulic Plant by Factor 554.289.344 522.101.760 32.187.584 1,795.789 33.983.373
1487.340 Land and Land Rights
P SG 21.542.794 20.291.803 1.250.990 1.250.990
P SG
1491 P SSGCT
1492 B8 21.542.794 20.291.803 1.250.990 1.250.990
1493
1494 341 Structures and Improvements
1495 P SG 105.937.740 99.785.935 6.151.805 6.151.805
1496 P SG 168.512 158.727 9.786 9.786
1497 P SSGCT 4.179.820 3.921.506 258.314 258.314
1498 B8 110.286.072 103.866,168 6,419.904 6.419.904
1499
1500 342 Fuel Holders. Proucers & Accessories
1501 P SG 6.693.078 6.304,411 388.667 38.667
1502 P SG 121.339 114.293 7.046 7.046
1503 P SSGCT 2.270.875 2.130.535 140.341 140.341
1504 B8 9.085.292 8.549.238 536.054 536.054
1505
1506 343 Prime Movers
1507 P S
1508 P SG 773.304 728.398 44.906 44.906
1509 P SG 1.211.613.127 1.141.254.749 70.358.378 50.872.523 121.230.901
1510 P SSGCT 51.085.812 47.928.695 3.157.117 (32.786)3.124.331
1511 B8 1.263,472,242 1.189.911.842 73.560.400 50.839.737 124.400.137
1512
1513 344 Generators
1514 P S
1515 P SG
1516 P SG 213.416.293 201.023.208 12.393.085 12.393.085
1517 P SSGCT 15.873.643 14.892.648 980.995 980.995
1518 B8 229.289.936 215.915.856 13.374.080 13.374.080
.
REVISED PROTOCOL Page 2.24
BeginninglEnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT AOJTOTAL
1519.!345 Accessory Electric Plant
P SG 122,290.594 115,189,179 7,101,415 7,101,415
P SG 156,586 147.493 9,093 9,093
1523 P SSGCT 3,012,036 2,825.891 186,145 186,145
1524 88 125,459,216 118,162,563 7,296,653 7,296,653
1525
1526
1527
1528 346 Misc. Power Plant Equipment
1529 P SG 6,912,640 6,511,223 401,417 401,417
1530 P SG 11,813 11,127 686 686
1531 88 6,924,453 6,522,350 402,103 402.103
1532
1533 347 Other Production ARO
1534 P S
1535 88
1536
1537 OP Unclassified Other Prod Plant-Acct 300
1538 P S
1539 P SG 151,409,535 142,617,183 8,792,352 8,792.352
1540 151,409,535 142,617.183 8.792,352 8,792.352
1541
1542 Total Other Production Plant B8 1,917.469,540 1,805,837,003 111,632,537 50,839,737 162,472.274
1543
1544 Summary of Other Production Plant by Factor
1545 S
1546 DGU
1547 SG 1,841.047,354 1,734,137,728 106,909,625 50,872,523 157.782,148
1548 SSGCT 76,422,186 71,699,275 4,722,911 (32,786)4,690,126
1549 Total of Other Production Plant by Factor 1,917 ,469,540 1,805,837,003 111,632.537 50.839,737 162,472,274
1550
1551 Experimental Plant
1552 103 Experimental Plant
1553 P SG
1554 Total Experimental Production Plant B8.Total Production Plant B8 7,44,780,973 7,014,707,145 432,073,829 62.657,375 494,731,203
350 Land and Land Rights
1558 T SG 21,194,069 19.963,330 1,230,740 1,230.740
1559 T SG 48,573.482 45,752,820 2.820,662 2,820,662
1560 T SG 24,582,184 23,154,696 1,427,487 (44,192)1,383,295
1561 88 94,349.735 88.870,845 5,478,889 (44,192)5,34,697
1562
1563 352 Structures and Improvements
1564 T S
1565 T SG 7,694,937 7,248,092 44,845 446,845
1566 T SG 18,309,921 17,246,664 1.063,257 1,063,257
1567 T SG 41,188,064 38,796,273 2,391,791 2,391,791
1568 88 67,192,922 63,291,029 3,901,893 3,901,893
1569
1570 353 Station Equipment
1571 T SG 133,265,659 125,526,922 7,738,737 7,738,737
1572 T SG 193,113,579 181,899,473 11,214.106 11,214,106
1573 T SG 761,485,009 717,265,572 44,219,437 44,219,437
1574 88 1,087,864,247 1,024,691,967 63,172,280 63,172,280
1575
1576 354 Towers and Fixtures
1577 T SG 156,331,416 147,253,250 9,078,166 9,078,166
1578 T SG 126.710,44 119.352,372 7,358,076 7,358.076
1579 T SG 144,434,707 136.047,383 8,387,324 8,387,324
1580 88 427,476.570 402,653.005 24,823,566 24,823,566
1581
1582 355 Poles and Fixtures
1583 T SG 67,678,61 63,747,996 3,930,065 3,930,065
1584 T SG 118,054,192 111,198,785 6,855,407 6,855,07
1585 T SG 347,528,690 327,347,698 20,180,992 9,409,904 29,590,896
1586 88 533,260,943 502,294,478 30,966,465 9,409,904 40,376,368
1587.
REVISED PROTOCOL Page 2.25
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DE SCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1588 356 Clearing and Grading.T SG 202,398,474 190,645,194 11,753,280 11,753,280
T SG 158,329,552 149,135,355 9,194,198 9,194,198
T SG 345,441,828 325,382,020 20,059.808 20,059,808
1592 68 706,169,854 665.162,568 41,007,286 41,007,286
1593
1594 357 Underground Conduit
1595 T SG 6,371 6,001 370 370
1596 T SG 127.199 119,812 7,386 7,386
1597 T SG 3,110,028 2,929,428 180,599 180,599
1598 68 3,243,597 3,055,241 188,356 188,356
1599
1600 358 Underground Conductors
1601 T SG
1602 T SG 1,053,107 991.954 61,154 61,154
1603 T SG 6,374,736 6,004,555 370,181 370,181
1604 68 7,427,844 6,996,509 431,335 431,335
1605
1606 359 Roads and Trails
1607 T SG 1,876,730 1,767,748 108,982 108,982
1608 T SG 467,634 440,478 27,155 27,155
1609 T SG 9,118,473 8,588,963 529,510 529.510
1610 68 11,462,837 10,797,190 665,647 665.647
1611
1612 TP Unclassified Trans Plant. Acct 300
1613 T SG 26,145,671 24,627,392 1,518,279 1,518.279
1614 68 26,145,671 24,627,392 1,518,279 1,518.279
1615
1616 TSO Unclassified Trans Sub Plant. Acct 300
1617 T SG
1618 B8
1619
1620 Total Transmission Plant 68 2.96,594,220 2.792.440.224 172,153.995 9,365,712 181,519,707
1621 Summary of Transmission Plant by Factor
1622 DGP
1623 DGU.SG 2,964,594,220 2,792,440,224 172,153,995 9,365,712 181,519,707
Total Transmission Plant by Factor 2,964,594,220 2,792,440,224 172,153,995 9.365,712 181,519.707
360 Land and Land Rights
1627 DPW S 46,101,103 44,845,561 1,255,542 1,255,542
1628 68 46,101,103 44,845,561 1,255,542 1,255,542
1629
1630 361 Structures and Improvements
1631 DPW S 54,801.132 53,649,815 1,151,317 1.151,317
1632 68 54,801,132 53,649,815 1,151,317 1.151,317
1633
1634 362 Station Equipment
1635 DPW S 707,536,192 681,412,293 26,123,899 26.123.899
1636 B8 707,536,192 681,412.293 26,123,899 26,123.899
1637
1638 363 Storage 6attery Equipment
1639 DPW S 1,457,805 1,457,805
1640 68 1,457,805 1,457,805
1641
1642 364 Poles, Towers & Fixtures
1643 DPW S 852,220,217 796,061,097 56.159,120 56,159,120
1644 68 852,220,217 796,061,097 56,159,120 56,159,120
1645
1646 365 Overhead Conductors
1647 DPW S 610,312,712 577,339,585 32,973,127 32,973.127
1648 68 610,312.712 577,339,585 32,973,127 32,973.127
1649
.
REVISED PROTOCOL Page 2.26
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.366 Underground Conduit
DPW S 272,932,062 265,989.584 6,942,477 6,942.477
B8 272,932,062 265,989,584 6,942,477 6.942.477
53
1654
1655
1656
1657 367 Underground Conductors
1658 DPW S 657,548,834 634,906,532 22,642,301 22,642,301
1659 B8 657,548,834 634,906,532 22,642,301 22,642,301
1660
1661 368 Line Transformers
1662 DPW S 988,749.117 926,686,876 62,062.240 62.062,240
1663 68 988,749,117 926,686.876 62.062,240 62,062.240
1664
1665 369 Servces
1666 DPW S 519,158.428 493.474,609 25.683,819 25.683.819
1667 68 519,158,428 493,474,609 25,683,819 25,683.819
1668
1669 370 Meters
1670 DPW S 185,783,461 171,965,927 13,817,534 13,817.534
1671 68 185,783,461 171.965,927 13,817,534 13,817,534
1672
1673 371 Installations on Customers' Premises
1674 DPW S 8,837,226 8,674,620 162.607 162,607
1675 68 8,837,226 8,674,620 162,607 162,607
1676
1677 372 Leased Propert
1678 DPW S 24,829 22,392 2,437 2,437
1679 68 24,829 22,392 2,437 2.437
1680
1681 373 Street Lights
1682 DPW S 60,412,919 59,820.436 592.483 592,483
1683 B8 60,412,919 59,820.436 592,483 592,483
1684
1685 DP Unclassified Dist Plant - Acct 300.!DPW S 29,000,576 27,607,894 1,392,682 1.392.682
68 29,000,576 27,607,894 1,392,682 1,392.682
1689 DSO Unclassified Dist Sub Plant - Acet 300
1690 DPW S
1691 68
1692
1693
1694 Total Distribution Plant B8 4,99,876,612 4,743,915,027 250,961,585 250.961,585
1695
1696 Summary of Distribution Plant by Factor
1697 S 4,994,876,612 4.743,915,027 250,961,585 250,961,585
1698
1699 Total Distribution Plant by Factor 4,994,876,61 4,743,915,027 250,961.585 250,961,585
.
REVISED PROTOCOL Page 2.27
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT AOJ TOTAL
1700 389 Land and Land Ri9hts.G-SITU5 5 8,960,984 8,763,345 197,639 197,639
CUST CN 1,128,506 1,084,733 43,773 43,773
PT 5G 332 313 19 19
1704 G-SG SG 1,228 1,156 71 71
1705 PTO SO 5,598,055 5,283,968 314,086 314,086
1706 B8 15,689.104 15,133,516 555,588 555.588
1707
1708 390 Strctures and Improvements
1709 G-SITUS 5 107,525,675 97,785,161 9,740,514 9,740,514
1710 PT SG 358,127 337,331 20,796 20,796
1711 PT SG 1,573,572 1,482,195 91,377 91,377
1712 CUST CN 12,092,854 11,623,794 469,059 469,059
1713 G-SG SG 3,992.709 3.760,852 231,857 231,857
1714 PTD SO 102,539,957 96,786,815 5,753,142 5,753,142
1715 B8 228,082,895 211,776,149 16,306,746 16,306.746
1716
1717 391 Offce Furniture & Equipment
1718 G-ITU5 5 14,469,238 13,520,356 948,881 948,881
1719 PT 5G 146,768 138,245 8,523 8,523
1720 PT SG 151,643 142,837 8,806 8,806
1721 CUST CN 7,284,434 7,001,885 282,550 282,550
1722 G-SG 5G 4,772,077 4,494,962 277,115 277,115
1723 P SE 141,948 132,794 9,155 9,155
1724 PTD SO 65,472,287 61,798,876 3,673,411 3,673,411
1725 G-SG S5GCH 149,689 141.213 8,476 8,476
1726 G-SG 55GCT 6,733 6,317 416 416
1727 B8 92,594,817 87,377,485 5,217,332 5,217.332
1728
1729 392 Transportation Equipment
1730 G-SITUS 5 71,167,779 66.239,302 4.928,477 4,928,477
1731 PTO SO 8,302,189 7,836,383 465,805 465,805
1732 G-SG SG 15,664,860 14,755,202 909,658 909,658
1733 CUST CN
1734 PT SG 969,353 913,062 56,290 56,290
1735 P SE 704,061 658,654 45,407 45,407.!PT SG 138,132 130,110 8,021 8,021
G-SG 5SGCH 366,892 34,117 20,775 20,775
PT 5SGCT 44,655 41,895 2,760 2,760
1739 B8 97,357.921 90,920,726 6,437,195 6,437.195
1740
1741 393 Stores Equipment
1742 G-SITU5 S 8,827,725 8,234,269 593,456 593,456
1743 PT SG 221,981 209,091 12,890 12,890
1744 PT SG 649,740 612,010 37,730 37,730
1745 PTD SO 441,665 416,885 24,780 24,780
1746 G-SG SG 3,327,215 3.134,004 193,211 193,211
1747 PT S5GCT 80,482 75,508 4,974 4,974
1748 B8 13,548,809 12,681,766 867,042 867,042
.
REVISED PROTOCOL Page 2.28
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1749.!394 Tools, Shop & Garage Equipment
G-5ITU5 5 31,393,987 29,763,311 1,630,676 1,630,676
PT 5G 2,555,122 2,406,746 148,376 148,376
1753 G-5G 5G 18,791,620 17,700,390 1,091.229 1,091,229
1754 PTO SO 4.099,455 3,869,450 230.005 230,005
1755 P 5E 7,106 6,648 458 458
1756 PT 5G 3,941,589 3,712,701 228,888 228,888
1757 G-5G 5SGCH 1,700,098 1,603,830 96,268 96,268
1758 G-SG SSGCT 80,583 75,603 4,980 4.980
1759 88 62,569.560 59,138,678 3,430,881 3,430.881
1760
1761 395 Laboratory Equipment
1762 G-SITU5 S 27,235,892 25,899,356 1,336,536 1,336,36
1763 PT 5G 112,594 106,056 6,538 6,538
1764 PT 5G 503,523 474,283 29,240 29,240
1765 PTD SO 5,458,605 5,152,342 306,262 306,262
1766 P SE 42.438 39.701 2,737 2,737
1767 G-SG 5G 5,882,451 5,540,857 341,594 341,594
1768 G-SG SSGCH 253,001 238,674 14,326 14.326
1769 G-SG 5SGCT 62,070 58,234 3,836 3,836
1770 88 39,550.574 37,509,504 2,041,070 2,041,070
1771
1772 396 Power Operated Equipment
1773 G-5ITU5 5 91,078,979 84,258,324 6,820,655 6,820,655
1774 PT 5G 981,699 924.692 57.007 57,007
1775 G-5G 5G 27,825,498 26,209,671 1,615,827 1,615,827
1776 PTD SO 1,625,409 1,534,213 91,96 91,196
1777 PT 5G 1,944,579 1,831,658 112,922 112,922
1778 P 5E 73,823 69,062 4,761 4,761
1779 P SSGCT
1780 G-5G 55GCH 846,777 798,828 47,949 47,949
1781 88 124,376,765 115.626,44 8,750,317 8,750,317
1782 397 Communication Equipment
1783 COM_EO 5 104,664,435 98,048,898 6,615,537 303,278 6,918,815
1784 COM_EO 5G 5,558,946 5,236,138 322,808 322,808.COM_EO 5G 10,430,523 9,824,823 605,701 605,701
COM_EO SO 50,00,157 47,223,148 2,807,009 132,285 2,939,294
COM_EO CN 4,536,381 4,360,423 175,958 7,392 183,350
1788 COM_EO 5G 65,034,602 61,258,042 3,776,560 22,185 3,798,744
1789 COM_EO 5E 113,823 106,482 7,341 7,341
1790 COM_EO 5SGCH 948,992 895,255 53,737 53,737
1791 COM_EO 5SGCT 44,584 41,829 2,755 2,755
1792 88 241,362,443 226,995,038 14,367,405 465,140 14,832,544
1793
1794 398 Misc. Equipment
1795 G-5ITU5 5 1,146,629 1,086,484 60,145 60,145
1796 PT 5G 15,384 14,491 893 893
1797 PT 5G 13,908 13,101 808 808
1798 CUST CN 197,260 189,609 7,651 7,651
1799 PTD SO 3,306,549 3,121,030 185,518 185,518
1800 P 5E 2,600 2,432 168 168
1801 G-5G 5G 1,451,292 1,367,016 84,277 84,277
1802 G-5G 5SGCT 1.325 1,243 82 82
1803 B8 6,134,947 5,795,405 339,542 339.542
1804
1805 399 Coal Mine
1806 P 5E 261,496,478 250,244,957 17,251,521 11,825,175 29,076,696
1807 MP P 5E
1808 B8 267,496,478 250.244,957 17,251,521 11,825.175 29,076.696
1809
1810 399L WIOCO Capital Lease
1811 P SE 88
1812
1813
1814 Remove Capital Leases
1815 B8
1816
.
REVISED PROTOCOL Page 2.29
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1817 1011390 General Capital Leases.G-SITUS S 13,145,093 13,145,093
P SG 14,737,388 13,881,588 855,800 855,800
PTD SO 12,902,451 12,178,541 723,909 723,909
1821 69 40,784,932 39,205,223 1,579,710 1,579,710
1822
1823 Remove Capital Leases (40,784,932)(39.205.223)(1,579.710)(1,579,710)
1824
1825
1826 1011346 General Gas Line Capital Leases
1827 P SG
1828 69
1829
1830 Remove Capital Leases
1831
1832
1833 GP Unclassified Gen Plant - Acct 300
1834 G-SITUS S
1835 PTO SO 449,864 424,624 25,240 25,240
1836 CUST CN
1837 G-SG SG
1838 PT SG
1839 PT SG
1840 68 449,864 424.624 25.240 25,240
1841
1842 399G Unclassified Gan Plant - Acct 300
1843 G-SITUS S
1844 PTD SO
1845 G-SG SG
1846 PT SG
1847 PT SG
1848 68
1849
1850 Total General Plant B8 1,189,214,176 1,113,624,296 75,589,880 12,290,314 87,880,194
1851
1852 Summary of General Plant by Factor.S 479.616,416 44,743,899 32,872,517 303,278 33,175,796
OGP
DGU
1856 SG 191,748,456 180,613,622 11,134,833 22,185 11,157,018
1857 SO 260.226,643 245,626,277 14,600,366 132,285 14,732,651
1858 SE 268.582,277 251,26,729 17,321,547 11,825,175 29,146,722
1859 CN 25.239,435 24,260,44 978,991 7,392 986,383
1860 OEU
1861 SSGCT 320.433 300,630 19,803 19,803
1862 SSGCH 4.265,449 4,023,917 241.532 241,532
1863 Less Capital Leases (40,784,932)f39,205,223)(1,579,710)(1,579,710)
1864 Total General Plant by Factor 1,189,214,176 V13,624,296 75,589,880 12,290.~14 87.880.194
1865 301 Organization
1866 I-SITUS S
1867 PTD SO
1868 I-SG SG
1869 68
1870 302 Franchise & Consent
1871 1-SITUS S 1,724,600 1.724,600 1,724,600
1872 I-SG SG 5,353,521 5,042,642 310,879 310,879
1873 i-SG SG 80,028,445 75,381,193 4,647,252 1,239,006 5,886,258
1874 i-SG SG 9,240,742 8,704,132 536,610 536,610
1875 P SG
1876 P SG 600,993 566,093 34,900 34,900
1877 B8 96,948,301 89,694.060 7,254.241 1,239,006 8,493.247
1878
.
REVISED PROTOCOL Page 2.30
Beginning/Ending
FERC BUS UNADJUSTED RESUL 1S IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1879 303 Miscellaneous Intangible Plant
e!1-SITUS S 1,805,661 1,413,280 392,381 392,381
I-SG SG 69,007,965 65,000,672 4,007,293 341,910 4,349,203
PTO SO 370,355,652 349,576,350 20,779,302 243,314 21,022,616
1883 P SE 3,623,519 3,389,829 233.690 233,690
1884 CUST CN 112,067,234 107,720,354 4,346,880 4,346,880
1885 P SG 344,575 324,566 20.009 20,009
1886 P SSGCT
1887 B8 557,204,607 527,425,051 29.779.555 585,224 30,364,779
1888 303 Less Non.Utilty Plant
1889 1-SITUS S
1890 557,204.607 527,425,051 29,779.555 585.224 30,364.779
1891 IP Unclassified Intangible Plant - Acct 300
1892 I-SITUS S
1893 I-SG SG
1894 P SG
1895 PTO SO 2,381,676 2,248,049 133,627 133.627
1896 2,381,676 2,248.049 133,627 133,627
1897
1898 Total Intangible Plant B8 656,534.583 619.367,160 37,167,423 1.824.230 38.991,653
1899
1900 Summary of Intangible Plant by Factor
1901 S 3,530,261 1,413,280 2,116,981 2,116,981
1902 OGP
1903 DGU
1904 SG 164,576,241 155,019,298 9,556,943 1,580,916 11,137,859
1905 SO 372,737,328 351,824,398 20,912,929 243,314 21,156,243
1906 CN 112,067,234 107,720,354 4,346,880 4,346,880
1907 SSGCT
1908 SSGCH
1909 SE 3,623.519 3,389,829 233,690 233,690
1910 Total Intangible Plant by Factor 656,534,583 619,367,160 37,167,423 1,824,230 38,991,653
1911 Summary of Unclassified Plant (Account 106)
1912 OP 29,000,576 27,607,894 1,392,682 1,392,682
1913 OSO
1914 GP 449,864 424,624 25,240 25,240.HP
NP
OP 151,409,535 142,617,183 8,792,352 8,792,352
191~TP 26,145,671 24,627.392 1,518,279 1,518,279
1919 TSO
1920 IP 2,381,676 2,248,049 133,27 133,627
1921 MP
1922 SP 3,141,303 2,958,888 182,415 182,415
1923 Total Unclassified Plant by Factor 212,528,25 200,484.029 12,044,596 12,044,S9l
1924
1925 Total Electric Plant In Service B8 17.252,000,564 16,284,053.852 967,946,712 86,137,630 1,054,084,342
.
REVISED PROTOCOL Page 2.31
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1926 Summary of Electric Plant by Factor.:5 5,478,023,290 5,192,072,206 285,951,083 303,278 286,254,361
5E 272,205,796 254,650,559 17,555,237 11.825,175 29,380,412
DGU
1930 DGP
1931 5G 10,244,285,064 9,649,399,400 594,885,665 68,644,466 663,530,130
1932 50 632,963,971 597,450,675 35,513,296 375,599 35,888,894
1933 CN 137,306,669 131,980,798 5,325,871 7,392 5,333,263
1934 DEU
1935 5SGCH 451,258,088 425,705,532 25,552,556 5.014,507 30,567,063
1936 SSGCT 76,742,619 71,999,905 4,742,714 (32,786)4,709,928
1937 Less Capital Leases ~40,784,932)(39,205,223)(1,579,710)(1,579.710)
1938 17, 52.00,564 16,284,053,852 967,946,712 86,137,630 1,054,084.342
1939 105 Plant Held For Future Use
1940 DPW S 1,566,169 1,566,169
1941 P SG
1942 T SG 7,405,028 6,975,018 430,010 (689,098)(259,088)
1943 P SG 4,461,651 4,202.563 259,088 259,088
1944 P SE 953,014 891,552 61,462 (61,462)°
1945 G SG
1946
1947
1948 Total Plant Held For Future Use 810 14,385,862 13,635,301 750,56 (750,560)(0)
1949
1950 114 Electric Plant Acquisition Adjustments
1951 P S
1952 P SG 142,633.069 134,350,366 8,282,103 8,282,703
1953 P SG 14,560,711 13,715,170 845,541 845,541
1954 Total Electric Plant Acquisition Adjustment B15 157,193,780 148,065,536 9,128.243 9,128,243
1955
1956 115 Accum Provision for Asset Acquisition Adjustments
1957 P S
1958 P SG (76,874,453)(4,46,100)
1959 P SG (11,233,390)(652,323)
1960 615 ,1 . 44 ,4
1961.~120 Nuclear Fuel
P SE
Total Nuclear Fuel 815
1965
1966 124 Weatherization
1967 DMSC S 3,881.062 3.843,192 37,870 37,870
1968 DMSC SO (2,464)(2,325)(138)(138)
1969 616 3,878,598 3,840,867 3032 37,732
1970
1971 182W Weatherization
1972 DMSC S 11,248,956 6,215,935 5,033.021 5,033,021
1973 DMSC SG
1974 DMSC SGCT
1975 DMSC SO
1976 616 11,248,956 6,215,935 5,033,021 5,033,021
1977
1978 186W Weatherization
1979 DMSC S
1980 DMSC CN
1981 DMSC CNP
1982 DMSC SG
1983 DM5C SO
1984 616
1985
1986 Total Weatherization 816 15,127,554 10,056,802 5,070,752 5,070,152
.
REVISED PRorOCOL Page 2.32
BeginninglEnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1987.151 Fuel Stock
P DEU
P SE 109,294,160 102,245,504 7,048,656 1,735.893 8,784,548
1991 P SSECT
1992 P SSECH 8,274,373 7,770,515 503,857 301,038 804,895
1993 Total Fuel Stock B13 117.568,532 110,016,019 7.552.513 2,036,930 9,589,443
1994
1995 152 Fuel Stock - Undistributed
1996 P SE
1997
1998
1999 25316 DG&T Working Capital Deposit
2000 P SE (712,500)(666,549)(45,951)(45,951)
2001 613 (712,500)(666,549)(45,951)(45,951)
2002
2003 25317 DG&T Working Capital Deposit
2004 P SE (1,619,511 )(1,515,065)(104.446)(104,46)
2005 613 (1,619,511 )(1,515,065)(104,446)(104,446)
2006
2007 25319 Provo Working Capital Deposit
2008 P SE
2009
2010
2011 Total Fuel Stock 613 115,236,521 107,834,405 7,402,116 2,036,930 9,439,046
2012 154 Materials and Supplies
2013 MSS S 82,786,565 78,005,253 4,781,312 4,781,312
2014 MSS SG 2,015,664 1,898,614 117,050 117.050
2015 MSS SE 4,485,530 4,196,247 289,283 289,283
2016 MSS SO 28,328 26,738 1,589 1,589
2017 MSS SNPPS 74,964,378 70,622,424 4,341,954 4,341,954
2018 MSS SNPPH (1,860)(1,752)(108)(108)
2019 MSS SNPD (4,617,053)(4,401,797)(215,256)(215,256)
2020 MSS SNPT
2021 MSS SG
2022 MSS SG.MSS SSGCT
MSS SNPPO 401,143 377,799 23,344 23,344
MSS SSGCH
2026 Total Materials and Supplies 813 160.062,695 150,723,527 9.339,168 9.339.168
2027
2028 163 Stores Expense Undistributed
2029 MSS SO
2030
2031 613
2032
2033 25318 Provo Working Capital Deposit
2034 MSS SNPPS (273,000)(257,188)(15,812)(15,812)
2035
2036 613 (273,000)(257,188)(15,812)(15,812)
2037
2038 Total Materials & Supplies 613 159,789,695 150,466,339 9,323,356 9,323,356
2039
2040 165 Prepayments
2041 DMSC S 3.256,834 3,054,764 202,069 202.069
2042 GP GPS 8.530,421 8,051,810 478,611 478,611
2043 PT SG 4,434,208 4,176.714 257,494 257,494
2044 P SE 2,754,616 2,576,964 177,652 177,652
2045 PTD SO 20,011,329 18.888,566 1.122,763 1,122,763
2046 Total Prepayments 815 38.987,409 36.748.819 2.238,589 2.238,589
2047
.
REViseD PROTOCOL Page 2.33
Beginninglnding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
41
182M Mise Regulatory Assets
DD52 5 64,867,163 65,134,658 (267,496)(5.642)(273,138)
DEF5G 5G 6,201,060 5,840,964 360,096 360,096
P 5GCT 10,195,361 9,601,031 594,330 594,330
2052 DEF5G SG.p (96,492)(96,492)
2053 P 5E
2054 P SSGCT
2055 DDS02 50 7,045,209 6.649,928 395,281 395,281
2056 Bl1 88,308,792 87,226,581 1,082,21 (102,134)980.017
2057
2058 186M Mise Deferred Debits
2059 LABOR S 4,035,508 4,035,508
2060 P 'SG
2061 P SG
2062 DEFSG 5G 47,760,691 44,987,227 2,773,463 2,773,63
2063 LABOR SO 76,977 72,659 4,319 4,319
2064 P SE 8,320,293 7,783,697 536,597 53,205 589,802
2065 P SNPPS
2066 GP EXCTAX
2067 Total Misc. Deferred Debits 811 60,193,470 š6.879.091 3,314,379 53,205 3,36,584
2068
2069 Working Capital
2070 CWC Cash Working Capital
2071 CWC S 41,638,469 39,377,660 2.260,810 7,008 2,267,817
2072 CWC SO
2073 CWC SE
2074 B14 41,638,469 39,377,660 2,260.810 7,008 2,267.817
2075
2076 OWC 01h Wcn, cap.
2077 131 Cas GP 5NP 11,667,121 11,024,811 642,310 (642,310)(0)
2078 135 WOr1in Fun GP 5G 2,151 2.026 125 125
2079 141 Note Recvabli GP SO 190,713 180,013 10,700 10,700
2080 143 Olr1V GP 50 26,532,240 25,043,613 1,488,627 1,488,627
2081 232 Al PTD 5
2082 232 Al PTD 50 (5,452,206)(5,146,303)(305,903)(305,903)
C 232 Al P SE (1,332,966)(1.246,999)(85,966)(85,966)
232 Al T SG
2533 01.. Mo, 1)1 Cr. P S
2533 01.. Mo, Ot Cro, P 5E (5,835,725)(5.459.364)(376,361)(376.361)
2087 230 As Reir. Oblig.P 5E (2,460,800)(2,302,097)(158,703)(158,703)
2088 230 As Reir. Oblig. P 5
2089 254105 ARO Reg l_.y P 5
2090 254105 ARO Reg Liabiity P SE (546,812)(511,547)(35,265)(35,265)
2091 2533 Choa Reamation P S5ECH
2092 B14 22,763,716 21,584,153 1,179,564 (642,310)537,253
2093
2094 Total Working Capital 814 64.402,186 60,961.813 3,440,373 (635,302)2.805.071
2095 Miscellaneous Rate Base
2096 18221 Unrec Plant & Reg Study Costs
2097 P 5
2098
2099 B15
2100
2101 18222 Nuclear Plant - Trojan
2102 P S (887,941)(887,941)
2103 P TROJP 2.111,016 1,986,370 124,646 124,646
2104 P TROJD 3,091,107 2,908,058 183,049 183,049
2105 B15 4,314,182 4,006,487 307,695 307,695
2106
2107
.
REVISED PROTOCOL Page 2.34
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT.DE SCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2108.1869 Misc Deferred Debits-Trojan
P 5
P 5NPPN
2112 B15
2113
2114 Total Miscellaneous Rate Base B15 4,314,182 4,006,487 307.695 307.695
2115
2116 Total Rate Base Additions B15 629,831,607 592,889,755 36,941.852 602,138 31,543,991
2117 235 Customer Service Deposits
2118 CUST 5
2119 CUST CN
2120 Total Customer Service Deposits B15
2121
2122 2281 Prop Ins PTO 50
2123 2282 Inj&Dam PTO 50 (7,277,878)(6,869,543)(408,335)(408,335)
2124 2283 Pen & Ben PTD 50 (20,615,854)(19,459,173)(1,156,680)(1,156,680)
2125 254 Reg Liab PTO 5G
2126 254 Reg Uab PTO 5E (1,526,930)(1,428,455)(98,476)(37,793)(136,268)
2127 254 Ins Prov PTO 50
2128 B15 (29.420,662)(27,757,17)(1,663,491 )(37.793)(1,701.284)
2129
2130 22844 Accum Hydro Relicensing Obligation
2131 P 5
2132 P SG
2133 B15
2134
2135 22842 Prv-Trojan P TROJO (1,242,005)(1,168,456)(73,549)(73,549)
2136 230 ARO P TROJP (2,159,328)(2.031,829)(127,499)(127,499)
2137 254105 ARO P TROJP (2,119,578)(1,994,426)(125,152)(125,152)
2138 254 P 5 (1,049,034)(970,817)(18,217)69,396 (8,821)
2139 B15 (6,569.945)(6.165,528)(404,417)69,396 (335,021)
2140
2141 252 Customer Advances for Construction
2142 DPW 5 (13,495,438)(13,462,782)(32,656)(130,469)(163,125)
2143 DPW 5E.T 5G (5,039,434)(4,746,794)(292,640)(111,531 )(404,171)
DPW 50
CUST CN (337,812)324,709)13,103)13,103 0)
2147 Total Customer Advances for Construction B19 ,2,68 1 ,534,2 5 38,3 9 , 9
2148
2149 25398 502 Emissions
2150 P 5E (2.744,693)(2,744,693)
2151 B19 (2,744,693)(2,744,693)
2152 '
2153 25399 Other Deferred Credits
2154 P 5 (4.615,986)(4.538,939)(77,048)(77,048)
2155 LABOR 50 (266,187)(251,252)(14,935)(625,817)(640,752)
2156 P SG (14,588,478)(13,741,325)(847,153)(62.353)(909,506)
2157 P SE (2,344,968)(2,193,735)(151,233)(151.233)
2158 B19 (21,815,619)(20.72,251 )(1,090,368)(688,170)(1,77,539)
.
REVISED PROTOCOL Page 2.35
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2159.190 Accumulated Deferred Income Taxes
P S 6,096.945 5,645,485 451,460 (259,585)191,876
CUST CN 100,289 96,399 3,890 3,890
2163 P IBT
2164 LABOR SO 40,832,990 38,542,000 2,290,990 (127,251 )2,163,739
2165 P DGP 184 184
2166 CUST BADDEBT 3,006,880 2,944,619 62,261 62,261
2167 P TROJD 137 129 8 8
2168 P SG 40,342,040 37,999,377 2,342,662 94,798 2,437,460
2169 P SE 14,266,483 13,346,402 920,081 1,041,638 1,961,720
2170 PTD SNP (0)(0)(0)(0)
2171 DPW SNPD 735,215 700,938 34,277 34,277
2172 P S5GCT 1,252,667 1,175,252 77,415 77,415
2173 Total Accum Deferred Income Taxes B19 106,633,831 100,450,785 6,183.045 749,601 6.932,646
2174
2175 281 Accumulated Deferred Income Taxes
2176 P S
2177 PT DGP
2178 T 5NPT
2179 B19
2180
2181 282 Accumulated Deferred Income Taxes
2182 GP 5 (1,311,327)(1,056,793)(254,534)1,392 (253,142)
2183 ACCMDIT DITBAL (1,453,442,766)(1,364,084,266)(89,358,500)(89,358,500)
2184 P S5GCH (11,290)(11,290)
2185 LABOR SO (13,464,253)(12,708,823)(755,430)(13,45)(768,875)
2186 CUST CN 109 109
2187 P 5E (14,328.925)(13,404,817)(924,108)541 (923,568)
2188 P 5G (11,540,157)(10,870,020)(670,137)(4,893,851 )(5,563,988)
2189 B19 (1,494,087,428)(1,402,124,719)(91,962,709)(4,916,544)(96,879.254)
2190
2191 283 Accumulated Deferred Income Taxes
2192 GP 5 (35,389,731)(34,297,130)(1,092,601 )655,897 (436,704)
2193 P 5G (9,163,040)(8,630,942)(532,098)72.750 (459,348)
2194 P SE (14,313,463)(13,390,352)(923,111 )(107,166)(1,030,277).LABOR SO (5,913,158)(5,581,392)(331,766)(331,766)
GP GPS (14,967,110)(14,127.360)(839,750)(839,750)
PTD SNP (7,142,462)(6,749,248)(393.214)(393,214)
2198 P TROJD 457,965 430,845 27,120 27,120
2199 P 55GCT
2200 P 5GCT (2,729,655)(2,570,532)(159,123)(159,123)
2201 P 55GCH
2202 B19 (89,160,655)(84,916,112)(4.244,543)621,481 (3,623.061 )
2203
2204 Total Accum Deferred Income Tax B19 (1,476,614,252)(1,386,590,045)(90,024,207)(3,545,463)(93,569,669)
2205 255 Accumulated Investment Tax Credit
2206 PTD 5
2207 PTD ITC84 (2,617,973)(2.617,973)
2208 PTD ITC85 (4,062,340)(4,062,340)
2209 PTD ITC86 (1,849,695)(1,849,695)
2210 PTD ITC88 (266,688)(266,688)
2211 PTD ITC89 (575,134)(575,134)
2212 PTD ITC90 (359,070)(308,867)(50,203)(50,203)
2213 PTD IBT -335,429 335,429
2214 Total Accumlated ITC B19 (9,730,900)(9,68õ.697)(50,203)335.29 285,226
2215
2216 Total Rate Base Deductions (1,563,024,062)(1,469,452,976)(93,571,085)(6,84.191)(100.411,276)
2217
.
REVISED PROTOCOL Page 2.36
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL.108SP Steam Prod Plant Accumulated Depr
2221 P 5
2222 P SG (845,561,293)(796,459,546)(49,101,747)(49,101,747)
2223 P SG (919,827,242)(866,412,871 )(53,14,371 )(53,414,371 )
2224 P SG (498,460,826)(469,515,204)(28.945,622)(58,694)(29.04,316)
2225 P SSGCH (185,135,732)(174,652,394)(10,483,338)(29,860)(10,513,198)
2226 617 (2,448,985.093 )(2.307,040.016)(141,945,077)(88,554)(142,033,632)
2227
2228 108NP Nuclear Prod Plant Accumulated Depr
2229 P SG
2230 P SG
2231 P SG
2232 617
2233
2234
2235 108HP Hydraulic Prod Plant Accum Depr
2236 P 5
2237 P SG (144,632,369)(136,233,567)(8,398,802)(8,398,802)
2238 P SG (28,211,936)(26.573.669)(1,638,267)(1,638,267)
2239 P SG (54.772,999)(51,592,331 )(3,180,668)(15,617)(3,196,286)
2240 P SG (9,051,245)(8,525,640)(525,606)(4,942)(530.547)
2241 617 (236,668,549)(222,925,206)(13,743,343)(20,559)(13,763,902)
2242
2243 1080P Other Production Plant. Accum Depr
2244 P 5
2245 P SG (1,583,085)(1,491,155)(91,930)(91.930)
2246 P SG
2247 P SG (110,121,288)(103,726,545)(6,394,744)(1,209,870)(7,604,613)
2248 P SSGCT (16,954,270)(15,906,492)(1,047,778)(1,047,778)
2249 617 (128,658,643)(121,124,192)(7,534,452)(1,209.870)(8.744,321)
2250
2251 108EP Experimental Plant - Accum Depr
2252 P SGIiPSG
Total Production Plant Accum Depreciation B17 (2.814,312,285)(2,651,089.413)(163,222,872)(1.318,983)(164,541.855)56
2257
2258 Summary of Prod Plant Depreciation by Factor
2259 5
2260 DGP
2261 DGU
2262 SG (151,691,756)(1,289,123)
2263 SSGCH (10,483,338)(29,860)
2264 SSGCT (1,047,778)
2265 Total of Prod Plant Depreciation by Factor 1 2, 7 1, 18,
2266
2267
2268 108TP Transmission Plant Accumulated Depr
2269 T SG (376,835,526)(354,952,686)(21,882,840)(21,882,840)
2270 T SG (377,107,334)(355,208,710)(21,898,624)(21,898,624)
2271 T SG 333,737,270)(314,357,146)19.380.124)(69,620)(19,449.744)
2272 Total Trans Plant Accum Depreciation B17 ,08 ,,1 ,4,5 8.6.8
.
REVISED PROTOCOL Page 2.37
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2273 108360 Land and Land Rights.DPW 5 (5,426,114)(5,191,977)(234,137)(234.137)
B17 (5,426,114)(5,191,977)(234,137)(234,137)
2277 108361 5tructures and Improvements
2278 DPW 5 (14,430,466)(13,945.723)(4a4,743)(484.743)
2279 B17 (14,430,66)(13,945,723 )(484,743)(4a4.743)
2280
2281 108362 Station Equipment
2282 DPW 5 (185,020,533)(176,682,885)(8,337.648)(8,337,648)
2283 B17 (185,020,533)(176,682,885)(8,337,648)(8,337.648)
2284
2285 108363 5torage Battery Equipment
2286 DPW 5 (749,006)(749,006)
2287 B17 (749,006)(749,006)
2288
2289 108364 Poles, Towers & Fixtures
2290 DPW 5 (44,270,441)(415,917,899)(28,352,542)(28,352.542)
2291 B17 (44,270,44 1)(415,917,899)(28,352.542)(28,352,542)
2292
2293 108365 Overhead Conductors
2294 DPW 5 (247,818,052)(236,697,544)(11,120,508)(11,120,508)
2295 B17 (247,818,052)(236,697.544)(11.120,508)(11,120,508)
2296
2297 108366 Underground Conduit
2298 DPW 5 (114.081,755)(110.809.280)(3,272,474)(3,272,474)
2299 817 (114,081,755)(110,809,280)(3,272,4 74)(3.272,474)
230
2301 108367 Underground Conductors
2302 DPW 5 (24a,580,695)(237,936,176)(10,644,519)(10,644,519)
2303 B17 (248,580,695)(237,936,176)(10,644,519)(10,644,519)
2304
2305 108368 Line Transformers
2306 DPW 5 (351,372,868)(326,280,612)(25,092,256)(25,092,256)
2307 B17 (351.372,868)(326,280,612)(25,092,256)(25,092,256)
2308.108369 5ervices
DPW 5 (151,972,177)(141,438,180)(10.533,997)(10,533,997)
B17 (151,972,177)(141,438,180)(10,533,997)(10,533,997)
2312
2313 108370 Meters
2314 DPW 5 (80,784,138)(73,845,763)(6,938,376)(6,938,376)
2315 B17 (80,784,138)í73,845,763)(6.938,376)(6,938,376)
2316
2317
2318
2319 108371 Installations on Customers' Premises
2320 DPW 5 (6,850,076)(6,712,402)(137,675)(137,675)
2321 B17 (6,850,076)í6,712,402)(137,675)(137,675)
2322
2323 108372 Leased Propert
2324 DPW 5 (20,556)(18,213)(2.343)(2,343)
2325 B17 (20,556)(18,213)(2,343)(2,343)
2326
2327 108373 5tret Lights
2328 DPW 5 (24,224,319)(23,845,218)(379,101)(319,101)
2329 817 (24,224,319)(23,845,218)(379,101 )(379,1011
2330
2331 108000 Unclassified Dist Plant. Acct 300
2332 DPW 5
2333 817
2334
2335 10805 Unclassified Dist 5ub Plant. Acct 300
2336 DPW 5
2337 B17
2338
2339 108DP Unclassified Dist 5ub Plant. Acct 300
2340 DPW 5 264,929 257,429 7,500 7,500
2341 B17 264,929 257,429 7,500 1,500
2342
2343~Total Distribution Plant Accum Depreciation B17 (1.875,336,266)(1,169.813,448)(105,522.818)(105,522.818)
5ummary of Distribution Plant Depr by Factor
47 5 (1,875,336,266)(1,169,813,44)(105,522,818)(105,522,818)
2348
2349 Total Distribution Depreciation by Factor B17 (1,87$,336,266)(1,769,813,448)(10S,22,818)(105,522,818)
REVISED PROTOCOL Page 2.38
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DeSCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2350 108GP General Plant Accumulated Depr.G-ITUS 5 (150,282,503)(138,259,608)(12,022.895)(3,668)(12,026,563)
PT SG (7,359,036)(6,931,697)(427.339)(427,339)
PT SG (14,294,098)(13,464,039)(830,058)(830,058)
2354 G-SG SG (42,466,304)(40.000,286)(2,466,018)(354)(2,466,372)
2355 CUST CN (6.324,731 )(6,079,407)(245,325)(287)(245,611 )
2356 PTD SO (87,629.616)(82,713,038)(4,916,578)(4,397)(4,920,915)
2357 P SE (451,561)(422,439)(29,122)(29,122)
2358 G-SG SSGCT (43,709)(41,008)(2,701)1,312 (1,389)
2359 G-5G SSGCH (2,417,343)(2,280,461 )(136,882)(136,882)
2360 817 (311,268.900)(290,191,981)(21,076,919)(7,393)(21,084.312)
2361
2362
2363 108MP Mining Plant Accumulated Depr.
2364 P S
2365 P SE (161,520,351)(151,103,497)(10,416,854)(1,424)(10,418.218)
2366 617 (161,520,351)(151,103,497)(10,416.854)(1,424)(10.418,278)
2367 108MP Less Centralia Situs Depreciation
2368 P S
2369 617 (161,520,351 )(151,103,497)(10,416.854)(1,424)(10,418.218)
2370
2371 1081390 Accum Depr . Capital Lease
2372 PTD SO 817
2373
2374
2375 Remove Capital Leases
2376 817
2377
2378 1081399 Accum Depr. Capital Lease
2379 P S
2380 P SE 617
2381
2382
2383 Remove Capitl Leases
2384 617
2385.!Total General Plant Accum Depreciation B17 (472,789,251 )(441,295.478)(31,493.773)(8,818)(31.502.591)
2389
2390
2391 Summary of General Depreciation by Factor
2392 S (150,282,503)(138,259,608)(12,022.895)(3,668)(12,026,563 )
2393 DGP
2394 DGU
2395 SE (161,971,912)(151,525,936)(10,445,976)(1,424)(10,447,401 )
2396 SO (87,629,616)(82,713,038)(4.916,578)(4,397)(4,920,975)
2397 CN (6,324,731 )(6,079,407)(245,325)(287)(245,611)
2398 SG (64,119,438)(60,396,022)(3.723,416)(354)(3.723,769)
2399 DEU
2400 SSGCT (43,709)(41,008)(2,701)1,312 (1.389)
2401 SSGCH (2,417,343)(2,280,461 )(136,882)(136,882)
2402 Remove Capital Leases -
2403 Total General Depreciation by Factor (472,789.251)(441,295,478)(31,493,773)(8,818)(31,502,591)
2404
2405
2406 Total Accum Depreciation - Plant In Service B17 (6,250,117.933)(5,886,716,881)(363,401,052)(1,397,420)(364.798,472)
2407 111SP Accum Prov for Amort-Steam
2408 P SSGCH
2409 P SSGCT
f311,848)f292,575)
(19,272)19,272 (0)
2410 818 ~11,848)292,575)(19,272)19,272 (0)
2411
2412
2413 111GP Accum Prov for Amort-General
2414 G-SITUS S (15,781,365)(15,781,365)
2415 CUST CN (2,091.376)(2.010,255)(81.121)(81,121)
2416 I-SG SG
2417 PTD SO (9,286,209)(8.765,194)(521,015)(521,015)
2418 P SE
2419 818 (27,158,949)(26,556,813)(602,136\(602,136)
2420.
REVISED PROTOCOL Page 2.39
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2421.111HP Accum Prov for Amort-Hydro
P SG (344,575)(324,566)(20,09)(20,009)
P SG
2425 P SG (5,298)(4,991)(308)(308)
2426 P SG (33,712)(311,508)(19,204)(19,204)
2427 618 (680,586)(641,065)(39,522)(39,522)
2428
2429
2430 1111P Accum Prov for Amort-Intangible Plant
2431 I-SITUS S (758,514)(50,195)(708,319)(708,319)
2432 P SG
2433 P SG (307,541)(289,682)(17,859)(17,859)
2434 P SE (981,538)(918,236)(63,302)(63,302)
2435 I-SG SG (37,491,322)(35,314,201)(2,177,121)(6,375)(2,183,496 )
2436 I-SG SG (9,711,174)(9,147,246)(563,928)(16,281)(580,209)
2437 I-SG SG (2,646,531 )(2,492,847)(153,684)(153,684)
2438 CUST CN (82,052,452)(78,869,790)(3,182,662)(3,182,662)
2439 P SSGCr
2440 P SSGCH (30,904)(29,154)(1.750)(1,750)
2441 pro so (244,166,020)(230,466,757)(13,699,263)(7,865)(13,707,128)
2442 618 (378,145,996)(357,578,108)(20,567,888)(30,521)(20.598,409)
2443 1111P Less Non-Utilty Plant
244 NUTIL OTH ..
2445 (378.145,996)(357.578,108)(20,567,888)(30.521)(20,598,409)
2446
2447 111390 Accum Amtr - Capital Lease
2448 G-SlrUS S (1,015,479)(1,015,479)
2449 P SG (839,977)(791,199)(48,777)(48,777)
2450 pro so 2,393,255 2,258,978 134.277 134,277
2451 537,799 452,300 85,499 85,499
2452
2453 Remove Capita Lease Amtr (537,799)(452,300)(85,499)(85,499)
2454
2455 Total Accum Provision for Amortization B18 (406.297,379)(385,068.561)(21,228,818)(11,248)(21,240,066)
2456.
2460 Summary of Amortization by Factor
2461 S (17.555,357)(16,847.039)(708,319)(708,319)
2462 OGP
2463 DGU
2464 SE (981,538)(918,236)(63,302)
2465 SO (251,058,974)(236.972,972)(7,865)(14,093,866)
246 CN (84,143,828)(80,880.045)(3,263,783)
2467 SSGCT (311,848)(292.575)19,272 (0)
2468 SSGCH (30,904)(29,154)(1,750)
2469 SG (51,677,131)(48,676,240)(22,656)(3,023,547)
2470 Less Capital Lease 537,799)(452,300)85,499)
2471 Total Provision For Amortization by Factor (4uii,,561),40,)
.
IDAHO REVISED PROTOCOL Page 3.0 Total
Reveue Adjustments (Tab 3)
TOTAL
3.1 3.2 3.3 3.4 3.5 3.6.Temperaure Revenue Effective Price S02Emission Grn Tag Revenue
Total Nonnalize Noriiztion Normliztion . Change Alloances Revenue Corcting
1 Oprating Revenues:
2 Geeral Busiess Revenues 4,363.364 (1,652,629)1,275,450 4,740,542
3 Interpartmental
4 Specil Sales
5 Other Operang Revenues 286,135 253.55 9.807
6 Total Oprating Revenues 4,649,499 (1.652.629)1.275,450 4.740.542 253.553 9.807
7
8 Opatin9 Expenses:
9 Sleam Prouction
10 Nuclear Prouction
11 Hydro Prouction
12 Ot Power Supply
13 Transmision
14 Ditrbutio
15 Custom Accountin9
16 Customer Servce & Info
17 Sales
18 Administrativ & General
19 Total O&M Expenses
20 Deprciation
21 Amortization
22 Taxes Other Than Income
23 Income Taxes: Federal 1,562,312 (SS2,160)426,141 1,583,863 64,714 12,145
24 Stae 212,292 (75,029)57,905 215.221 11,511 1,650
25 Deerd Income Taxes (41,583)(41,583)
26 Investment Tax Credit Adj.
27 Mise Revue & Expense 83,029 109.571 (26,542)
28 Total Opetin9 Expenses:1,816.050 (627.189)48.046 1.799,083 67.988 96.226 (12.747)
29
30 Opating Rev For Return:2.833.449 (1.025.440)791,404 2.941,459 (67,988)157,327 22.55
31
32 Rale Base:
33 Electric Plant In Service
34 Plant Held for Future Use.35 Mie Deerr Debits
36 Elec Plant Acq Adj
37 Nuclear Fuel
36 Prepaymts
39 Fuel Stock
40 Materil & Supplies
41 Worng Capital
42 Weaterzation Loans
43 Mie Rale Bae
44 Total Eleric Plant:
45
46 Dections:
47 Accum Prov For Deee
48 Accum Prv For Amort
49 Accum Def Income Tax 1.041.638 1,041,638
50 Unamrtzed ITC
51 Custom Adv For Const
52 Customer Service Depoits
53 Micellaneous Dections (2,744,693)(2,744.693)
54
SS Total Deductions:(1,703.055)(1.703,OSS)
56
57 Total Rate Base:(1.703,055)(1,703,055)
58
59
60 Estimated ROE impact 1.112%-0.385%0.297%1.104%0.020%0.059%0.008%
61
62
63
64 TAX CALCULATiON:
65
66 Opeting Revenue 4,58,470 (1.652.629)1,275.450 4.740.542 (109,571)253,55 36,34
67 Oter Detions
66 Inlerest (AFUDC)
69 Interest
TO Schedule "M" Additions 315,30 315,306.71 Schedule"M" Deductions 205.735 205,735
72 Income Before Tax 4,676.041 (1.652,629)1,275,450 4,740,542 253,SS3 36,349
73
74 Stae Inom Taxes 212,292 (75,029)57.905 215,221 11,511 1,650
75
76 Taxbl Income 4,463.749 (1,577.599)1.217,545 4,525,322 242,041 34.699
77
78 Fedl Income Taxes 1.562.312 (552,160)426,141 1,583.863 54,714 12,145
IDAHO REVISED PROTOCOL Page 3.0.1 Total
Revenue Aduslmnts (Tab 3)
TOTAL
3,0 0 0 0.0 0 0.West Valley
Reserve 0 0 0 0 0 0
1 Opting Revenues:
2 General Business Revenues
3 Interdepartmental
4 Special Sales
5 Oter Operaing Revenues 22,775
6 TolalOpertlng Revenues 22.775
7
8 Operatig Expenses:
g Steam Prouction
10 Nuclear Production
11 Hyro Prouction
12 Other Pow Supply
13 Transmission
14 Distribulíon
15 Customer Accounting
16 Customr Service & Info
17 Sales
18 Admlnistralíve & General
19 Total O&M Exenses
2D Depreialíon
21 Amization
22 Taxes Oter Than Income
23 Income Taxes: Federal 7,609
24 State 1,034
25 Deerr Income Taxes
28 Investment Tax Credit Adj.
27 Mise Revenue & Expese
28 Total Oprating Expenses:8.643
29
30 Operating Rev For Return:14.132
31
32 Rate Base:
33 Electric Plt In Serce
34 Plant Held lor Future Use.35 Mise Deferd Debits
36 Elec Plant Acq Adj
37 Nuclear Fuel
38 Prepaymnts
39 Fuel Stock
40 Materal & Suppies
41 Worng Cap~al
42 Weatherizatio Loans
43 Mise Rate Base
44 Tota Elecc Plant
45
46 Dections:
47 Accum Prov For Depre
48 Acm Prov For Amort
49 Accum De Income Tax
50 Unamortize ITC
51 Customer Ad For Const
52 Customer Servce Deposits
53 Miscellaneous Deduclíons
54
55 Total Deuclíon:
56
57 Total Rate Base:
58
59
60 estimated ROE Impact 0.005°4 0.00%0.000%0.00%0.000%0.00%0.000%
61
62
63
64 TAX CALCULATION:
65
66 Operating Revenue 22,775
67 Other Deductins
68 Interest (AFUDC)
69 Interest
70 Schedule oM" Addis.71 Scheule oM" Deuctions
72 Income Belore Tax 22,775
73
74 State Income Taxes 1,034
75
76 Taxble Income 21,741
77
78 Federal Income Taxes 7,609
Rocky Mountain Power PAGE 3.1
Idaho Results of Operations.December 2008
Temperature Normalization.TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Revenue:
Residential 440 1 (1,457.914)10 Situs (1,457,914)3.1.1
Commercial 442 1 (194.715)10 Situs (194,715)3.1;1
Total (1,652,629)(1,652.629)
.
Description of Adjustment:
This adjustment normalizes revenues in the test period by comparing actual sales to temperature normalized sales. Weather
normalization reflects weather or temperature patterns which can be measurably different than normal. defined as the average
weather over a 20-year rollng time period (currently 1988 to 2007).
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Rocky Mountain Power PAGE 3.2
Idaho Results of Operations - December 2008.Revenue Normalization
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Revenue:
Residential 440 1 21,080 10 Situs 21,080
Commercial 442 1 175,286 10 Situs 175,286
Industrial 442 1 440,811 10 Situs 440,811
Special Contract 2 442 1 (57.146)10 Situs (57,146)
Special Contract 1 . Firm 442 1 29,829 ID Situs 29,829
Special Contract 1 . Non Firm 442 1 (636,634)ID Situs (636,634)
Special Contract 1 - Curtailed 442 1 1,302.224 ID Situs 1,302,224
Public Street Lighting 444 1 ID Situs
Other Sales to Public Authorities 445 1 10 Situs
Total 1,275,450 1,275,450 3.1.1
.
.
Description of Adjustment:
This adjustment normalizes revenues by removing the SPA credit, reversing the SMUD amortization and normalizing
special contract revenues.
Rocky Mountain Power PAGE 3.3
Idaho Results of Operations.December 2008.Effective Price Change
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Revenue:
Residential 440 3 1,409,377 10 Situs 1,409,377
Commercial 442 3 649,487 10 Situs 649,487
Industrial 442 3 930,617 10 Situs 930,617
Nu West 442 3 123,847 10 Situs 123,847
Monsanto-Firm 442 3 89,987 10 Situs 89,987
Monsanto-Non Firm 442 3 1,537,227 10 Situs 1,537,227
Monsanto-Curtailed 442 3 10 Situs
Public Street Lighting 444 3 10 Situs
Other Sales to Public Authorities 445 3 10 Situs
4,740,542 4,740,542 3.1.1
.
.
Description of Adjustment:
The type 3 adjustments reflect proforma price changes for special contracts effective January 1, 2009 - all other schedules
were effected by the April 18, 2009 price change,
.
.
Description of Adjustment:
Over the years, the Company's annual revenue from the sale of sulfur dioxide ("S02") emission allowances has been
uneven, This adjustment removes the sales occurrng in the historical period and includes amortization of sales over a 15
year period. This treatment was included in the Company's stipulated general rate case in Docket No. PAC-E-06-4.
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Page 3.4.2
Rocky Mountain Power
Results of Operations - December 2008
502 Emmission Allowance Sales
SAP Account 301947
Year Month Amount Balance
2008 1
2008 2
2008 3
2008 4 (1,192,027.38)(1,192,027,38)
2008 5 (1,192,027.38)
2008 6 (1,192,027.38)
2008 7 (1,192,027.38)
2008 8 (1,192,027.38)
2008 9 (1,192,027.38)
2008 10 (149,500.00)(1,341,527.38)
2008 11 (1,393,500.00)(2,735,027.38 )
2008 12 (2,154,000.00)(4,889,027.38) Pg. 3.4
.
.
.
Rocky Mountain Power
Idaho Results of Operations - December 2008
Green Tag Revenue
PAGE 3.5
TOTAL IDAHO
ACCOUNT ~ COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Re-allocation of Actual Wind Sales (For RPS Banking)
Re-allocation for Non-RPS States 456 1
Adjustment for CA RPS Banking 456 1
Adjustment for OR RPS Banking 456 1
Incremental Wind Green Tag Revenues from Historical Period to CY 2009Incremental Wind Green Tag Rev. 456 3 3,199,570 SG 5.807%
67,295 3.5.1
3.5.1
3,5.1
67,295
185,799 3.5.1
79,403 3.5,1
3.5.1
3.5.1
79,403
(331)3,5,2
(78,614)3,5.2
(78,945)
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Situs
Situs
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CA
OR
1,158,868
(67,907)
(1,090,961)
Re-allocation for Non-RPS States
Adjustment for CA RPS Banking
Adjustment for OR RPS Banking
456
456
456
3
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1.367,364 SG
(80,124) CA
(1,287,239) OR
5.807%
Situs
Situs
Incremental Adjustment for Salt River Project and Blundell RevenuesSalt River Project 456 3 (5,700) SGBlundell Sales (Contract Expired) 456 3 (1,353.776) SG
(1,359,476)
5.807%
5.807%
Description of Adjustment:
A market for green tags or renewable energy credits is developing where the tag or "green" traits of qualifing power
procuction facilties can be detached and sold separately from the power itself. These green tags or renewable energy
credits (REC's) may be applied to meet renewable portolio standards in various states. Currently, California and Oregn
have renewable portolio standards that make it advisable to bank REC's, for future compliance, rather than sell them. This
adjustment reallocates Oregon and California's SG factor amounts to the Company's other jurisdictions, consistent with the
agreement With the Multi-State Process (MSP) standing committee. In addition this adjustment adds incremental revenues
based on the CY 2009 projected levels.
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.Rocky Mountain Power Page 3,5,2
Results of Operations. December 2008
Green Tag Revenues
2009 Wind Generation. MWH . from GRID
Foote Creek I 102,699
Glenrock Wind 323,799
Glenrock II Wind 117,264
Goodnoe Wind 266,887
High Plains Wind 66,927
Leaning Juniper 1 305,473
Marengo I 393,136
Marengo II 187,226
Rollng Hills Wind 275,520
Seven Mile Wind 349,596
Seven Mile II Wind 68,862
Total 2009 Wind Generation. MWH 2,457,388
Qualified Facilties & Purchased Power. MWH. from GRID
Rock River I 142,099
OF Mountain Wind 437,903
Wolverine Creek 176,896
Total QF & Purchased Power. MWH 756,898.Total Renewable Energy Credits - MWH 3,214,286
Renewable Energy Credits Allocation
ID/UTIWAIY - SG Factor Allocated Portion 70,06%
MWH Available for Sale 2,251,912
Percent of Available MWH Sold 75%
TotalMWH Sold 1,688,934
Sales Price per MWH sold $3,50
Total Adjusted Green Tag Revenue from Wind - Dec. 2009 $5,911,270 Ref 3.5.1
Incremental Change
Total Actual Green Tag Revenue from Wind - Dec. 2008 $2,711,700
Incremental Change $3,199,570 Ref 3.5.1
Salt River Project
Actual Revenues(12 Months Ended December 2008)
Projected CY 2009 Revenues
Pro forma Adjustment to Revenues for Salt River Project
2,086,200
2,080,500
(5,700) Ref 3.5
.Blundell Green Tags
Actual Revenues(12 Months Ended December 2008)
Projected CY 2009 Revenues (Contract Expired)
Pro forma Adjustment to Revenues for Blundell
1,353,776
(1,353,776) Ref 3.5
Rocky Mountain Power PAGE 3.6
Idaho Results of Operations.December 2008.Revenue Correcting
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Revenues:
Other Electric Revenues 456 (168,880)UT Situs 3.6.1.
Other Electric Revenues 456 168,880 SG 5.807%9,807 3.6.1
9,807
Gains on Propert Sales
Gains on Propert Sales
421
421
(473,071)
473.071
SO
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5.611%
Situs
(26.542) 3.6.1
3.6.1
(26,542)
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Description of Adjustment:
This restating adjustment reflects non recurrng entries made to FERC 421 (Gains and Losses) and FERC 456 (Misc
Electric Revenue), in which incorrect or no tax jurisdiction codes were assigned when entered. Per Accounting.
failure to input a tax jurisdiction code would then cause FERC programming to assign the location code from the profi
center, assigning in tum an incorrect allocation factor.
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Rocky Mountain Power PAGE 3.7.Idaho Results of Operations. December 2008
West Valley Reserve
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Revenues:
Other Electric Revenues 456 353,146 SE 6.449%22,775 3.7.1
.
Description of Adjustment:
The current Grid model includes reserves associated with the West Valley plant. This adjustment provides the expected West
Valley Generation level included in GRID, adjusts it for the reserve requirement and mulitiplies it by the OASIS reserve rates to
calculate the revenue to add to results and be consistent with GRID. This adjustment is included in the fiing solely for the
purposes described above and is not related to the West Valley Leiise adjustment No. 5.2.
.
.Rocky Mountain Power Page 3.7.1
Results of Operations - December 2008
West Valley Reserve Revenue
Monthly Average Generation (GRID Input)
Pro Forma
Month Total MWh HLH LLH Tarriff Rate Revenues
1 20,357 15,207 5,151 0.746 $15,186
2 15,221 12,877 2,344 0.746 11,355
3 20,330 15,623 4,707 0.746 15,166
4 27,750 22,313 5,437 0.746 20,701
5 39,586 30,889 8,697 0.746 29,531
6 43,302 33,436 9.866 0.746 32,303
7 62,747 47,427 15,320 0.746 46,809
8 61,434 49,185 12,249 0.746 45,829
9 56,619 40,344 16,274 0.746 42,237
10 47,841 38,730 9,111 0.746 35,689
11 39,736 31,003 8,733 0.746 29,643
12 38,467 29,325 9,142 0.746 28,696
473,387 366,358 107,029 $353,146
Ref 3.7
.
..
IDAHO REVISED PROTOCOl Page 4.0 Total
O&M Adjlments (Tab 4)
TOTAl
4.1 4.2 4.3 4.4 4.5 4.6 4.7.Wag & EmployeMiscelusBenefi-Wag & Emploe MEHC Trasition lIti Load Incremetal Reme Non
Total Noraliz Gener Exse Annualiztlon Ben - Pr Fonna Savings Con1rol Proram Generation O&M Recurng Entres
1 Opeati Revenue:
2 General Business Revenues
3 Interdeparnt
4 Specal Sales
5 Other Operang Revenues
6 Total Operatng Revenues
7
8 Operat Expenses:
9 Sieam Prouctn 855.531 18,06 34.012
10 Nucear Producton
11 Hydro Producon 56,499 2,88 53.711
12 Ot Pow Supy 6.931.297 (12)6.58 126.816 5,65.813 821,118
13 Tranmision 86,277 3.612 89,577
14 Distrut 379.50 18,210 35,823
15 Custoer Accouting 152.525 7.526 144,99
16 Custo Service & Inf 9,171 (903)1,213 23,376
17 Sale
18 Administrtive & Genral 3,29,373 (14,714)12,861 247,777 268.188 2,337,717
19 Tota O&M Expeses 11,90,183 (15,629)70.856 1,36.092 268.188 5,656,813 821,118 2.337,717
20 Depriation
21 Amortzati
22 Taxes Ot Than Incme
23 Ince Taxes: Fedra (3,495.50)5,222 (23,674)(45,091)307.501 (1,889,99)(274,34)(781,055)
24 State (474,981)710 (3,217)(61.975)41.784 (256.819)(37.279)(106.132)
25 Defeed Inc Taxes (82,603)12.084
26 Investmt Tax Credit Adj.
27 MIe Revenu & Expense
28 Total Oprang Expenses:7.847.09 (9.698)43.967 847,026 629.55 3,509.996 50,496 1,450.530
29
30 Operating Rev For Retu:(7.847.09)9,698 (43.967)(847.026)(629.558)(3.50.99)(50.496)( 1,450.53)
31
32 Rate Base:
33 Elec Plant In Seric
34 Plant Hel for Fute Use.35 Mise Deerred Debits (5,642)
36 Elee Plant Ac Adj
37 Nucar Fuel
38 Prepymnts
38 Fue Stok
40 Matrial & Suppl
41 Woring Capl42 Wealh Loa
43 MIe Rate Base
44 Tot Ele Plant:(5,642)
45
46 Deuct:
47 Accum Pro For Depree
48 Accum Pro For Amrt
49 Accum De Inc Tax 314,581 451.686 74.818
50 Unamored ITC
51 Customer Adv For Const
52 Custome Servic Depoit
53 MlsceDaneou Deduct
54
55 Total Dedu:314,581 451,686 74,818
56
57 Total Rate Bae:30,93 451,686 74,818
58
59
60 Esti ROE ir -2.951%0.00%-0.016%-0.318%-0.248%-1.317%-0.191%-0.54%
61
62
63
64 TAX CAlCULATION:
65
66 Opeting Revenue (11.90,183)15.629 (70,858)(1,36,092)(268,166)(5,656,813)(821,118)(2,337,717)
67 Ot Dect
68 Intrest (AFUO)
691nlerest
70 Schule "M" Addils
71 Schdule "M" Deucons (1.43,04)(1,188,547)
72 Inco Befre Tax (10.46,138)15,629 (70.85)(1,36,092)920,35 (5,65.813)(821.118)(2,337.717).73
74 Slat Incoe Taxes (474,981)710 (3,217)(61,975)41,784 (256,819)(37.279)(106,132)
75
76 Taxabl Inco (9,987,156)14.919 (67,641)(1,303,116)878,574 (5.39.99)(783,839)(2.231,585)
77
7S Fedlnco Taxes (3,495,50)5.222 (23.674)(45.091)307.501 (1.889.998)(274,34)(781,05)
IDAHO REVISED PROTOCOL Page 4.0.1 Totl
O&M Adjutmnts (Tab 4)
TOTAL
4.8 4.9 4.10 4.11 4.12 4.13 4.14 4.15.A&GCosI
Aflat Mgmt Fee Preiminary Plan Compance Commhmenl Genertion Mebehips &
(MEHC)Expens Adver1slng Deparnt Insur Expense (MEHC)Overul Subscrtins
1 Opeting Revenues:
2 Gene Busins Revenues
3 Interdeparental
4 Speia Sal
5 Otr Operatg Revenues
6 TQlI Operating Revenus
7
8 Opeting Expeses:
9 Ste Proucn 489,455
10 Nuar Prcl
11 Hy Proucon
12 Ot Pow Suppl (23,53)343,511
13 Tranmissio 13,088
14 OIs1n 10,476
15 Customr Accntng
16 Custoer Serice & Info (14.515)
17 Sales
18 Admiistratie & General (77,405)(4.742)28,310 (225,623)9.997
19 Total O&M Expeses (77.405)(23.53)(14.515)18.822 28,310 (225,623)832.96 9.997
20 Depratin
21 Amortzatin
22 Taxes Oter Than Incme
23 Income Taxes: Federal 25.862 7.862 4.850 (6.289)(9,459)150,766 (278,30)(3.34)
24 State 3,514 1,068 659 (855)(1,285)20,487 (37,817)(45)
25 Deered Inc Taxes (85,626)
26 Investment Tax Creit Adj.
27 Mise Revenue & Expense
28 Tota Opeatng Expenses:(48.029)(14,601)(9.00)11,679 17,566 (139,996)516,847 6.203
29
30 Openg Rev For Return:48,029 14,601 9,00 (11,679)(17,56)139,99 (516,847)(6.203)
31
32 Rat Sase:
33 Elect Plant In Servic
34 Plnt Held fo Future Use
35 Mie Defered Debis.36 Elec Plant Acq Adj
37 Nucear Fuel
38 Pr-"nts
39 Fuel Stok
40 Maal & Suplies
41 Worng Capil
42 Weatriti Loans
43 Mis Raie Base
44 Totl Elect Ptl:
45
46 Dectns:
47 Accm Pr For Depree
48 Ac Pro For Amor
49 Ac De Inc Tax (214,06)
50 Unaord ITC
51 Custo Ad For Conl
52 Customer Servic Deüs
53 Miscellans Deucns
54
55 Tot Deuctons:(214,06)
56
57 Tot Rate Base:(214,06)
56
59
60 Estiled ROE impact 0.018%0.00%0,003%-0.00%-0.007%0.05%-0.194%-0.002%
61
62
63
84 TAX CALCULATION:
65
66 Opeatng Revenue 77.40 23,53 14,515 (18,822)(28,310)225,623 (832,96)(9,997)
67 Other Deuctons
68 inteest (AFUOC)
69 Intel
70 Sc oM" Adns71 SCul "M De (225,623)
72 Inc Befre Tax 77,405 23,53 14,515 (18,82)(28,310)451,246 (832,96)(9,997).73
74 Sta In Taxes 3,514 1,068 659 (85)(1,285)20,487 (37,817)(454)
75
76 Taxab Income 73,891 22,46 13,65 (17.967)(27,025)43,759 (795,149)(9,543)
77
78 Fedal Inco Taxes 25,86 7,86 4,65 (6,289)(9,45)150.766 \278,30)(3,34)
IDAHO REVISED PROTOCOL Pag 4.0.2 Tota
O&M Adjustmts (Tab 4)
TOTAL
4.16 4.17 0 0 0 0 0 0.10 Pensio
Idho Inteenor Expense Cash
Funing BasiS 0 0 0 0 0 0
1 Operati Revenus:
2 Geral Busins Revenues
3 Inierdepartmental
4 Speal Sales
5 Otr Opealin Revenues
6 Totl Opratg Revenues
7
8 Operatig Expenses:
9 Steam Pructon
10 Nuclear Pro
11 Hydo Produc
12 Other Powr Supply
13 Transmission
14 Distrbutn
15 Custome Accunting
16 Cuslome Service & Inlo
17 Sale
18 Admistrative & Genral (11.285)85,291
19 Tota O&M Expenses (11.285)858,291
20 Deprecti
21 Amotion
22 Taxes Othr Than Incom
23 Inme Taxes: Fedral 11,747 (286.764)
24 State 1,59 (38.966)
25 De Inc Taxes (9,061)
26 Investmnt Tax Credit Adj.
27 MiSe Revenue & Expese
28 Tota Openg Expenses:(7.002)53,561
29
3D Operati Rev For Retur:7.00 (53,561)
31
32 Rate Base:
33 Elctc Plant In Serice
34 Plant Hel lor Future Use.35 MiSe Defered Debit (5.642)
36 Ele Plant Acq Adj
37 Nuclar Fuel
38 Prepayments
39 Fuel Sto
40 Material & SuPØies
41 Worlng Capil
42 Wea~ti Loans
43 Mie Rate Base
44 Tot Electc Plat (5,642)
45
46 Deducon:
47 Accum Pro For Deee
48 Acum Pro For Amo
49 Accm Def Inco Tax 2.142
50 Unamed ITC
51 Customer Adv For Conl
52 Custome Service Depoits
53 MIcellan Deducts
54
55 Totl Dectons:2.142
56
57 Totl Rate Base:(3,501)
58
5960 estited ROE imt 0,00%.0200%0.00%0.00%0.00%0.00%0.00%0.00%
61
62
63
64 TAX CALCULATION:
65
66 Oprati Reven 11,285 (85,291)
67 Other Deucs
68 Inlerest (AFUDC)
69 Inst
70 Schule "M" Aditns
71 Schule "M" Deucton (23,876)
72 Incoe Belore Tax 35,161 (858,291).73
74 Stale Ince Taxes 1,59 (38,96)
75
76 Taxable Incme 33,56 (819,324)
77
78 Fedl Incme Taxes 11.747 (286,764)
.
.
.
Rocky Mountain Power
Idaho Results of Operations - December 2008
Miscellaneous General Expense
Adjustment to Expense:
Other Expenses
Advertising Expense
Advertising Expense
Administrative & Gen Salaries
Offce Supplies & Exp
Outside Services Employed
Miscellaneous General Expense
l
PAGE 4.1
ACCOUNT Type
TOTAL IDAHO
COMPANY FACTOR FACTOR % ALLOCATED REF#
557
909
909
920
921
923
930
1
1
1
1
1
1
1
(209) SG
(23,290) CN
(500) UT
(5,141) SO
(12,561) SO
(235,317) SO
(9,225) SO
(286,242)
5.807%
3.879%
Situs
5,611%
5.611%
5.611%
5.611%
(12)
(903)
(288)
(705)
(13,203)
(518)
(15,629)
Description of Adjustment:
This adjustment removes from results of operations certain miscellaneous expenses that should have been
charged to non-regulated accounts.
.Rocky Mountain Power Page 4.1.1
Results of Operations - December 2008
Miscellaneous General Expense
Description FERC Factor Amt to Exclude
FERC 557 - Other Expenses
Charitable Donations & Sponsorships 557 SG 209
FERC 909 - Informational & Instructional Adv
Mise Advertising 909 CN 2,579
Charitable Donations & Sponsorships 909 CN 20,711
Charitable Donations & Sponsorships 909 UT 500
23,790
FERC 920 - Administrative and General
Mise Administrative Costs 920 SO 5,141
FERC 921 - Ofice Supplies & Expenses
Charitable Donations and Sponsorships 921 SO 5,135
Employee Expenses 921 SO (4,417)
Legislative & Lobbyist 921 SO 8,258
Mise Expense 921 SO 3,585
12,561
FERC 923 - Outside Services.Mise Advertising 923 SO 1,151
Charitable Donations 923 SO 746
Grid West 923 SO 750
Scottsh Power 923 SO 19,024
Sublease Tenant Improvement 923 SO 213,647
235,317
FERC 930 - Misc General Expense
Charitable Donations 930 SO 9,225
TOTAL MISC GENERAL EXPENSE REMOVED 286,242
Ref 4.1
.
Rocky Mountain Power PAGE 4.2
Idaho Results of Operations. December 2008.Wage & Employee Benefit - Annualization
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Expense:
Steam Operations 500 2 186,131 SG 5,807%10,809
Steam Operations 500 2 (10)SSGCH 5.663%(1 )
Fuel Related - Non-NPC 501 2 2,560 SE 6.449%165
Steam Maintenance 512 2 123,077 SG 5.807%7,147
Steam Maintenance 512 2 (989)SSGCH 5.663%(56)
Hydro Operations 535 2 22,740 SG-P 5.807%1.321
Hydro Operations 535 2 18,652 SG-U 5.807%1,083
Hydro Maintenance 545 2 4,714 SG-P 5.807%274
Hydro Maintenance 545 2 1,905 SG-U 5.807%111
Other Operations 548 2 13,826 SG 5.807%803
Other Operations 548 2 4,237 SSGCT 6.180%262
Other Maintenance 553 2 4,885 SG 5,807%284
Other Maintenance 553 2 1,265 SSGCT 6.180%78
Other Expenses 557 2 88,689 SG 5.807%5,150
Other Expenses 557 2 95 SSGCT 6.180%6
Transmission Operations 560 2 33,757 SG 5.807%1,960
Transmission Maintenance 571 2 28,435 SG 5.807%1,651
Distribution Operations 580 2 59,221 ID Situs 3,100
Distribution Operations 580 2 133,915 SNPD 4.662%6,243
Distribution Maintenance 593 2 119.913 ID Situs 7,328
Distribution Maintenance 593 2 32.997 SNPD 4.662%1,538
Customer Accounts 903 2 91,085 CN 3.879%3,533
Customer Accounts 903 2 61,681 ID Situs 3.993
Customer Services 908 2 7,440 CN 3.879%289
Customer Services 908 2 69 OTHER 0.000%.Customer Services 908 2 10.124 ID Situs 925
Administrative & General 920 2 8,583 ID Situs 1,563
Administrative & General 920 2 201,378 SO 5.611%11,299
1,260,377 70.858
Description of Adjustment:
The Company has several labor groups, each with different effective contract renewal dates. This adjustment annualizes the wage
increases that occurred during the year for labor charged to operations and maintenance accounts. See page 4.3.1 for more
information on how this adjustment was calculated.
.
Rocky Mountain Power PAGE 4.3Idaho Results of Operations. December 2008.Wage & Employee Benefit. Pro Forma
TOTAL IDAHOACCOUNTTypeCOMPANYFACTOR FACTOR %ALLOCATED REF#Adjustment to Expense:
Steam Operations 500 3 3,585,862 SG 5.807%208,231Steam Operations 500 3 (188)SSGCH 5,663%(11 )Fuel Related - Non-NPC 501 3 49,327 SE 6.449%3,181Steam Maintenance 512 3 2,371.101 SG 5.807%137,690Steam Maintenance 512 3 (19,060)SSGCH 5,663%(1,079)Hydro Operations 535 3 438,092 SG-P 5.807%25,440Hydro Operations 535 3 359,327 SG-U 5.807%20,866Hydro Maintenance 545 3 90,822 SG-P 5.807%5,274Hydro Maintenance 545 3 36,699 SG-U 5,807%2,131Other Operations 548 3 266,368 SG 5,807%15.468Other Operations 548 3 81.624 SSGCT 6.180%5,044Other Maintenance 553 3 94,104 SG 5.807%5.465Other Maintenance 553 3 24,367 SSGCT 6,180%1,506Other Expenses 557 3 1,708,623 SG 5.807%99,220Other Expenses 557 3 1,838 SSGCT 6.180%114
Transmission Operations 560 3 650,342 SG 5.807%37,765Transmission Maintenance 571 3 547,814 SG 5.807%31,812Distribution Operations 580 3 1,140,900 10 Situs 59,728Distribution Operations 580 3 2,579,909 SNPD 4.662%120,280Distribution Maintenance 593 3 2,310.153 10 Situs 141.178Distribution Maintenance 593 3 635,702 SNPD 4.662%29,638Customer Accounts 903 3 1,754,775 CN 3.879%68,064Customer Accounts 903 3 1.188,293 10 Situs 76,934Customer Services 908 3 143,341 CN 3.879%5,560Customer Services 908 3 1,334 OTHER 0,000%.Customer Services 908 3 195.046 10 Situs 17,816Administrative & General 920 3 165.351 10 Situs 30,107Administrative & General 920 3 3,879,595 SO 5.611%217.670
24.281,459 1.365,092
Description of Adjustment:
The Company has several labor groups, each with diferent effective contract renewal dates. This adjustment recognizes
increases that have occurred, or are projected to occur through December 2009. See page 4.3.1 for more information on how
this adjustment was calculated.
.
.
.
.
Rocky Mountain Power
Results of Operations December 2008
Wage and Employee Benefit Adjustment
The unadjusted, annualized (12 months ended December 2008), and pro forma period (12 months ended
December 2009) labor expenses are summarized on page 4.3,2. The following is an explanation
of the procedures used to develop the proforma labor expenses.
1. Actual December 2008 total labor related expenses are identified on page 4.3.2. including bare
labor, incentive, other labor. pensions, benefits, and payroll taxes.
2. Actual December 2008 expenses for regular time, overtime. and premium pay were identified by
labor group and annualized to reflect wage increases during the base period. These annualizations
can be found on page 4.3.3.
3. The annualized December 2008 regular time, overtime, and premium pay expenses were then
escalated prospectively by labor group to December 2009 (see page 4,3.4). Union costs
were escalated using the contractual rates found on page 4.3,5. Non-union costs were escalated
using the budgeted increases.
.4. Miscellaneous non-union incentive payments were escalated at the non-union rate. The Annual
Incentive Plan costs are included at the 2009 budget leveL. Union employees do not participate in
the Company's annual incentive program; instead. they receive annual increases to their wages that
are reflected in the escalation described above.
5. Pro forma December 2009 pension and employee benefi expenses were based on the 2009 budget.
These expenses can be found on page 4.3.7.
6. Payroll tax calculations can be found on page 4.3.8.
Page 4.3,1
.Rocky Mountain Power
Result of Operations December 2008
Wage and Employee Benefit Adjustment.~
5OO1XX
5OO2XX
5OO3XX
500110
5OO5XX
50000
50070050050
50109X
50000
5010
50250
501103
501325
502300
58099
50iiox
501115
5011SX
501160
.
501102
50112X
501175
501200
50122X
501250
501251
501275
501300
5016XX
50290
è':,',~:::;,;;;::==r :.',
405,771,165
59,441,768
5,313,050
470,525,983
836,194
1,980,923
2,122
( 1,852,005)
6,038,594
(1,288,172)
476,243,638
Rela Ordina Timovim
Prium Pay
Subtotal fo esclation
5ear la Adstt
Unuse Le AclTempory/Cotr labor
5eernceRedundancy (1)
Otr salary/labo Co
JO Cutbck
Subttal Bare Labor
Bous
Annul Inctie
Totl Incetie
1,535.130
31,142,229
32,677,359
94,235
121,48186
331,163
(245,082)1,154,661
510,075,658
ovme MeaJont Owne Pen PaymetPhysil Ex
Education Asnc
Mining salaryBet CreitTota. Ot Labor
Subtotal Labor and Incentive
Pesis (2)
SERP Plan
Po Retiret Bets. FAS 106 (2)
Post Emplmet Be - FAS 11
Total Pensions
33,014,96
3.367,024
21.581,023
5,073,226
63,036,237
338.567
49,729,886
2,098,926
194,626
995,965
23.751,629
(n,322)94,743
3,313.324
1,60,948
1,731,523
83,778,815
146,815,051
Pesi AdministMeiclDetaVisi
ure
5toc401(k)/ESOP
401(k) Admlnisti
Actal Deth &. Disability
Lo- Ter DisalitWorers CopesatioOt 5ary OvTotl Benefi
Subtotal Peions and Beefi
34,359,520
3,069,257
37,428,777
694,319,486
202,197,690
492,121,797
580500 Payr Tax Exse
580700 Payr Tax Exseuneplmet
Total Payroll Taxl!
Total Labor
No-lll and capitali La
Total utlit Labor
Annualized
, ';'12 Mitl hi "
, ,Òtii 208 ' ' :
407,198,200
59,650,824
5331736
472.180820
;.~,
1,427.095
209,056
18686
1654 837
Prforma
'îzNåi eå&:!~~Debe 100
418,103,463 10,905,203
61,248,337 1,597,513
5474526 1427904882632612.645505
861,608 22,473
2,041.127 53,238
2,122 -
( 1,852,05)
1 6,038,5~
-
1327323 (346201
490.590.449 126865%
1,588,859 53,730
32067866 92563733656725979367
94.235 -
121,481
864
1~31,163245082
1154 661 -
525401836 13 665 963
32,605,751 (40,212)3,500,00 132,976
16,899,200 (4,681.823)6308913 1235688
59313 865 (3.7223721
778,621 440,054
53,104,691 3,374,80
2,113,488 14,562
287,694 93,068
1,055,514 59,549
41,40,299 17,652,670
390,498 467,820
64,689 (30,05)
3,139,896 (17,428)
3,404,858 1,797,910
1372 852 (3586711
107.117099 23338.285
16643096 19615.913
35,453,621 976,087
3069257
3852 877 976087
730.355.677 34257963
212,692,04 9,976,504
517,663;34 24,281,459
Notes:
(1) No adust is ma to sence bese it Is co in th MEHC Transit Adjustt.
(2) Pesion CurtUrent Gain and Pesion an Poent Meuret Da Oiang efec hav be re. Th ar co In the No-rernng entr adjustt 4.12
.
839,135 2,941
1,987,889 6,967
2,122 -
( 1,852,005)-
16,038,594
-
1292703 (45301
477903853 1660215
1,535,130
31142229 -
32.677 359 -
94,235 -
121,48186 -
331,163 -
1245082
1154 661 -
511 735 873 1660215
33,014,96 -
3,367.024
21,581,023
5073 226
63,036 237 .
338,567 -
49,729,886 -
2,09,926 -
194,626
995,965
23,751,629 -
(77,322)-
94.743 -
3.313,324 -
1,60,948 -
1731523 -
83 778 U5 -
146 815051 -
34,477,533 118,013
3069257 -
37546790 118013
6%097714 1778,228
202.715,540 517,850
493,382.174 1,260,377
Pa 4.2 Pag 4.3
Page 4.3.2
Ro.
4.3.3
4.3.3
4.3.3
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Page 4.3.7
Rocky Mountain Power
Results of Operations December 2008
Wage and Employee Benefit Adjustment
50110X Pensions - FAS 87 33,014,96 34,122,94 33,700,000 32,605,751 (409,212)4,3.2
S01115 SERP Plan 3,367,024 3,367,024 3,500,000 3,500,000 132,976 4.3.2
SOl1SX Post Retrement Benefi - FAS 106 21,581,023 22,220,567 17,400,000 16,899,200 (4,681,823)4.3,2
501160 Post Employment Beefits - FAS 112 5,073,226 5,226,886 6,500,000 6,308,913 1,235,688 4.3.2
Subtotal 63,036,237 64,937,422 61,100,000 59,313,865 (3,722,372)4.3.2
501102 Pension Administration 338,567 346,559 797,000 778,621 44,054 4.3.2
50112X Medical 49,729,886 51,411,103 54,900,00 53,104,691 3,374,805 4.3.2
501175 Dental 2,098,926 2,184,842 2,200,000 2,113,488 14,562 4.3.2
S01200 Vision 194,626 202,951 300,000 287,694 93,068 4.3.2
S0122X ute 995,965 1,037,941 1,100,000 1,055,514 59,549 4,3.2
501250 5tok/40 l(k)/ESOP 23,751,629 24,380,179 42,50,00 41,404,299 17,652,670 4.3.2
501251 401(k) Administration (77,322)(79,798)403,000 390,498 467,820 4.3,2
501275 Acddental Death & Disabilty 94,743 95,199 65,000 64,689 (30,054)4.3.2
S01300 Long- Term Disabilit 3,313,324 3,413,681 3,235,00 3,139,896 (173,428)4.3,2
S016XX Worker's Compensation 1,606,948 1,651,851 3,500,000 3,40,858 1,797,910 4.3.2
502900 Oter salary Overhead 1,731,523 l.34,232 1,375,000 1,372,852 (358,671)4.3.2
Subtotal 83,778,815 86,378,740 110,375,00 107,117,099 23,338,285 4.3.2
Grand Total 146r815,051 151,316,162 171,475,000 166,430,964 19,615,913 4.3.2
.
.
.
Rocky Mountain Power
Results of Operations December 2008
Wage and Employee Benefit Adjustment
Payroll Tax Adjustment Calculation
FICA Calculated on Annualized December 2008 Labor
Annualized Wages Adjustment
Annualized Incentive Adjustment
Total Labor 12 Months Ended Decem ber 2008
Medicare Rate (no cap)
Social Security Rate
Percentage of Social Security Eligible Wages
Total FICA Tax
FICA Calculated on December 2009 Pro Forma Labor
Pro Forma Wages Adjustment
Pro Forma Incentive Adjustment
Total Pro Forma Wage Increase
Medicare Rate (no cap)
Social Security Rate
Percentage of Social Security Eligible Wages
Total FICA Tax
Page 4,3,8
Reference
1,660,215 4.3.2
1,660,215
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24,073
6.20%
102,933
91.26%
93,940
118,013 4.3.2
12,686,596 4.3,2
979,367 4.3.2
13,665,963
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6.20%
847,290
91.81%
777,931
976,087 4.3.2
.
.
.
Rocky Mountain Power
Idaho Results of Operations - December 2008
MEHC Transition Savings
PAGE 4.4
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Expense:
Remove expense credited at WY reg asset set-up 920 4,780,000 SO 5,611%268,188
Adjustment to Tax:
Sch M Adjustment SCHMDT 1 (10,308,150)SO 5.611%(578,353)
Sch M Adjustment SCHMDT 1 (610,194)ID Situs (610,194)
Sch M Adjustment SCHMDT 1 (2.655,556) WY-ALL Situs
Deferred Tax Expense 41010 1 (3,912,046)SO 5.611%(219,491)
Deferred Tax Expense 41110 1 231,575 ID Situs 231,575
Deferred Tax Expense 41010 1 (1,007.810) WY-ALL Situs
Deferred Tax Balance 190 1 (2.268,035)SO 5.611%(127,251)
Deferred Tax Balance 283 1 578,937 10 Situs 578,937
Deferred Tax Balance 283 1 503,905 WY-ALL Situs
Description of Adjustment:
The Company eliminated many positions as a result of the MEHC transaction. These savings were made possible by the payment
of Change-In-Control Severance. It is being amortized into expense over a three-year period on the books of the Company as
authorized by the Commission in Docket No. PAC-E-07-05. Since the amoritzation is included in unadjusted results, the only entry
necessary is the correction of the set-up of the Wyoming MEHC CIC severance regulatory asset in January 2008.
.
.
.
Rocky Mountain Power
Idaho Results of Operations. December 2008
Irrigation Load Control Program
PAGE 4.5
TOTAL IDAHO
ACCOUNT ~ COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Other Purchased Power
Other Purchased Power
(6.005,556) SG
6.005,556 10
5,807%
Situs
(348,743) 4.5.1
6.005,556 4.5.1
5.656,813
1
1
557
557
Description of Adjustment:
Payments made to Idaho irrgators as part of the Idaho Irrgation Load Control Program are system allocated in the
unadjusted data. This adjustment situs assigns the payments to Idaho. The reallocation is required as DSM costs
are situs assigned to the states in which the costs are incurred to match the benefit of reduced load reflected in
allocation factors.
.
.
.
Rocky Mountain Power
Account NO. 514511
DSM . Irrigalion Load Control Page 4.5.1
ilsilliø æi&iø el ¡ &l~_.fo.,.I.JRÊ~'ž..;
AprOl
June 08
July 08
Aug 08
5ep08
Oet08
Nov 08
De 08
(2.55)
1,836,060.90
1,838,877.01
1,838,661.36
1.024,931.48
(543.388.89)
12,971.76
(2.55.34)
TOl2OD8 6.005.555.73
Ref. 1#.5
.
.
Energy Trust of Oregon (ETO) Credit:
Reverse ETO Credit in 2008 549
ETO credit in 2008 (Oregon Only) 557
795,591 SG
(795,591) OR
5.807%
Situs
46,200 4.6.13
3
Description of Adjustment:
This adjustment annualizes the O&M expense of the Goodnoe Hils wind plant, Marengo /I wind plant, and the
Chehalis gas plant which were placed into service May 2008, June 2008, and September 2008 respectively. This
adjustment also adds incremental operation and maintenance expenses for generating units that were not in
service during the 12 months ended December 2008 but wil be in service during the 12 months ended December
2009.
Funding received from the Energy Trust of Oregon related to the Goodnoe Hils plant is removed from results.
.
.
.
Rocky Mountain Power
Results of Operations. December 2008
Incremental Generation O&M
Chehalis
Marengo II
Goodnoe Hils
BPACredit
Glenrock
Seven Mile Hil
Rollng Hils
Glenrock III
Seven Mile Hil ii
High Plains
Administration
Total:
Jan 08 . Dec 08
1,689,000
960,410
1,039,270
(564,500)
o
o
°
°
o
°
612,270
3,736,450
Jan 09 . Dec 09
5,603,000
2,195.000
2,360,000
°
1,518,000
1,576.00
1,515,00
608,000
356,000
461,000
889,000
17,081,000
Page 4.6.1
Variance
3,914,000
1,234.590
1,320,730
564,500
1,518,000
1,576,00
1,515,00
608,000
356,000
461,000
276,730
13,34.550 Refer 4.6
Oregon Energy Trust Fund Credit. (795,591) ° 795,591
. These credits wil be applied against the Oreon allocated operation and maintenance expense of the Goodnoe Hils wind plant in 2008.
In unadjusted results the credit was incorrectly recorded on a sysem basis instead of an Oregon only amount.
Rocky Mountain Power PAGE 4.7.Idaho Results of Operations - December 2008
Remove Non-Recurring Entries
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
1) MCBIT Refund 903 (270,691 )OR Situs 4.7.1
2)Sandy Training Center O&M 931 1 (18,750)SO 5,611%(1,052)4.7.1
3) Pension Curtailment 920 1 2,338,769 10 Situs 2,338,769 4.7.1
TOTAL Non-recurring Adjustments 2,049,328 2,337,717
Adjustment to Tax:
3) Accum Def Inc Tax Balance 283 1 74,818 10 Situs 74,818
.
.
Description of Adjustment:
A variety of accounting entries were made to expense accounts during the twelve months ended December 2008
that are non-recurring in nature or relate to a prior period. These transactions are removed from results of
operations to normalize the test period results. A description of each item is provided on page 4.7.1.
.
.
.
Page 4.7.1
Rocky Mountain Power
Results of Operations - December 2008
Remove Non-Recurring Entries
~Postg Date I Text I FERC Acctl Amount as Booked I Reference I
MCBIT Refund: In September 2007 the I
I
Company reached agreement on a final refund
amount for Multnomah County Business
Income Tax colleced from customers since
1993.
As a result of the settlement, the Company set
1 Mar '08
aside $2.2 milion to cover the customer refund,9032000 270,691 Ref 4.7 attorneys fees, and other costs of the
settlement. The Company made an entry in
March 31, 2008 to increase a previously
accrued reserve.
This adjustment reverses the impact of that
entry on regulated results. All other associated
settlement expenses were booked and
removed in prior periods.
Sandy Training Center:The O&M expense
associated with the Sandy Training Center
facilties lease was decreased from $75,000 to
2 Jan'08 - Mar'08 $25,000 on an ongoing basis starting April 9310000 18,750 Ref 4.7
2008.
This adjustment removes $18.750 from the
historical period for the expenses related to the
prior contract amount.
1($6,250 * 3 months = $18.750)
Pension Curtailment: Idaho is on a cash
basis for pension expense. This entry is related
3 Dec '08 to the actuarial effects of pension curtailment 9200000 (2,338,769)Ref 4.7 and measurement date change and was
incorrectly assigned to Idaho in the unadjusted
results.
Total (2,049,328) Ref 4.7
.
.
.
Rocky Mountain Power
Idaho Results of Operations. December 2008
Affilate Mgmt Fee (MEHC)
PAGE 4.8
Adjustment to Expense:
ACCOUNT Type
TOTAL
COMPANY
IDAHO
FACTOR FACTOR % ALLOCATED REF#
Operation & Maintenance expens,930 1 (1,379,610) SO 5.611%(77,405)
Adjustment Detail
MEHC Management Fee Limit per Commitment 9
MEHC Mangement Fee Booked above the line - 12 me
Adjustment Required
7,300,000
(8,679,610)
(1,379,610)
Description of Adjustment:
In merger Commitment No.9, the Company committed to hold customers harmless for costs that were
previously assigned to affliates relating to management fees and set the total company amount at $1,500,000.
This commitment is offsettable to the extent PacifiCorp demonstrates to the Commission's satisfaction that
corporate allocations from MEHC to PacifiCorp included in PacifiCorp's rates are less than $7.3 milion, This
adjustment limits Corporate allocations from MEHC included in rates to the $7.3 milion limit.
.
.
.
Rocky Mountain Power
Idaho Results of Operations. December 2008
Preliminary Plant Expense
ACCOUNT ~
TOTAL
COMPANY
PAGE 4,9
IDAHO
FACTOR FACTOR % ALLOCATED REF#
SG 5.807%(23,532) 4,9.1
Adjustment to Expense:
Preliminary Plant Expense 557 1 (405,235)
Description of Adjustment:
The Company looked into additional generation projects, including recovered energy generators at compressor
stations along the Kern River pipeline. After these projects were abandoned by the Company, the expenses
incurred for these projects were written off to FERC account 557, This adjustment removes these write-offs and the
associated O&M expenses from regulatory results of operations.
.
.
.
Rocky Mountain Power
Results of Operations - December 2008
Preliminary Plant Expense
Project
Kern River Recovered Energy Generators
Total Adjustment
GIL Account
545990
Entry Date
8/31/2008
Ref Doc Number Cost Center
116002643 10200
Page 4.9.1
Total
405,235
405,235
Rocky Mountain Power PAGE 4.10.Idaho Results of Operations.December 2008
Advertising
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Advertising Campaign 909 1 (307,628)CN 3.879%(11,932)
General Rate Case Advertising 909 1 (148,176)CN 3.879%(5,747)
General Rate Case Advertising 909 1 18,043 CA Situs
General Rate Case Advertising 909 1 20,731 OR Situs
General Rate Case Advertising 909 1 15,133 WA Situs
General Rate Case Advertising 909 1 1,250 UT Situs
General Rate Case Advertising 909 1 3,165 10 Situs 3,165
General Rate Case Advertising 909 1 89,854 WY-ALL Situs
(2,582)
.
Description of Adjustment:
In December 2008, charges for the production of the new customer awareness campaign were charged to FERC
account 909. After reviewing the advertisements for the new campaign, it was determined some of the ads should not
be included in regulatory results. This adjustment removes the production expenses that relate to the below the line
advertisements,.
This adjustment also removes general rate case advertising that was allocated system and assigns the costs directly
to the jurisdiction the advertising was for.
.
.
.
Rocky Mountain Power
Results of Operations - December 2008
Advertising Adjustment
Description
CONCEPTING
IMAGE CAMPAIGN:30 RADIO
SAFETYEFFICIENCY CAMPAIGN-.30 TV
CUSTOMER-AWARENESS:15 TV-SAFETY, EFFICIENCY
CUSTOMER AWARENESS:30 TV-SAFETY, EFFICIENCY
CONCEPTING-CUSTOMER AWARENESS CAMPAIGN
PLANNING/NEW CAMPAIGN-CUSTOMER AWARENESS
SAFETY, EFFICIENCY, SERVICE CAMPAIGN:15 TV
Customer awareness campaign :30 TV
Customer awareness campaign :30 Radio
Customer Awareness Campaign Pnnt Ads
CUSTOMER AWARENESS CAMPAIGN INTERNAL LAUNCH
CUSTOMER AWARENESS CAMPAIGN:30 RADIO
CUSTOMER AWARENESS INTERNAL LAUNCH
Internal Launch Screensaver
Internal Launch Thumb Drive card
Internal Launch President's letter
Pat Reiten OIT Video
Internal launch Window decals
Internal Launch Launch posters
Internal launch Laminated card
Internal launch Emails for customer awareness
Riester-Banners
Riester-Renewables
Riester-Renewables
Riester-Regulation
Riester-UT rates
Riester-UT rates
Riester-UT rates
CUSTOMER AWARENESS PROJECT ACTIVATION
PACIFICORP PROMO PRODUCTS (ESTORE)
PACIFICORP PROMO PRODUCTS (ESTORE)
Document No.
1012798586
1012885339
1012913207
1012913208
1012913209
1012913212
1012913213
1012953885
1013027743
1013027746
1013027747
1013033394
1013034496
1013034527
1013039407
1013039408
1013039410
1013039414
1013044867
1013044868
1013044870
1013044872
1013043807
1013043807
1013043807
1013043807
1013043807
1013043807
1013043807
1013044905
1013045931
1013045931
Page 4.10.1
Postg Date Amount
10/31/2008 2,852
11/19/2008 7,952
11/25/2008 23,934
11/25/2008 2,276
11/25/2008 23,934
11/25/2008 7,849
11/25/2008 2,513
1212/2008 3,277
12126/2008 29,39512126/2008 4,873
12/26/2008 2,285
12/29/2008 4,242
12129/2008 4,255
12/29/2008 62,293
12/31/2008 2,192
12/31/2008 959
12131/2008 5,299
12131/2008 3,634
12/31/2008 5,364
1213112008 5,891
12/31/2008 1,781
1213112008 5,960
12/31/2008 822
12/31/2008 227
12/31/2008 6,987
12/31/2008 891
1213112008 4,14412131/2008 1,370
12/31/2008 10,006
12131/2008 12,604
12131/2008 25,000
12131/2008 32,568
307,628
Page 4.10
.
.
.
Rocky Mountain Power
Idaho Results of Operations - December 2008
Compliance Department
PAGE 4.11
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Operation Supervision & Engineering 560 3 306,706 SG 5.807%17,810
Load Dispatching 561 3 (81,322)SG 5.807%(4,722)
Operation Supervision & Engineering 580 3 106,275 SNPD 4.662%4,955
Load Dispatching 581 3 (89,339)SNPD 4.662%(4,165)
Maint Supervision & Engineering 590 3 70,220 SNPD 4.662%3,274
Maint of Station Equipment 592 3 137,543 SNPD 4.662%6,413
Offce Supplies & Expenses 921 3 (84,522)SO 5.611%(4,742)
Total 365,561 18,822 4.11.1
Description of Adjustment:
On June 18, 2007 the FERC approved enhanced compliance requirements imposed by the North American Reliabilty
Corporation (NERC). Utilties and other bulk power industry participants that violate any of the new standards wil face
enforcement actions including possible sanctions of up to $1,Om a day, in addition to potentially more rigorous
compliance monitoring and testing requirements.
In order to comply with the enhanced reliabilty standards as of December 2008, the Company has hired 11 and plans to
hire an additional 2 full-time employees. This adjustment brings the costs for these employees to the level expected in
2009,
.
.
.
Rocky Mountain Power
Compliance Expenses
December 2009
Department
Main Grid Planning
Finance
Transmission Development Planning
Account
560
560
560
Total Account 560
Transmission & Distribution Operations 561
Transmission & Distnbution Operations 580Finance 580
Total Account 580
Transmission & Distnbution Operations 581Finance 581
Total Account 581
590
592
921
921
921
Investment Planning
Transmission & Distnbution Operations
General Counsel
Physical Secunty
Finance
Total Accunt 921
Total
12 Months
Ending
12131/2009
769,820
62,700
1.716,670
2,549,190
134,640
55,440
67.575
123,015
117,480
202.000
319,480
97,870
211,111
269,525
84,000
8,475
362,000
3,797,306
Page 4.11.1
Actual
Jan-Dec
12131/08 Adjustment
2,242,484 306,706
215,962 (81.322)
16,740 106,275
408,819 (89,339)
27,650 70,220
73,568 137,543
446,522
3,431,745
(84.522)
365,561 Pg 4.11
.
.
.
Rocky Mountain Power
Idaho Results of Operations - December 2008
Insurance Expense
PAGE 4.12
Adjustment to Expense:
Injuries and Damages
ACCOUNT ~
TOTAL
COMPANY
IDAHO
FACTOR FACTOR % ALLOCATED REF#
SO 5.611%28,310 4.12.19253504,575
Description of Adjustment:
This adjustment normalizes injury and damages expense to reflect a three year average of gross expense
minus insurance receivables. This adjustment also examines the level of captive insurance expenses which wil
remain below $7.4 milion as agreed to by the company as part of the MEHC transaction as stated in Idaho
Docket No. PAC-E-05-08, commitment 129.
Page 4.12.1.Rocky Mountain Power
Results of Operations. December 2008
Insurance Expense
Excluding Auto (280311)2.107,448 8.990.118
293,998 1,084,570
25,000 50.000
2,426,446 10,124,688
0 (4,717,560)
2,426,446 5,407,128
Jan. Dec 2008 Totals
Accrual Accrual
8,157,958 19,255,525
292,375 1,670,943
50,000 125,000
8.500.333 21,051,467
(5,340,408)(10.057,968)
3,159,925 10,993,499
3,664,500
Jan - Dec 2006 Jan. Dec 2007
Accrual Accrual
Auto (280312)
Construction (280313)
* Receivable
Net - Accrual Minus Receivable
3 Year Average
* A receivable is established at the time the reserve analysis (accrual) for a given incident goes above the
insurance deductible. These monies are not received until after the incident is settled, paid. At that time a claim
is submitted to insurance company
Adjustment Detail:
Base Year Expense $8,500.333.Minus Insurance Receivable (5,340,408) Above
Net Base Year Expense. Cost Center 13272 $3,159,925
3 Year Average - Accrual Basis $3,664,500 Above
Regulatory Adjustment $504,575 Pg 4.12
.
.
.
.
Rocky Mountain Power
Idaho Results of Operations. December 2008
A&G Cost Commitment (MEHC)
PAGE 4,13
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Administrative and General 930 3 (225,623)10 Situs (225,623) 4.13.2
Tax Adjustment
Accum Def Income Tax Balance 190 1 (214,065)10 Situs (214,065)
Schedule M Deduction SCHMDT 1 (225,623)10 Situs (225,623)
Deferred Income Tax Expense 41010 1 (85,626)10 Situs (85,626)
Description of Adjustment:
The current normalized A&G expense is below the MEHC Merger Commitment as stipulated in the Idaho
commitment 131. Therefore, no adjustment is necessary. This adjustment also reflects Idaho's share of the
$500,000 per month administrative and general expense deferred savings due to the MEHC merger. The savings
is being amortized over the 3 years starting January 1, 2008.
4.13.1.Rocky Mountain Power
Results of Operations. December 2008
A&G Expense Cost Commitment
Description Account (s)Total Company Code Allocation %Idaho Ref. #
Decmber 2008 Actual Administrative and General Expense 170,044,138 Various Various 7,316,882 2.2
A&G Adjustments:
Miscellaneous General Expense 920 (5,141)SO 5.611%(288)4.1
Miscellaneous General Expense 921 (12,561)SO 5.611%(705)4.1
Miscellaneous General Expense 923 (235,317)SO 5.611%(13,203)4.1
Miscellaneous General Expense 930 (9.225)SO 5.611%(518)4.1
Wage and Employee Benefits. Annualization 920 8,583 \0 100.000%1,563 4.2
Wage and Employee Benefis. Annualization 920 201,378 SO 5.611%11,299 4.2
Wage and Employee Benefits - Pro Forma 920 165,351 10 100.000%30,107 4.3
Wage and Employee Benefits. Pro Forma 920 3,879,595 SO 5.611%217,670 4.3
MEHC Transition Savings 920 4,780,000 SO 5.611%268,188 4.4
Non-Recurrng Expense 923 (18,750)SO 5.611%(1,052)4.7
Non-Recurrng Expense 920 504,575 10 100.000%28,310 4.7
Affliate Management Fee 930 (1,379,610)SO 5.611%(77,405)4.8
Compliance Expense 921 (84,522)SO 5.611%(4,742)4.11
Insurance Expense 925 SO 5.611%4.12
A&G Cost Commitment 930 (225,623)\0 100.000%(225,623)4.13
Membership & Subscriptions 930 178,175 SO 5.611%9,997 4.15
Idaho Intervenor Funding 928 (11,285)10 100.00%(11,285)4.16
Idaho Pension Expense Cash Basis 930 15,297.572 SO 5.611%858,291 4.17
West Valley Lease 930 (218.926)10 100.000%(218,926)5.2
Total A&G adjustments 22,814,268 871,678
Adjusted A&G Expense 192,858,406 8,188,560 2.2
Required Adjustment.
.
Total normalized A&G Expense was below the A&G Cost Commitment as stipulated in Idaho Merger Commitment 131.
Therefore, no adjustment is necessary.
Normalized A&G Cost Commitment Level
Cap Commitment per Docket No. PAC-E-05-08, Commitment No. I 31
Escalation % Increase
222,800,000
12.23%
December 2009 A&G Cost Commitment 250,043,099
Jan-09 18,802 (432,443)
Feb-09 18,802 (413,641)
Mar-09 18,802 (394,839)
Apr-09 18,802 (376,038)
May-09 18,802 (357,236)
Jun-09 18,802 (338,434)
Jul-09 18,802 (319,632)
Aug-09 18,802 (300,830)
Sep-09 18,802 (282,028)
Oct-09 18,802 (263,226)
Nov-09 18,802 (244,424)
Dec-09 18,802 (225,623)
lOne Year Amortization 225,623 4.13 i
.Rocky Mountain Power
Results of Operations - December 2008
Deferral and Amortization of MEHC A&G Commitment
Amortize over 3 years beginning January 2008
Amortization
Dec-07
Jan-08
Feb-08
Mar-08
Apr-08
May-08
Jun-08
Jul-08
Aug-08
Sep-08
Oct-08
Nov-08
Dec-08
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
.~,
Jan-10
Feb-10
Mar-10
Apr-10
May-10
Jun-10
Jul-10
Aug-10
Sep-10
Oct-10
Nov-10
Dec-10
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
18,802
,.
Page 4.13,2
Unamortized
Balance Ref#
(676,868)
(658,066)
(639,264)
(620,462)
(601,660)
(582,858)
(564,056)
(545,254)
(526,453)
(507,651)
(488,849)
(470,047)
(451,245)
(206,821)
(188,019)
(169,217)
(150,415)
(131,613)
(112,811)
(94,009)
(75,208)
(56,406)
(37,604)
(18,802)
(0)
.
.
.
Rocky Mountain Power
Idaho Results of Operations - December 2008
Generation Overhaul
Adjustment to Expense:
Generation Overhaul Expense - Steam
TOTAL
ACCOUNT Type COMPANY
PAGE 4.14
IDAHO
FACTOR FACTOR %ALLOCATED REF#
SG 5,807%489,455 4,14.1
SG 5.807%489,455 4,14.1
978.909
Description of Adjustment:
This adjustment normalizes generation overhaul expenses in the year ended December 2008 using a four year
average methodology. In this adjustment overhaul expenses from December 2005 to December 2007 are escalated to
a December 2008 level using Global Insight indices and then those escalated expenses are used in computing a four
year average. For new generating units, which include Currant Creek, Lake Side and Chehalis, the four year average
is comprised of the overhaul expense planned for the first four years these plants are operationaL. The actual overhaul
costs for the year ended December 2008 are subtracted from the four year average which results in this adjustment.
510 1 8,428,699
5,915,472
14,344,171
Generation Overhaul Expense - Other 553 1
.
.
.
Rocky Mountain Power
Results of Operations - December 2008
Generation Overhaul Expense
FUNCTION: OTHER
Period
CY 2005
CY 2006
CY 2007
CY 2008
4 Year Average
Overhaul Expense
545,000
2,940,000
2,860,000
1,725,000
2,017,500
New Plant Overhaul Expense
Lake Side Plant - 4 Year Average
Currant Creek Plant - 4 Year Average
Chehalis Plant - 4 Year Average
Total New Plant Overhaul Expense
Total 4 Year Average - Other
Year Ending December 2008 Overhaul Expense - Other
Total 4 Year Average - Other
Adjustment
*Escalation Rates: Ref 4.14.3
FUNCTION: STEAM
Period
Year Ending December 2005
Year Ending December 2006
Year Ending December 2007
Year Ending December 2008
4 Year Average
Overhaul Expense
25,845,753
29,613,264
28,560,541
20,030,017
26,012,394
Year Ending Dec 2008 Overhaul Expense - Steam
Total 4 Year Average - Steam
Adjustment
*Escalation Rates: Ref 4.14.3
Page 4.14.1
Escalation Rates
to Dec 2008 * Escalated Expense14.50% 624,0049.25% 3,211,8205.50% 3,017.300
1,725,000
2,144,531
1,110,750
3,113,191
1.272,000
5,495,941 Ref4.14.2
7,640,472
1,725,000 Ref4.14.2
7,640,472
5,915,472 Ref 4.14
Escalation Rates
to Dec 2008 * Escalated Expense16.53% 30,118,71611.32% 32,965,7097.56% 30,720,420
20,030,017
28,458,716
20,030,017 Ref 4.14.2
28,458,716
8,428,699 Ref4,14
4.14.2
.Rocky Mountain Power
Results of Operations. December 2008
Generaion Overhaul Expense
Existing Units
Calendar calendar Calendar Calendar
Yr 2005 Yr2006 Yr 207 Yr 2008
By Plant
Blundell 73,934 2,677,913 83,913
Carbon (113,331)723,024 24,146 1,730,915
DaveJohnston 5,255,000 30,900 3,279,981 5,824,658
Gadsby
Hunter 6,916,750 3,910,432 8,171,859 (950,900)
Huntington 6,533.00 7,575,000 (39,000)
JimBridger 5,846,000 5,904,000 6.815,000 4,427,00
LiltleMt 139,000
Naughton 1,348,33 3.648.974 4,864,643 1,341,431
WVailey
Wyodak 5,629,000
Camas 418,000
Cholla 6,460,000
Colstrip 925,00 1,300,000
Craig 60,000 448,000 1,376,000 743.000
Hayden 745,000 90,000 370,00
Hermiston 545,000 2,383,000 2,860,000 1,725,000 Ref. 4.14.1
Total 26,390,753 32,553,264 31,420.541 21,755,017
By Function
Steam 25,845,753 29,613,264 28,560,541 20,030,017 Ref. 4.14.1
Other 545,000 2,940,000 2,860,00 1,725,000
Total $26,390,753 $32,553,264 $31,420,541 $21,755,017
New Generating Units'
Actual Budget
Calendar Calendar Calendar Calendar Calendar Calendar
Yr2007"Yr2008 Yr 2009 Yr 2010 Yr 2011 Yr 2012.Currant Creek 1,606,765 1.216.000 8,403,000 1,227,000
Lake Side 544,000 624,000 2,629,000 646,00
Chehalis 171,000 2,008,000 250,000 250,000 2,580.000
Ref. 4.14.1
'Currnt Crek LakeSide & Chehalis are both Funcon. Other
-2007 Currnt Creek figure is escalated to the December 2008 level using escalation factors.
.
.
.
.
Rocky Mountain Power
Results of Operations. December 2008
Generation Overhaul Expense
Escalation Rates: OTHER
Escalation Rate to December 2008
Escalation Rates: STEAM
Escalation Rate to December 2008
~
14,50%~
16.53%
CY06
9,25%
CY06
11.32%
CY07
5.50%
CY07
7.56%
~
CY08
Page 4.14,3
.
.
.
Rocky Mountain Power
Idaho Results of Operations. December 2008
Memberships & Subscriptions
PAGE 4,15
Adjustment to Expense:
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Miscellaneous General Expense 178,175 SO 9,997 4.15.15.611%930 1
Description of Adjustment:
This adjustment removes expenses in excess of Commission policy allowances as stated in Idaho Power's
Order No. 29505. National and regional trade organizations are recognized at 75%. Fees for WECC and
Northern Tier Transmission Group are included at 100%.
.Page 4.15.1
Rocky Mountain Power
Results of Operations. December 2008
Memberships and Subscriptions Adjustment Breakdown
Account Description
Remove Total Memberships and Subscnptions in Accunt 930.2930,2 SAP Extact
Amount
(4,451,908)
National and Regional Trade Membership Allowances
.
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
930.2
Associated taxpayers of Idaho inc
Consortium for energy effciency
E source companies IIc
Electnc Power Research Institute
Idaho mining association
Intermountain Electncal Assoc
National coal trnsportation assoc
National automated c1eanng house
National Electric Energy Testing Research and Applications Center
National joint utilties
Nextgen energy council inc
Norwest power and conseNation
One-ll of Wyoming
Oregon business association
Oregn business council
Oregon joint use association
Pacic Nortwest Utilities Conference Committee
Portand business allance
Rocky Mountain Electrical League
Utah foundation
Utah manufacturers association
Utah taxpayers association
Western Energy Institute
Edison Elecmc Institute
3e Strategies
Breakfast Exchange Club
Fremont county utilty council
Greater Gateway Boosters
IESNA
Klamath Forest Protective Association
Unn-Benton utilties
Power Quality SeNice Center
Western Lampac
850
13,120
13,220
433,353
6.000
9.000
1,250
4,500
97,500
7.875
50,000
15.000
400
11,000
30,059
2.700
50,302
39,250
18,000
22.500
6,000
20,000
40,000
45,750
600
400
100
123
500
9
175
10.000
2.000
951,536Total Memberships Allowances:
713.652Add Back Ordered Memberships at 75%
Add Membership Fees ~ 100%
930.2 Western Electricity Coordinating Council
930.2 Nortern tier trnsmission group
Total Adjustment
3.586,673
329,757
178.175
.
.Rocky Mountain Power
Idaho Results of Operations - December 2008
Idaho Intervenor Funding
PAGE 4.16
Adjustment to Expense:
Misc. General Expense
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
928 3 (11,285)10 Situs (11,285) 4.16.1
Adjustment to Rate Base:
Deferred Regulatory Expense 182M 3 (5,642)10 Situs (5,642) Below
Adjustment to Tax:
Schedule M SCHMDT 3 (17,580)10 Situs (17,580)
Schedule M SCHMDT 1 (6,296)10 Situs (6,296)
Deferred Tax Expense 41010 1 (2,389)10 Situs (2,389)
Deferred Tax Expense 41010 3 (6,672)10 Situs (6,672)
Accum, Oef. Tax Balance 283 3 2,142 10 Situs 2,142
Adjustment Detail:
Dec 2007 Balance 28,865 4.16.1
Dec 2008 Balance 35,160 4.16.1
Dec 2008 Average Balance 32,013.Dec 2008 Balance 35,160 4.16.1
Dec 2009 Balance 17,580 4.16.1
Dec 2009 Average Balance 26,370
Incremental adjustment to rate base (5,642)
.
Description of Adjustment:
This adjustment amortizes $35,160 of intervenor funding awarded to CAPAI and the Idaho Irrigation Pumpers
Association, as ordered in Case No. PAC-E-07-05 over a period of two years. Amortization expense is increased by
the expected amortization amount in calendar year 2009 and rate base is adjusted to reflect an average balance as
of calendar year 2009.
.Rocky Mountain Power Page 4.16.1
Results of Operations. December 2008
Idaho Intervenor Funding Adjustment
Amortization Schedule & Balance Timeline
Monthly Annual
Date Activity Amortization Amortization Explanation of Activity Balance Ref
Nov-05 27,938 CAPAI & Irrigation Funding 27,938
Dec-05 27,938
Jan-06 27,938
Feb-Q 27,938
Mar-06 27,938
Apr-D6 27.938
May-D6 27.938
Jun-D6 27,938
Jul-D6 27,938
Aug-D6 27,938
Sep-06 27,938
Oct-06 27,938
Nov-Q 27,938
Dec-06 27,938
Jan-7 927 CAPAI Funding 28,865
Feb-D7 28,865
Mar-07 28.865
Apr-D7 28,865
May-D7 28,865
Jun-07 28,865
Jul-07 28.865
Aug-07 28.865
Sep-D7 28,865
Oct-D7 28.865
Nov-D7 28,865
Dec-07 28,865 Ref 4.16.1
Amortize Nov 2005 & Jan 2007 CAPAI &.Jan-D8 35,160 (2,405)Imgation Funding (1 year)61,620
Feb-08 (2,405)59.214
Mar-08 (2,405)56,809
Apr-08 (2,405)54,403
May-D8 (2,405)51,998
Jun-D8 (2,405)49,593
Jul-08 (2,405)47,187
Aug-D8 (2,405)44,782
Sep-08 (2.405)42.376
Oct-D8 (2,405)39.971
Nov-08 (2,405)37,565
Dec-D8 (2,405)(28.865 35.160 Ref 4.16.1
Amortize Jan 2008 CAPAI & Imgator Funding (2
Jan-D9 (1,465)years)33,695
Feb-09 (1,465)32,230
Mar-D9 (1,465)30,765
Apr-09 (1,465)29,300
May-D9 (1,465)Ref 4.16 27,835
Jun-D9 (1,465)Difference = 11,285 26.370
Jul-D9 (1,465)24.905
Aug-09 (1,465)23,440
Sep-9 (1,465)21.975
Oct-D9 (1,465)20,510
Nov-D9 (1,465)19,045
Dec-D9 (1,465)(17,580)17.580 Ref 4,16.1
Jan-10 (1,465)16,115
Feb-10 (1.465)14,650
Mar-10 (1.465)13.185
Apr-10 (1,465)11,720
May-10 (1,465)10,255
Jun-10 (1,465)8,790
Jul-10 (1.465)7,325
Aug-10 (1,465)5.860
Sep-10 (1,465)4.395
Oct-10 (1,465)2.930.Nov-10 (1,465)1,465
De-10 (1,465)(17,580)0
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Rocky Mountain Power
Idaho Results of Operations - December 2008
ID Pension Expense Cash Basis
PAGE 4.17
TOTAL IDAHO
ACCOUNT ~ COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Pension expense 1 15,297,572 SO 5.611%858,291 4,17.1930
Description of Adjustment:
This adjustment replaces the actuarially determined pension expense for the 12 months ended December 2009
with the forecasted amount funded (cash basis).
.
.
.
Rocky Mountain Power
Results of Operations. December 2008
Convert Actuarial Pension Expense to Cash Basis
Cash Basis Pension Expense
Pension Funding 12 Mos Ended December 2009
Portion to exclude Mines
49,564,280
97.06%
48,107,194
96.75%Portion to exclude Joint Ventures
Pension Funding to Electric Expense
Accrual Basis Pension Expense
Actuarial Pension Expense in Results 12 Mos Ended December 2009
Electric Portion
Electric Expense in Results
25,800,000
96.75%
Total Difference
O&M portion
Adjustment to O&M
Page 4,17.1
46,545,140
24,962,267
21,582,873
70.88%
15,297,572 Ref4.17
IDAH REVISD PROTOCOl Page 5.0 Total
Net Powr Cost Adjustments (Tab 5)
TOTAL
5.1 5.2 5,3 5.4 5.5 5.6 0.James River
Royalt Ofet I Electc Lake BPA Residential
Totl Noalized NPC T3 Study West Valley LElse UlleMtn Gren Tag Sellement Exchange 0
1 Oprating Revenues:
2 General Business Revenues
3 Interdeørtental
4 Speial Sales 10,095,239 10,095,239
5 Oter Operating Revenues 105.764 105.764
6 Total Operating Revenues 10,201,003 10.095.239 105.764
7
8 Operating Exenses:
9 Sleam Producn 965,282 965,282
10 Nuclear Producton11 Hyro Pruc
12 Oter Por Supply 788.251 1.762.860 (501,475)(7,128)87,725 (553.731)
13 Transmission 545.194 545.194
14 Ditrbution
15 Customer Accounting
16 Customer Serice & Info
17 Sale
18 Administrative & General (218.926)(218,926)
19 Totl O&M Expenses 2,079.801 3,273.336 (720,401)(7,128)87.725 (553.731)
20 Depreciation (374)(374)
21 Amrtzation (7,111)(7.111)
22 Taxes Oter Than Income
23 Inco Taxes: Federal 2,705.314 2,279,266 243.194 35.337 2.382 (39,872)185,007
24 State 367,607 309,714 33,046 4,02 324 (5,418)25,139
25 Deered Incoe Taxes 11,997 (0)11.997
26 Investment Tax Credij Adj.
27 Mise Revenue & Exense
28 Total Operatig Exenses:5,157.234 5.862.316 (451,646)40,138 (4,423)54,433 (343,585)
29
30 Operating Rev For Return:5,043,769 4,232.923 451.646 65.625 4.423 (54,433)343.585
31
32 Rate Base:
33 Electric Plant In Serice (32,786)(32.786)
34 Plant Held for Future Use.35 Mise Deferred Debit 53.205 53.205
36 Ele Plant Acq Adj
37 Nuclear Fuel
38 Prepayments
39 Fuel Stock
40 Material & Suppties
41 Woring Capitl
42 Weatherti Loans
43 Mie Rate Base
44 Tota Elect Plant:20,419 (32,786)53.205
45
46 Deuctns:
47 Acm Pr For Deree 1.312 1.312
48 Acrn Prv For Amrt 19.272 19,272
49 Acrn Def In Tax (95,452)(83.084)(12,36)
50 Unamorted ITC
51 Customet Adv Fo Const
52 Customer Service Depoits
53 Miscellaneous Deducons (100,146)(100.146)
54
55 Total Deucts:(175,014)(62.500)(112,514)
56
57 Total Rate Base:(154,594)(95.285)(59.309)
58
59
60 Estimated ROE impact 1.897%1.588%0.172%0.025%0.002%-0.019%0.129%0.00%
61
62
63
64 TAX CALCULATION:
65
66 Operatig Revenue 8,128.687 6,821,903 727,886 105,764 7,128 (87,725)553,731
67 Oter Deuctions
68 Interest (AFUDC)
69 Interet
70 Schedule"M" Additions (7,224)(7,224).71 Schedul"M" Deuctons 24,388 24,388
72 Incom Before Tax 8.097,076 6.821,903 727.886 105.764 7,128 (119,337)553,731
73
74 State Income Taxes 387,607 3D9,714 33,046 4.802 324 (5.418)25,139
75
76 Taxable Ine 7,729.468 6,512.189 694.840 100.962 6,805 (113,919)528.592
77
78 Federal Incoe Taxes 2,705,314 2,279,266 243,194 35,337 2.382 (39.872)185.007
.
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Rocky Mountain Power.Period Ending
Dec-09
SPECIAL SALES FOR RESALE
Pacific Pre Merger
Post Merger
Utah Pre Merger
NonFirm Sub Total
TOTAL SPECIAL SALES
PURCHASED POWER & NET INTERCHANGE
BPA Peak Purchase
Pacific Capacity
Mid Columbia
Mise/Pacific
O. F. ConlractsPPL
Pacific Sub Total
Gemstate
GSLM
OF ContractslU PL
IPP Layoff
UP&L to PP&L
Utah Sub Total
.APS Supplemental
Avoided Cost Resource
Blanding Purchase
Chehalis Tollng
Combine Hils
Constellation p2576n
Constellation p257678
Constellation p26B849
Deseret Purchase
Georgia-Pacific Camas
Hermiston Purchase
Hurricane Purchase
Idaho Power RTSA Purchae
Kennecott GeneratiOn Incentive
MagCorp
MagCorp Reserves
Morgan Stanley p1B96
Morgan Stanley p2440
Morgan Stanley p244841
Morgan Stanley p272153.6-8
Morgan Stanley p272154-7
Nebo Heat Rate Option
NuCor
P4 Production
Rock River
Roseburg Forest Products
Thre Buttes Wind
Tri-State Purchase
UBSp268848
UBSp26850
Weyerheuser Reserve
Wolverine Creek
Place Holder
BPA So. Idaho Exchange
DSM (Irration)
PSCO Exchange
TrasAlla p3713431s37134.
Merged
01l0Q-1210Q
24,660,236
975,969,280
25,490,589
1,02,120,105
47,058,00
2,267,640
24,143.205
5,943,589
79,361,60
158,n4,04
2,716,400
128,752,213
25.490,589
156,95,202
9.582,003
19,725
3,872,489
31,404,60
6.171,651
89.06,319
328,501
2,103,115
9,66.109
1,755,36
10,683,600
5,282,160
1,744,080
1.515,00
4,610,40
15,415,920
5,041,688
8.767,109
12.951,499
66,250
291.60
9,654,954
1,800,00
(1,64,00)
Study Results
MERGED PEAK/ENERGY SPLIT
($)
Pre-Mergerll
24,660,236
25,490,589
50,150,825
47,058,00
60.00
7,242,962
1,232,479
6,350,767
62,484,208
20.608,960
25,490,589
46,099,549
Pre-Mergerfæ
1,667,640
16,90,244
4,711,110
30,941,865
54,220,859
2,716,40
8,832,411
11,548,811
~
Page 5.1.2
Post-Merger
975,969,280
975,96,280
42,068.976
42,06,976
99,310,842
99,310,842
9,582,003
19,725
3.872,489
31,404,60
6,171,651
89,063,319
328,501
2,103,115
9,66,109
1.755,360
10,683,60
5,282,160
1,744,080
1,515,00
4,610,40
15.415,920
5.041,688
8.767,109
12,951,499
662,250
291,60
9,65,95
1,800,00
(1,64,00)
Rocky Mountain Power.Period Ending
Dec-(
Short Term Firm Purchases
New Firm Sub Total
Non Firm Sub Total
TOTAL PURCHASED PW & NET INT.
WHEELING & U. OF F. EXPENSE
Pacifi Firm Wheeling and Use of Facilitief
Utah Firm Wheeling and Use of Facilities
Post Merger
Nonfirm Wheeling
TOTAL WHEELING & U. OF F. EXPENSE
.
THERMAL FUEL BURN EXPENSE
Carbn
Cholla
Colstrip
Craig
Chehalis
Currant Creek
Dave Johnston
Gadsby
GadsbyCT
Hayden
Hermiston
Hunter
Huntington
Jim Bridgr
Lake Sid
Litle MountainNaugn
West Valley
Wyodak
TOTAL FUEL BURN EXPENSE
OTHER GENERATION EXPENSE
Blundell
Wind Integratin Charg
TOTAL OTHER GEN. EXPENSE
NET POWER COST
.
Study Results
MERGED PEAK/ENERGY SPLIT
($)
Merged
01109-12/09
20,580,157
Pre-MergerJi li
Page 5.1.3
Post.Merger
203,580,157
434,320,289
575.700,107
34,597,586 34,597,586
380,063 38,063
95,769,309 95,769,309
203,231 203,231
..-_......._-_..._.-..._......_..____......._ __..______....._..a -_.__.....-.................._..................._.....
130,950,190 34,977,649 203,231 95,769,309
18,957,267 18,957,267
56,999,00 56.999,00
11,321,780 11,321,780
20,148,716 20,148,716
70,975,450 70,975,450
150,387,080 150,387,080
50,926,722 50,926.722
17,274,035 17,274,035
21.198,771 21,198,771
10,991,873 10,991,873
52,708,033 52,708,033
107,170,128 107,170.128
76.321,991 76,321,991
157,144,453 157,144,453
199,189,249 199,189,249
10,473,00 10,473,00
78.552,673 78,552,673
19,432.039 19,432,039
---------..----.........._....._.._--- --_...._-..-----.-_.----..........--_.....-..-....-..---_..
1,130,172,269 1,130,172,269
======--== ===---== ========= ======= ======
Pre-Merger~
434,320,289
750,053,534 65,769,670108,583,758
3,328,169
4,386,527
3,328,169
4,386,527
7,714,69 7,714.69
65,769,670 1.138,09,196 (304,499,864)99,770,585 93,410,582- === =====-:--= ======--=-~=--==== -==
.Rocky Mountain Power PAGE 5.2
Idaho Results of Operations. December 2008
West Valley Lease
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Generation Expense 548 1 (3,006,572)SSGCT 6.180%(185,807)5,2.1
Rents (Other generation)550 1 (4,583,304)SSGCT 6.180%(283,249)5.2,1
Maintenance of Structures 552 1 (166,275)SSGCT 6.180%(10,276)5,2,1
Maintenance Gen & Electric Plant 553 1 (190,591 )SSGCT 6.180%(11,779)5.2.1
Maintenance Misc Other Power Gen 554 1 (124,016)SSGCT 6.180%(7,664)5.2.1
Other Expenses 557 1 (43,687)SSGCT 6.180%(2,700)5.2.1
Total Revenue Adjustment (8,114,445)(501,475)
Depreciation Expense 403GP 1 (6,054)SSGCT 6.180%(374)5.2,1
Amortization Expense 4040P 1 (115,060)SSGCT 6.180%(7,111 )5.2.1
Lease Reduction Amortization 930 3 (218,926)10 Situs (218,926)5.2.2
Adjustment to Rate Base:
Electric Plant in Service 343 1 (530,511 )SSGCT 6.180%(32,786)5.2,1.Accum Depreciation Reserve 108GP 1 21,230 SSGCT 6.180%1,312 5.2.1
Accum Amortization Reserve 111SP 1 311,848 SSGCT 6.180%19.272 5.2.1
ADIT 10 Lease 190 3 124,627 ID Situs 124,627
Deferred Tax Expense 41010 3 83,085 ID Situs 83,085
Schedule M Addition SCHMDT 3 218,926 ID Situs 218,926
AD IT 10 Lease 190 1 (207,711 )10 Situs (207,711 )
Deferred Tax Expense 41010 1 (83,085)10 Situs (83,085)
Schedule M Addition SCHMDT 1 (218,926)ID Situs (218,926)
Description of Adjustment:
.The Company terminated the West Valley leae effective May 31, 2008. This adjustment removes any and all expense and
investment from 12 months ended December 2008 results to align with net power costs. It also credits Idaho ratepayers with
lease reduction amortization for 12 months ending December 2009. This treatment is consistent with the stipulation in Idaho
PAC-E-05-08Item 127.
.Rocky Mountain Power
Results of Operations. December 2008
West Valley Lease. Idaho
Page 5.2.1
Operation & Maintenance Account Total Dec 2008 Ref.
Generation Expense 548 3,006,572
Rents (Other generation)550 4,583,304
Maintenance of Structures 552 166,275
Maintenance Gen & Electric Plant 553 190,591
Maintenance Misc Other Power Gen 554 124,016
Other Expenses 557 43,687
8,114,445 To 5.2
Depreciation & Amortization
Depreciation Expense 403GP 6,054 To 5.2
Amortization Expense 4040P 115,060 To 5.2
Rate Base
EPIS 343 530,511 To 5,2
Accm Depreciation Reserve 108GP (21,230)To 5,2
Accm Amortization Reserve 111SP (311,848)To 5.2 .
.
.Rocky Mountain Power
Results of Operations. December 2008
West Valley Lease. Idaho
Reg Uab . West Valley Lease Reduction
Accounts 288133. Idaho
Page 5.2.2
8.827%
Unamorized
Seg Sal Additons Amortization Interest Balance
2006 Mar-06 (8,429)(8.429)
Apr-D (28,497)(167)(37,093)
May-D (28,497)(378)(65,967)
Jun-06 (28,97)(590)(95,054)
Jul-06 (28,497)(804)(124.355)
Aug-06 (28.497)(1.020)(153,872)
Sep-06 (28,497)(1,237)(183,605)
Oct-06 (28,497)(1,455)(213,558)
Nov-06 (28,97)(1,676)(243,730)
De-06 (28,497)(1.898)(274,125)
2007 Jan-07 (28,497)(2.121)(304,743)
Feb-07 (28,97)(2,34)(335,58)
Mar-07 (28,97)(2.573)(366,657)
Apr-07 (28,497)(2,802)(397,956)
May-07 (28,97)(3,032)(429,485)
Jun-D7 (28,497)(3,264)(461,246)
Jul-D7 (28,497)(3,498)(493.240)
Aug-07 (28,97)(3,733)(525,470)
Sep-07 (28,497)(3,970)(557,937)
Oct-07 (28,497)(4.209)(590,643)
Nov-07 (28,97)(4,449)(623,589)
Dec-07 (28,97)(4,692)(656.778)
2008 Jan-08 (656,778)18,244 (638,534)
Feb-08 (638,534)18,244 (620,290).Mar-08 (620,290)18,244 (602,047)
Apr-08 (602,047)18,244 (583,803)
May-08 (583,803)18,244 (565,559)
Jun-o (565,559)18,244 (547,315)
Jul-08 (547,315)18,244 (529,071)
Aug-08 (529,071)18,244 (510,827)Sep-8 (510,827)18,244 (492.584)
OCt-08 (492,584)18.244 (474,340)
Nov-08 (474,340)18,244 (456,096)
De-08 (456,096)18,244 (437,852)
2009 Jan-09 (437,852)18,244 (419,608)Feb-9 (419,608)18,244 (401,364)
Mar-09 (401,364)18,244 !~~3,!~!?Apr-D9 (383,121)18,244 Total
May-09 (364,877)18,244 (346,633)218,926
Jun-09 (346,633)18,244 (328,389)Ref 5.2
Jul-09 (328,389)18,244 (310,145)
Aug-09 (310,145)18,244 (291,901)
Sep-09 (291,901)18,244 (273,658)
Oct-09 (273,658)18,244 (255,414)
Nov-09 (255,14)18,244 (237,170)
Dec-09 (237,170)18,244 (218,926)
2010 Jan-10 (218,926)18,244 (200,682)
Feb-1O (200.682)18,244 (182,438)
Mar-10 (182,438)18.244 (164,194)
Apr-1O (164,194)18,244 (145,951)
May-1O (145.951)18,244 (127,707)
Jun-10 (127,707)18,244 (109,463)
Juf.10 (109,463)18,244 (91,219)
Aug-1O (91.219)18,244 (72,975)
Sep-10 (72.975)18,244 (54,731)
OCt-1O (54,731)18,244 (36,88)
Nov-1O (36,488)18,244 (18,244).Dec-10 (18,244)18,244 0
(606,865)656,778 (49,913)
.
.
.
Rocky Mountain Power
Idaho Results of Operations - December 2008
James River Royalty Offset I Little Mtn
PAGE 5.3
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Revenue:
Other Electric Revenue 456 3 $6,185,030 SG 5.807%359,165 Below
Other Electric Revenue 456 3 ($4,363,714 )SG 5,807%(253,401) Below
$1,821,316 105,764
Adjustment Detail:
12 Months Ended
12/31/2009
James River Offset
Capital Recovery
Major Maintenance Allowance
Total Offset
5,685,509
499.521
6,185,030
Little Mountain Revenue Forecast
Forecasted Steam sales -12 months ended 12/31/2009
Less: Steam sales in unadjusted results
2,924,667
7,288,382
(4,363,714)
5.3.1
Description of Adjustment:
This adjustment credits Other Electric Revenues for the James River Royalty Ofset as agreed in the January 13, 1993
agreement. Since the cost of James River power is included in the net power cost adjustment, it is necessary to show a credit for
capital cost and maintenance cost recovery.
This adjustment also accounts for an increase in the LIttle Mountain Steam sales which is attributable to matching revenue with
the assumptions used in the Net Power Cost study.
.
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Rocky Mountain Power
Idaho Results of Operations - December 2008
Green Tag
Adjustment to Revenue:
Green Tag Purchases
TOTAL
ACCOUNT Iï COMPANY
PAGE 5.4
IDAHO
FACTOR FACTOR % ALLOCATED REF#
SE 6.449%(7,128) 5.4.1555NPC1(110,531)
Description of Adjustment:
This adjustment removes from results the green tags purchase costs associated with the Blue Sky program.
.
.
.
Rocky Mountain Power
Results of Operations - December 2008
Green Tag Adjustment
January - December 2008
Account
546536
110,531
Account
546538 Total
110,531
Ref 5.4
These accounts record green tag purchases which must be removed from results because
they are purchased for the Blue Sky program,
Page 5.4.1
.Rocky Mountain Power PAGE 5.5
Idaho Results of Operations. December 2008
Electric Lake Settlement
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Settlement of Costs:
Amortization O&M Portion 557 1 1,510,680 SG 5.807%87,725 5.5.1
Regulatory Liabilty 25399 1 (1,073,760)SG 5.807%(62,353)5.5.1
Regulator Asset 186M 3 824,983 SE 6.449%53,205 5.5.1
Regulatory Liabilty 254 3 (586,002)SE 6.449%(37,793)5.5.1
Tax Adjustments
Fuel Amortization
Sch M SCHMAT 3 2,650,502 SE 6.449%170,938
Sch M SCHMAT 1 (2,762,514)SE 6,449%(178,161)
DIT Exp.41110 3 (1,005,892)SE 6.449%(64,873)
DIT Exp.41110 1 1,048,402 SE 6.449%67,614
DITBal.283 3 (1,137,480)SE 6.449%(73,359).DITBal.283 1 (524,201 )SE 6.449%(33,807)
Coal Supply Adjustment
SchM SCHMDT 3 1,881,857 SG 5.807%109,279
SchM SCHMDT 1 (1,960,857)SE 6.449%(126,461)
DIT Exp.41010 3 714,183 SG 5.807%41,473
DIT Exp.41010 1 (744,165)SE 6.449%(47,993)
DITBal.190 3 807,610 SG 5.807%46,898
DITBal.190 1 372,083 SG 5.807%21,607
Settlement Costs
Sch M SCHMDT 3 715,840 SG 5,807%41,569
DIT Exp.41010 3 271,668 SG 5.807%15,776
DITBal.190 3 452,780 SG 5.807%26,293
.
Description of Adjustment:
Canyon Fuel Company owns the Skyline mine located near Electric Lake. Electric Lake is owned by PacifiCorp and
provides water for the Huntington Power Plant. The two companies have disputed the claim made by PacifiCorp that
CFC's mining operations punctured the lake and caused water to flow into the Skyline mine, PacifiCorp has incurred
capital costs and O&M costs to pump water from the breach back into Electric Lake. The two companies negotiated a
settlement and release agreement for the claims made by PacifiCorp. The settlement of costs reimburses for legal
expenses, other O&M and capital costs associated with the pumping and is split 71% O&M and 29% CapitaL. The
value of the settlement is $10,087,658 and wil be amortized over three years. This adjustment reduces rate base for
the fixed cost portion of the settlement, and includes one year of amortization for the O&M portion of the settlement.
.Rocky Mountain Power Page 5.5.1
Results of Operations. December 2008
Electric Lake Settlement
Settlement of Costs
Value of Settlement 10.087.658
Offet O&M 71%
Reduction of O&M 7.162,237
Amortzation Account 25399 over 3 years (715.840)
Amortzation Account 254 (1.881.857)
Reducton to Account 557 (2.597,697)
Accunt 557 Reduction in actual results (4,108,377)Adjustment needed to reflect reductn amount 1,510,680 Ref 5.5
Reduction to Account 557 (2,597,697)
Regulatory Liabilty Account 25399 Dec-08 Dec-09
Ofset O&M Account 557 2,147,520 1,431,680
Amortization of Offet (715,840)(715,840)
Remaining Liabilit Balance 1,431,680 715,840
Dec 08 - Dec 09 Beginning I Ending Average 1.073.760 Ref 5.5
Regulatory Asset 186.5 Dec-08 Dec-09
Set-Up Deferred Asset 7,062,982 4,300,468
Amortzation (2,762,514)(2.650,503)
Ending Balance 4,300,468 1,649,966
Dec 08 - Dec 09 Beginning I Ending Average 2,975,217.Account 186.5 average balance in actual results 2,150.234
Adjustment needed to reflect account balance 824,983 Ref 5.5
Dec 08 - Dec 09 Beginning I Ending Average 2,975.217
Regulatory Liabilty Account 254 Dec-08 Dec-09
Set-Up Deferred Asset (5.014.717)(3,053,860)
Amortization 1,960,857 1,881,857
Ending Balance (3,053,860)(1.172,003)
Dec 08 - Dec 09 Beginning I Ending Average (2,112.932)
Account 254 average balance in actual results (1,526.930)
Adjustment needed to reflect account balance (586,002)Ref 5.5
Dec 08 - Dec 09 Beginning I Ending Average (2,112,932)
Coal Delivered Account 151.1 D.Johnston Carbon Total
Decmber 2008 Amontization 1,136,894 1,625.620 2,762.514
Amortization 12 months ended December 2009 978.003 1,672,500 2,650.503
.
.
.
.
Rocky Mountain Power
Idaho Results of Operations. December 2008
SPA Residential Exchange
PAGE 5.6
TOTAL IDAHO
ACCOUNT Iï COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Purchased Power Expense 555 1 4,162,064 OR Situs
Purchased Power Expense 555 1 1,269,727 WA Situs
Purchased Power Expense 555 1 (553,731)10 Situs (553,731)
4,878,060 (553,731)
Description of Adjustment:
The Residential Exhange credit received from SPA is treated as a 100% pass-through to eligible customers. Both a
revenue credit and a purchase power expense credit is posted to unadjusted results, Both of these transactions are to
be removed from results. This adjustment reverses the SPA purchase power expense credit recorded.
IDAHO REVISED PROTOCOL Pag 6.0 Total
Depreiation & Amortzation (Tab 6)
TOTAL
6.1 6.2 0 0 0 0 0.Depreciation &Depreciation &Amrtzati Amorzation
Total Noralized Expense Reserve 0 0 0 0
1 Operatig Revenues:
2 General Business Revenues3 Inteeparttal
4 Speial Sale
5 Oter Operting Revenues
6 Total Oprating Revenues
7
8 Opating Exenses:
9 Steam Pructn
10 Nuclr Pructon
11 Hyro Productn
12 Otr pO\ Suppl
13 Transmisio
14 Disbution
15 Customer Acounting
16 Custoer Seric & Info
17 Sale
18 Administratie & General
19 Total O&M Expees
20 Depreciation 2.849.723 2,649,723
21 Amatin 61,041 61,041
22 Taxe Oter Than In
23 Inco Taxe: Federal (972,515)(972,515)
24 State (132,149)(132,149)
25 Deerr Incom Taxes ,
26 inestmt Tax Creft Adj.
27 Mi Revenue & Expense
28 Totl Operating Exenses:1,806.100 1,806,100
29
3D Operating Rev For Retum:(1.806,100)(1.806,100)
31
32 Rate Base:
33 Electr Plant In Service
34 Plant Held for Future Use.35 Msc Defered Debit
36 Ele Plant Acq Adj
37 Nuear Fuel
38 Prpaymnts
39 Fuel Sto
40 Malarl & Suppl
41 WOling Capitl42 Weather Lons
43 Mise Rate Base
44 Total Ele Plnt
45
46 Dect:
47 Acm Prov For Dere (1,424.862)(1,424.862)
48 Acm Pr For Amrt (30.521)(30,521)
49 Ac De In Tax
50 Unam ITC
51 Custo Adv For Cost
52 Custome Servic Depos
53 Millaneos Deuctns
54
55 Total Deductons:(1,455,362)(1,455,362)
56
57 Total Rate Base:(1,455,362)(1,455.382)
58
59
60 Estiled ROE imact -0.641%-0.678%0.039%0.000%0.00%0.00%0.000%0.000%
61
62
63
64 TAX CALCULATION:
65
66 Operati Revenue (2.910,764)(2,910,764)
67 Oter Deucs
68 Intert (AFUOC)
69 Intere
70 Scule oM" Addit.71 Scheule OM" Deuctns
72 Income Beor Tax (2,910,764)(2,910.764)
73
74 State Incom Taxes (132,149)(132,149)
75
76 Taxable Inco (2,778.616)(2.778,616)
77
78 Feeral Inco Taxe (972.515)(972,515)
Rocky Mountain Power PAGE 6.1
Idaho Results of Operations. December 2008.Depreciation & Amortization Expense
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Expense:
Steam Production 403SP 2 467,908 SG 5.8070%27,171
Steam Production 403SP 2 1,039,555 SSGCH 5.6625%58,865
Hydro Production 403HP 2 196,818 SG-P 5.8070%11,429
Hydro Production 403HP 2 141,835 SG-U 5.8070%8,236
Hydro Production 403HP 2 SG-U 5.8070%
Other Production 4030P 2 27,867,463 SG 5,8070%1,618.264
Transmission 403TP 2 1,699,053 SG 5.8070%98.664
Distribution - Idaho 403364 2 982,559 10 Situs
General Plant - Idaho 403GP 2 49,558 10 Situs 7,336
General Plant 403GP 2 156.745 SO 5.6106%8,794
General Plant 403GP 2 12,176 SG 5.8070%707
General Plant 403GP 2 14,793 CN 3,8788%574
Mining Plant 403MP 2 44,164 SE 6,4493%2,848
Intangible Plant 4041P 2 170,447 SO 5.6106%9,563
Intangible Plant 4041P 2 SE 6.4493%
Intangible Plant 404IP 2 219.562 SG 5.8070%12.750
Intangible Plant 4041P 2 560,738 SG-P 5.8070%32,562
33.623,375 1,897,764 6.1.1
Steam Production 403SP 3 1,553,586 SG 5.8070%90,217
Steam Production 403SP 3 15,108 SSGCH 5.6625%855
Hydro Production 403HP 3 341,060 SG-P 5.8070%19,805.Hydro Production 403HP 3 28,356 SG-U 5.8070%1,647
Hydro Production 403HP 3 SG-U 5.8070%
Other Production 4030P 3 13,801,890 SG 5,8070%801,476
Transmission 403TP 3 1,598,663 SG 5.8070%92.834
Distribution - Idaho 403364 3 1,072,767 10 Situs
General Plant -Idaho 403GP 3 246,207 10 Situs
General Plant 403GP 3 SO 5.6106%
General Plant 403GP 3 SG 5.8070%
Mining Plant 403MP 3 SE 6.4493%
Intangible Plant 4041P 3 109,897 SO 5,6106%6,166
Intangible Plant 4041P 3 SE 6.4493%
Intangible Plant 4041P 3 SG 5.8070%
Intangible Plant 4041P 3 SG-P 5.8070%
18,767.534 1.013,000 6.1.1
Description of Adjustment:
This adjustment enters into the test period results depreciation and amortization expense for the major plant additions added
to rate base in adjustment 8.6.
.
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t
a
l
31
2
40
3
S
P
SS
G
C
H
1,5
0
8
%
74
,
4
4
1
,
0
3
1
4,5
84
1
,
8
3
1
6
64
1
,
8
3
1
To
t
a
l

S
t
e
a
m

P
l
a
n
t
10
7
,
5
1
3
,
4
2
2
1,5
0
7
,
4
6
3
67
,
2
7
2
,
1
6
5
1,
5
6
8
,
6
9
4
3,
0
7
6
,
1
5
6
Hy
d
r
o

P
r
o
d
u
c
t
o
n

P
!
a
n
l
:
Va
r
i
o
u
s
33
2
40
3
H
P
SG
-
P
2.1
7
9
%
9,0
3
4
,
5
0
7
6
19
6
,
8
1
8
15
.
6
5
5
,
6
3
5
6
34
1
,
0
6
0
53
7
,
8
7
9
Va
r
i
o
u
s
33
2
40
3
H
P
SG
-
l
J
2,7
3
0
%
5,1
9
5
,
6
8
2
6
14
1
,
8
3
5
1,
0
3
8
,
7
3
0
6
28
,
3
5
6
11
0
,
1
9
1
To
t
a
l

H
y
d
r
o

P
l
a
n
t
14
,
2
3
0
.
1
9
0
33
8
,
6
5
4
16
,
6
9
4
,
3
6
4
36
9
,
4
1
6
70
8
,
0
7
0
Ot
h
e
r

P
r
o
d
u
c
t
i
o
n

P
l
a
n
t
:
Ma
e
n
g
o

I
I

W
i
n
d

E
x
p
a
n
s
i
o
n
34
3
40
3
0
P
SG
4.0
5
2
%
62
.
4
8
6
,
4
9
9
5,
5
2.
3
2
0
.
7
7
2
6
2.
3
2
0
.
7
7
2
Go
o
n
o
e

H
i
l
l
s

W
i
n
d

P
r
o
j
e
c
t
34
3
40
3
0
P
SG
4,0
5
2
%
91
,
8
7
5
.
5
9
6
4.
5
2,
7
9
1
.
8
7
7
6
2,
7
9
1
.
8
7
7
Hig
h

P
l
a
i
n
s

W
i
n
d

P
r
o
j
e
t
34
3
40
3
0
P
SG
4.0
5
2
%
6
40
,
9
1
8
,
0
4
0
2
1,
6
5
7
.
8
6
7
1.6
5
7
.
8
6
7
Ro
i
l
n
g

H
i
l
l
s

W
i
n
d

P
r
j
e
c
34
3
40
3
0
P
SG
4.0
5
2
%
6
20
5
,
1
4
5
,
4
9
0
12
8.3
1
1
,
8
3
3
8,3
1
1
,
8
3
3
Gl
e
n
r

W
i
n
d

P
l
a
n
t
34
3
40
3
0
P
SG
4.0
5
2
%
99
,
7
1
3
,
1
0
0
11
,
5
7,
7
4
3
,
4
3
5
2,
2
0
9
,
6
1
1
6
89
,
5
2
6
7.8
3
2
,
9
6
1
Se
v
e

M
i
l
e

H
i
l
i

W
I
n
d

P
l
a
n
t
34
3
40
3
0
P
SG
4.0
5
2
%
96
,
2
6
2
,
5
6
11
,
7,
4
7
5
,
4
7
8
1,
8
1
3
.
8
7
2
8
73
,
4
9
2
7,5
4
8
.
9
7
1
Gi
e
n
r
o

I
I

W
i
n

P
r
o
e
c
t
34
3
40
3
0
P
SG
4,0
5
2
%
.
6
86
.
8
4
3
,
4
9
9
12
3.
5
1
8
,
6
1
8
3,5
1
8
,
6
1
8
Se
v
e
n

M
I
l
e

H
i

I
I

W
i
n
d

P
r
o
e
c
l
34
3
40
3
0
P
sa
4.0
5
2
%
20
,
6
9
5
,
6
2
3
11
.
5
1,6
0
7
,
1
6
3
15
4
.
5
2
0
6
6,2
6
1
1.
6
1
3
,
4
2
4
Ch
e
h
a
l
i
s
34
3
40
3
0
P
SG
2.6
3
4
%
14
8
,
9
7
3
,
9
6
8
8.
5
5,
5
5
7
,
9
8
0
6
5,5
5
7
.
9
8
0
Ch
e
h
a
U
s

O
v
e
r
a
u
l
34
3
40
3
0
P
SG
2.6
3
4
%
5,1
0
8
.
7
9
2
6
13
4
,
5
4
2
6
13
4
,
5
4
2
Va
r
o
u
s

W
i
n
d

O
l
l
e
r
34
3
40
3
0
P
SG
4.0
5
2
%
6
1.1
0
4
,
2
1
5
6
44
,
7
3
9
44
,
7
3
9
Va
r
i
o
u
34
3
40
3
0
P
SG
2.6
3
4
%
8,9
6
9
,
4
9
7
6
23
6
,
2
1
5
3,7
8
0
,
1
9
8
6
99
,
5
5
3
33
5
.
7
6
8
To
t
l

O
l
h
r

P
l
a
n
t
53
4
,
0
8
5
,
6
6
3
27
,
8
6
7
,
4
6
3
34
1
,
9
6
9
,
4
4
5
13
,
8
0
1
,
8
9
0
41
,
6
6
9
,
3
5
2
Tr
a
n
s
m
i
s
s
i
o
n

P
l
a
n
l
:
Va
r
i
o
u
s
35
5
40
3
T
P
SG
2.0
3
5
%
83
.
8
8
.
5
6
6
6
1.
6
9
9
,
0
5
3
78
,
5
5
5
,
5
7
8
6
1.
5
9
8
.
6
6
3
3,2
9
7
,
7
1
8
To
t
a
l

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

P
l
a
n
l
83
,
4
8
8
,
5
6
6
1,
6
9
9
,
0
5
3
78
.
5
5
5
,
5
7
8
1,
5
9
8
,
6
6
3
3,2
9
7
,
7
1
8
Di
s
t
r
b
u
t
o
n

P
l
a
n
l
:
Ca
l
i
f
o
r
i
a
36
40
3
3
6
CA
3.7
5
0
%
3,4
2
6
,
9
5
0
6
12
8
.
5
0
2
2.
1
2
9
.
0
7
9
6
79
.
8
3
5
20
8
.
3
3
8
Or
o
n
36
4
40
3
3
6
4
OR
2.8
6
3
%
3,6
1
9
,
0
6
4
6
10
3
,
5
9
6
5.9
4
1
,
8
6
7
6
17
0
.
0
8
7
27
3
.
6
8
3
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s
h
i
n
t
o
n
36
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40
3
3
6
4
WA
3.1
1
8
%
1.1
6
9
,
5
4
6
6
36
,
4
6
5
6
36
,
4
6
5
Ut
h
36
4
40
3
3
6
4
UT
2.5
0
5
%
23
,
6
9
3
,
3
2
9
6
59
3
,
4
8
2
26
,
2
2
9
.
0
7
2
6
65
6
.
9
9
9
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0
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4
8
1
Id
a
h
o
36
4
40
3
3
6
4
10
2,5
6
3
%
6
6
Wy
o
m
l
n
9
36
4
40
3
3
6
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E
2.8
1
7
%
4,2
7
8
,
0
6
9
6
12
0
,
5
1
3
5,8
6
7
,
3
1
4
6
16
5
,
8
4
6
28
6
,
3
5
9
To
t
a
l

D
i
s
t
r
i
b
u
t
i
o
n

P
l
a
n
l
36
,
1
8
6
,
9
5
9
98
2
,
5
5
9
40
,
1
8
7
,
3
3
2
1,
0
7
2
,
7
6
7
2,
0
5
5
,
3
2
6
Ge
n
e
r
a
l

P
l
a
n
l
:
Ca
l
o
r
n
i
a
39
7
40
3
G
P
CA
2.3
2
3
%
.
6
6
Or
e
9
0
n
39
7
40
3
G
P
OR
2.
6
8
7
%
1,
3
8
1
,
6
7
9
6
37
.
1
2
7
4.
5
8
4
.
3
7
7
6
12
3
,
1
8
7
16
0
.
3
1
4
Wa
s
h
i
n
t
o
n
39
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40
3
G
P
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3,
3
8
7
%
6
6
Uta
h
39
7
40
3
G
P
UT
2.
2
3
8
%
22
7
,
7
0
7
6
5.
0
9
6
2.2
4
1
.
7
1
7
6
50
,
1
6
4
55
,
2
6
0
Id
a
h
o
39
7
40
3
G
P
10
2.
4
1
9
%
30
3
,
2
7
8
6
7,
3
3
6
6
7.3
3
6
Wy
o
i
n
39
7
40
3
G
P
WY
E
3.
6
7
4
%
.
6
1,
9
8
3
.
0
5
7
6
72
,
8
5
6
72
.
8
5
6
Ge
n
e
r
a
39
7
40
3
G
P
SO
6.6
4
8
%
2,3
5
7
.
7
4
7
6
15
6
,
7
4
5
6
15
6
.
7
4
5
Ge
n
e
r
a
l
39
7
40
3
G
P
CN
7.
7
6
2
%
19
0
,
5
8
3
6
14
,
7
9
3
6
14
,
7
9
3
Ge
n
e
r
a
39
7
40
3
G
P
SG
3.
1
8
7
%
38
2
,
0
3
1
6
12
,
1
7
6
6
12
,
1
7
6
To
t
a
l

G
e
n
e
r
a
l

P
l
a
n
l
4,6
4
3
,
0
2
5
23
3
,
2
7
3
8,6
0
9
,
1
5
1
24
6
,
2
0
7
47
9
,
4
8
0
MI
n
i
n
g

P
l
a
n
t
:
Co
a
l

Min
e

39
9
40
3
M
P
SE
3,
7
9
2
%
1,
1
6
4
.
6
7
8
6
44
.
1
6
4
6
-
44
.
1
6
4
To
t
a
l

M
i
n
i
n
g

P
l
a
n
l
1,
1
6
4
,
6
7
8
44
,
1
6
4
.
44
,
1
6
4
In
t
a
n
g
l
l
e

P
l
a
n
i
:
Ge
n
e
r
a
l
30
3
40
4
1
P
SO
6.
4
6
5
%
2,6
3
6
,
6
5
7
6
17
0
,
4
7
1,
7
0
0
.
0
0
0
6
10
9
,
8
9
7
26
0
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3
4
4
Ge
n
e
r
a
l
30
3
40
4
1
P
SE
6,9
4
4
%
6
6
.
Ge
n
e
r
a
l
30
3
4D
4
I
P
sa
3.
7
2
9
%
5,8
8
7
,
8
9
0
6
21
9
,
5
6
2
6
21
9
,
5
6
2
Hy
d
r
o

R
e
U
c
e
n
s
i
30
2
40
4
1
P
SG
.
p
2.6
2
8
%
21
,
3
3
6
,
4
2
1
6
56
0
.
7
3
8
.
6
.
56
0
,
7
3
8
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t
a
l
l
n
l
l
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g
b
l
e

P
1
a
n
l
29
,
8
6
0
,
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6
8
95
0
,
7
4
7
1.
0
0
,
0
0
0
10
9
,
8
9
7
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4
81
1
,
3
7
3
,
4
7
0
33
,
6
2
3
,
3
7
5
55
5
.
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8
,
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4
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,
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m

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1
Rocky Mountain Power PAGE 6.2.Idaho Results of Operations. December 2008
Depreciation & Amortization Reserve
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Reserve:
Steam Production 108SP 2 (233,954)SG 5.8070%(13,586)
Steam Production 108SP 2 (519,778)SSGCH 5,6625%(29,432)
Hydro Production 108HP 2 (98,409)SG-P 5,8070%(5.715)
Hydro Production 108HP 2 (70,918)SG-U 5.8070%(4,118)
Hydro Production 108HP 2 SG-U 5.8070%
Other Production 1080P 2 (13.933,731)SG 5,8070%(809,132)
Transmission 108TP 2 (849,527)SG 5.8070%(49,332)
Distribution - Idaho 108364 2 (491.280)10 Situs
General Plant - Idaho 108GP 2 (24,779)10 Situs (3,668)
General Plant 108GP 2 (78,373)SO 5.6106%(4,397)
General Plant 108GP 2 (6,088)SG 5.8070%(354)
General Plant 108GP 2 (7,397)CN 3.8788%(287)
Mining Plant 108MP 2 (22,082)SE 6.4493%(1,424)
Intangible Plant 1111P 2 (85.224)SO 5.6106%(4,782)
Intangible Plant 1111P 2 SE 6.4493%
Intangible Plant 1111P 2 (109,781)SG 5.8070%(6,375)
Intangible Plant 1111P 2 (280.369)SG-P 5.8070%(16,281 )
(16,811,687)(948,882)6.2.1
Steam Production 108SP 3 (776.793)SG 5.8070%(45,108)
Steam Production 108SP 3 (7,554)SSGCH 5.6625%(428)
Hydro Production 108HP 3 (170,530)SG-P 5.8070%(9,903).Hydro Production 108HP 3 (14.178)SG-U 5.8070%(823)
Hydro Production 108HP 3 SG-U 5.8070%
Other Production 1080P 3 (6,900.945)SG 5.8070%(400,738)
Transmission 108TP 3 (799,332)SG 5.8070%(46,417)
Distribution - Idaho 108364 3 (536,383)10 Situs
General Plant - Idaho 108GP 3 (123,104)10 Situs
General Plant 108GP 3 SO 5.6106%
General Plant 108GP 3 SG 5.8070%
Mining Plant 108MP 3 SE 6.4493%
Intangible Plant 1111P 3 (54.948)SO 5.6106%(3,083)
Intangible Plant 1111P 3 SE 6.4493%
Intangible Plant 1111P 3 SG 5,8070%
Intangible Plant 1111P 3 SG-P 5.8070%
(9.383,767)(506,500)6.2.1
Description of Adjustment:
This adjustment enters into the test period results depreciation and amortization reserve for the major plant additions added
to rate base in adjustment 8.6.
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8
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5
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9
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5
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6
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7
0
7
6
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9
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5
4
8
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1
7
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1
6
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7
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6
3
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10
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7
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3
3
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8
8
8
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6
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6
8
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m
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g
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7
10
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7
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8
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0
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7
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8
5
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8
.
4
2
8
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6
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4
2
8
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a
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39
7
10
8
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4
8
%
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3
5
7
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7
4
7
6
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5
6
.
7
4
5
)
(7
8
,
7
3
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6
(7
8
.
3
7
3
)
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a
l
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7
10
8
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P
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8
2
%
19
0
,
5
8
3
6
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4
.
7
9
3
)
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.
3
9
7
)
6
(7
,
3
9
7
)
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n
a
l
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7
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8
7
%
38
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0
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1
6
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,
1
7
8
)
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,
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1
IDAHO REVISED PROTOCOL Page 7.0 Total
Tax Adjusbnts (Tab 7)
TOTAl
7.1 7.2 7.3 7.4 7.5 7.6 7.7.Propert Tax Renewbl Energy Orego Steam 10 State Tax Tax Allotion
Total Normalize IntrestTru Up Exe Tax Credt Depriaton SeWement IDStalelTC Adjbnt
1 Operatig Revenues:
2 General Business Revenues3 Interdearttal
4 Special Sales
5 O1r Opeating Revenues
6 Tota Operatg Revenues
7
8 Operat Expenses:
g Steam Producton
10 Nuclar Proon
11 Hyd Prod
12 O1r Power Supply
13 Transmission
14 Distrutn
15 Custo Accnting
16 Custo Service & inf
17 Sals
18 Administrtive & General
19 Total O&M Expenses
20 Deaton
21 Amorttion
22 Taxes Ot Than Income 507.35 507.354
23 Income Taxes: Fedral (3,880.391 )(510,466)(169,512)(3.04,333)(192.751)40.871
24 State (147.043)(69,36)(23,034)(33,980)(26,192)5.526
25 Deerr Incoe Taxes 1,156.557 218,943 6,04 931,570
26 Invesiment Tax Credt Adj.
27 MIse Revenue & Expense
28 Total Opertig Expeses:(2.363.523)(579.830)314,808 (3.082,313)°6,04 gn.767
29
30 Operating Rev For Return:2,36,523 579.830 (314.808)3,082.313 (0)(6.04)(977.767)
31
32 Rate Base:
33 Electri Plant In Servic
34 Plant Held lor Fute Use
35 Mise Deferred Deits.36 Elec Plt Acq Adj
37 Nucear Fuel
38 Prepaymnts
39 Fuel Sto
40 Malrll & Supplies
41 Working Capit
42 Weathtion Loans
43 MIse Role Base
44 Total Elec Plant
45
46 Deuctons:
47 Accm Pro For Depree
48 Accu Prov For Amort
49 Acc De Incoe Tax (104.939)(109.472)4,533
50 Unamor ITC 335,42g 335.429
51 Cuslomer Adv For Cont
52 Custor Service Depoits
53 Miceaneus Deucons
54
55 Tot Deductns:23O,4g1 (109,472)4,53 33,42g
56
57 Tota Rate Base:23O,4g1 (109,472)4.53 33,429
58
59
60 Estimad ROE impac 0.88%0.218%-0.118%1.157%0.003%-0.002%-0.00%-0.367%
61
62
63
64 TAX CALCULATION:
65
66 Oprating Revenue (507.354)(507,35)
67 Oter Deucon
68 IntereSI (AFUDC)
691nter1 1,527,838 1.527,83
70 Sch OM" Add (517,570)(576,910)59,34
71 Schul OM" Deucns (62,389)(62.38g)
72 Incom Beore Tax (2,490.373)(1.527,838)(507.35)(576,910)121.72g
73.74 State Inc Taxes (147.04)(69,36)(23,034)(33,98)(26,192)5.52
75
76 Taxable Incme (2,343,33)(1,451.474)(484.320)33,980 (55.718)116,202
77
78 Fedl Incom Tax . Calclaled (820,165)(510,466)(169,512)11,893 (192,751)40,671
79 Adjubnts to Calculated Tax:
80 Renab Enrgy Tax Creit (3,060,226)(3.06.226)
81 Federal Ince Taxes (3.880,391 )(510.466)(169.512)(3,04.33)(lg2.751)40.671
.
.
.
Rocky Mountain Power
Idaho Results of Operations. December 2008
Interest True Up
Adjustment to Expense:
Other Interest Expense - Type 1
Other Interest Expense - Type 2
Other Interest Expense - Type 3
Adjustment Detail:
Type 1
Jurisdiction Specifc Adjusted Rate Base
Weighted Cost of Debt:
Trued-up Interest Expense
Actual Interest Expense
Total Interest True-up Adjustment
Type 2
Jurisdiction Specific Adjusted Rate Base
Weighted Cost of Debt:
Trued-up Interest Expense
Type 1 Interest Expense
Total Interest True-up Adjustment
Type 3
Jurisdiction Specific Adjusted Rate Base
Weighted Cost of Debt:
Trued-up Interest Expense
Type 2 Interest Expense
Total Interest True-up Adjustment
TOTAL
ACCOUNl ~ COMPANY
427
427
427
1
2
3
(603,459)
1,330,155
801,141
1,527,838
PAGE 7.1
IDAHO
FACTOR FACTOR % ALLOCATED REF#
ID
ID
ID
Situs
Situs
Situs
(603,459) Below
1,330.155 Below
801,141 Below
1,527,838 2.18
533.961,660 1,0
2,993% 2,1
15,979,102 1.0
16,582,560 2.18
(603,459) 1.0
578,410,464 1,0
2.993%2.1
17,309,257 1.0
15,979,102 1.0
1,330,155 1.0
605,181,596 2,2
2.993%2:1
18,110.398 2.18
17,309,257 1,0
801,141 1.0
Description of Adjustment:
This adjustment synchronizes interest expense with the jurisdictional allocated rate base by multiplying the rate base
by the Company's weighted cost of debt.
.
.
.
Rocky Mountain Power
Idaho Results of Operations - December 2008
Property Tax Expense
PAGE 7.2
Adjustment to Expense:
Taxes Other Than Income
TOTAL IDAHO
ACCOUNTIì COMPANY FACTOR FACTOR % ALLOCATED REF#
GPS 5.6106%507,354 7.2.140839,042,721
Description of Adjustment:
This adjustment normalizes the difference between actual accrued propert tax expense and forecasted propert
tax expense resulting from estimated capital additions.
.
.
.
Rocky Mountain Power
Results of Operations. December 2008
Property Tax Adjustment Summary
FERC Account GIL Account Co. Code Factor
408.15 579000 1000
Total Accrued Propert Tax - 12 Months Ending December 2008
Arizona
California
Colorado
Idaho
Montana
New Mexico
Oregon
Utah
Washington
Wyoming
Misc. Possessory
Forecasted Propert Tax for the 12 Months Ending Dec 31, 2009
Less Accrued Property Tax - 12 Months Ending Dec 31, 2008
Incremental Adjustment to Propert Taxes
Page 7.2,1
Total
77,529,279
77,529,279
B!
Projected
2009 Expense
1,870,000
2,350,000
1,590,000
2,230,000
2,680,000
10,000
16,790,000
39,980,000
8,860,000
9,910,000
302,000
86,572,000
86,572,000
(77,529,279)
9,042,721 Ref. 7.2
Rocky Mountain Power PAGE 7.3.Idaho Results of Operations. December 2008
Renewable Energy Tax Credit
TOTAL IDAHO
ACCOUN1~COMPANY FACTOR FACTOR %ALLOCATED REF#Adjustment to Expense:
FED Renewable Energy Tax Credit 40910 1 (9,074,691 )SG 5.8070%(526.967)
FED Renewable Energy Tax Credit 40910 2 (41,628,069)SG 5.8070%(2,417,342)
FED Renewable Energy Tax Credit 40910 3 (1,405,464)SG 5,8070%(81,615)
(52,108,224)(3,025,925)
UT Renewable Energy Tax Credit 40911 3 (197,825)SG 5.8070%(11,488)
OR Business Energy Tax Credit 40911 3 (387,339)SG 5,8070%(22,493)
Mining Rescue Training Credit 40910 3 (50,009)SG 5,8070%(2,904)
Research and Experimentation Credits 40910 3 (540,673)SG 5.8070%(31,397)
(1,175,846)(68,281)
.
.
Description of Adjustment:
This adjustment normalizes federal! state renewable energy income tax credits and state tax credits the Company is
entitled to take as a result of placing qualified generating plants into service. The federal production tax credit is based on
the generation of the plant, and the credit can be taken for ten years on qualifying propert. The Utah state production tax
credit is based on the generation of the plant, and the credit can be taken for four years on qualifyng propert, The Oregon
BETC is based on investment of plant, and the credit is taken over a 5 year period on qualifying propert.
.
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.
.
Description of Adjustment:
This adjustment removes the tax impacts of additional book deprecation for coal fired steam plants allocated to all jurisdictions
erroneously.
Rocky Mountain Power PAGE 7.5.Idaho Results of Operations.December 2008
10 State Tax Settlement
TOTAL IDAHOACCOUN1~COMPANY FACTOR FACTOR %ALLOCATED REF#Adjustment to Expense:
Income Tax Expense 41010 1 6,044 10 Situs 6,044
Adjustment to Rate Base:
Accum Deferred Income Tax Balance 190 1 4,533 10 Situs 4,533
.
.
Description of Adjustment:
In FY2003, PacifiCorp made state income tax settlement payments totaling $634.571. Idaho's portion of these costs are based on
an average of Idaho's historicallBT factor (1994 to 1998) and amortized over a 5 year period. This adjustment adds Idaho's
portion of the settlement balance along with the amortization expense to the results of operations.
.
.
.
Rocky Mountain Power
Idaho Results of Operations. December 2008
10 State ITC
Adjustment to Expense:
Idaho -ITe
TOTAL
ACCOUNT ~ COMPANY
PAGE 7,6
IDAHO
FACTOR FACTOR % ALLOCATED REF#
1ST -13.835%335,429 7.6.1255(2,424,573)
Description of Adjustment:
This adjustment normalizes Idaho State investment tax credit the Company has taken as a result of placing propert into service. The
tax credit is based on the plant placed in service. and the credit is usually utilzed in a subsequent period depending on the availability
of Idaho state taxable income. Since PacifiCorp is a 46(f)1) Company, the ITC unamortized balance is what is reflected in results of
operations as a rate base reduction.
Rocky Mountain Power PAGE 7.7.Idaho Results of Operations - December 2008
Tax Allocation Adjustment
TOTAL IDAHO
ACCOUNl :I COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Taxes:
Schedule M SCHMAT 1 (938,633)SSGCT 6.1800%(58.008)
Schedule M SCHMAT 1 938,633 SGCT 5.8294%54,717
Schedule M SCHMAT 1 (207,540)UT Situs
Schedule M SCHMAT 1 207,540 NUTIL 0.0000%
Schedule M SCHMAT 1 1,078,549 SG 5.8070%62,631
1,078,549 59,340 7.7.1
Schedule M SCHMDT 1 1,078,549 SG 5.8070%62,631
Schedule M SCHMDT 1 (37,806)SE 6.4493%(2.438)
ScheduleM SCHMDT 1 37,806 SG 5.8070%2,195
Schedule M SCHMDT 1 (12,569,707)OR Situs
Schedule M SCHMDT 1 12,569,707 OTHER 0.0000%
1,078,549 62,389 7.7.1
Deferred Tax Expense 41010 1 23,618.512 OTHER 0.0000%
Deferred Tax Expense 41010 1 30.921,206 GPS 5,6106%1,734.876
Deferred Tax Expense 41010 1 (214.379)1ST -13.8346%29,658
Deferred Tax Expense 41010 1 615,673 NUTIL 0.0000%
Deferred Tax Expense 41010 1 2,565,446 SE 6.4493%165,452
Deferred Tax Expense 41010 1 (4,113,666)SG 5.8070%(238.881)
Deferred Tax Expense 41010 1 28.238,440 SNP 5.5053%1,554,611
Deferred Tax Expense 41010 1 (13,115,623)SO 5.6106%(735,870).Deferred Tax Expense 41010 1 415,797,945 TAXDEPR 5.8811%24,453,431
Deferred Tax Expense 41010 1 (510,329,764)10 Situs (27,573.011)
(26,016,210)(609,733)7.7.2
Deferred Tax Expnse 41110 1 (11,695,418)OTHER 0.0000%
Deferred Tax Expnse 41110 1 (24,762,096)CIAC 4.6622%(1.154,455)
Deferred Tax Expense 41110 1 291,290 1ST -13.8346%(40,299)
Deferred Tax Expense 41110 1 (469,538)NUTIL 0.0000%
Deferred Tax Expense 41110 1 (184.134,435) iCHMDEXI 5.4264%(9,991,873)
Deferred Tax Expense 41110 1 1,334,666 SE 6,4493%86,076
Deferred Tax Expense 41110 1 1,322,235 SG 5.8070%76,782
Deferred Tax Expense 41110 1 (23,155,615)SNP 5.5053%(1,274,786)
Deferred Tax Expense 41110 1 (833,521)SNPD 4.6622%(38,860)
Deferred Tax Expense 41110 1 21,688,796 SO 5.6106%1,216,879
Deferred Tax Expense 41110 1 246,429,846 10 Situs 12,661,839
26,016,210 1,541,302 7.7.2
Description of Adjustment:
This adjustment corrct the allocation factor for both current and deferred taes
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IDAH REVISED PROTOCOL Pa 8.0 TotaM"is Rate Base Adjusbnts (Tab 8)
TOTAL
8.1 8.2 8.3 8.4 8.5 8.6 8.6.1.Environmental Customer
Update Cash Trapper Mine Rate Jim Brdger Mine Settemenl Advances lor Pro Fora Major Tax -plant
Total Normalized Working Capital Base Raie Bae (PERCO)Constrcton Plant Additons additions
1 Operatig Revenues:
2 General Business Revenues
3 Inlerdepartmental
4 Specal Sales
5 Oter Operati Revenues
6 Totl Opeating Revenues
7
8 Operating Exenses:
9 Sleam Proucon
10 Nuclear Producti
11 Hyro Producton (2,338)
12 Oter Po Supply
13 Transmission
14 Distruti
15 Custoer Acnting
16 Customer Serice & Info
17 Sale
18 Admiistrtive & General
19 Total 0&1. Exenses (2,338)
20 Derecation (677)21 Amzatin (40.329)
22 Taxes Oter Than Income
23 Inco Taxes: Federal (8,487,306)(8,464.025)24 State (1,153.284)(1,150,120)
25 Defer Income Taxes 9,675,914 9,614.145
26 Investmt Tax Creit Adj.
27 Mie Revenue & Exense (49.736)
28 Tota Opeatig Exenses:(57,755)0
29
30 Opertig Rev For Return:57,755 (0)
31
32 Rate Base:
33 Elec Plant in Service 86,170,416 643,670 11.106,391 74,464,547
34 Plant Held fo Future Use (750,560).35 Mise Deferred Debits (96,492)
36 Elec Plant Acq Adj
37 Nuclar Fuel
38 Prpayments
39 Fuel Stoc 2.036.930
40 Material & Supplis
41 Woring Capital (635.302)7,008
42 Weatheriation Loans
43 Mise Rale Bae
44 Total Elec Plant 86.724.992 7.008 643.670 11,106.391 74,464.547
45
46 Deucts:
47 Accum Pr For Depree 28,129
48 Acum Pr For Amort
49 Accum Def Income Tax (4.701.291)(4,607.073)50 Unamoed rrc
51 Customr Ad For Const (228,897)(228,897)
52 Custo Servic Deposit
53 MisceUaneus Deuctons (556,421)(625.817)
54
55 Total Deducts:(5,460,480)(625.817)(228.897)(4.807.073)
56
57 Total Rate Bae:81.264.512 7.008 643.670 11,106,391 (625,817)(228.897)74.464.547 (4,807.073)
58
59
60 Estimated ROE impact .1.843%0.00%-0.017%-0.288%0.017%0.006%-1.725%0.128%
61
62
63
64 TAX CACULATION:
65
66 Operatig Revenue 93,080
67 Oter Deucts
88 Interest (AFUDC)
69 Inlerest
70 Schedule"M" Aditios 2.811,429 2,910,765
71 Schule"M" Deducts 28.307,239 28.243,813.72 Income Before Tax (25,402,730)(25,333,049)
73
74 State Inco Taxes (1.153,284)(1,150,120)
75
76 Taxble Incoe (24.249,446)(24,182.928)
77
78 Federl Inco Taxes (8,87,306)(8,464.025)
IDAHO R~ED PROTOCOL Page 8.0.1 Totl
Mise Rale Base Adjusts (Tal
TOTAL
8.7 8.8 8.9 8.10 0 0 0 0.Milaneous Poale Hyro Go Creek
Rate Base Removal Trasmission FERC 105 (PHFU)0 0 0 0
1 Operting Revenues:
2 Generl Business Revenues
3 Interdepartental
4 Special Sale
5 Other Operating Revenues
6 Totl Operating Revenues
7
8 Operatig Expenses:
g Steam Producton
10 NucJ Prouct
11 Hydro Pruction (2.338)
12 Oter Por Supply
13 Transmsion
14 Ditrutin
15 Custo Acnting
16 Customr Seice & Info
17 Sale
18 Admiistratie & General
19 Totl O&M Exnses (2,338)20 Depreatin (677)21 Amtion (40.329)22 Taxes Oter Than Inome
23 inc Taxes: Federal (23.507)226
24 State (3.194)31
25 Derrd Inco Taxes 42.894 18.875
26 Investment Tax Creij Adj.
27 Mise Revenue & Expense (49.736)28 Totl Operating Expenses:(26,74)(31,281)
29
30 Opeating Rev For Retum:26,474 31,281
31
32 Rate Bae:
33 Elect Plant in Service (44,192)
34 Plant He for Future Use (750,560).35 Mie Deerd Deits (96,492)
36 Elec Plant Acq Adj
37 Nuclear Fuel
38 Prpayments
39 Fuel Stok 2,036,930
40 Mateal & Supplies
41 Wcring Capil (642,310)
42 Weathriatin Loans
43 Mie Rate Base
44 Totl El Plant:1,394.620 (96,492)(44,192)(750,560)
45
46 Deuctons:
47 Accum Prov For Depre 26.12948 Acm Prv For Amrt
49 Ac De Inco Tax 72,750 33,032
50 Unamorze ITC
51 Customr Mv For Const
52 Custor Sere Deposits
53 Miscllaneous Deucts 69,396
54
55 Total Deuctons:72,750 128.557
56
57 Totl Rate Ba:1.394,620 (23,742)84,36 (750.560)
58
59
60 Estite ROE imact -D.037%0.011%0.010%0.020%0.00%0.000%0.000%0.000%
61
62
63
64 TAX CALCULATION:
65
66 Opratig Revenue 42,667 50.413
67 Oter Dectns
68 Interest (AFUDC)
69 Intet
70 SCedule OM" Mdilons (99,336)
71 Schedule OM" Deductions 13.689 49.736.72 Inco Before Tax (70,358)677
73
74 State Incoe Taxes (3,194)31
75
76 Taxable Inco (67.164)64
77
78 Feder Income Taxes (23,507)226
Rocky Mountain Power
Idaho Results of Operations. December 2008
Update Cash Working Capital
PAGE 8.1.
CWC
CWC
CWC
1
2
3
TOTAL IDAHO
COMPANY FACTOR FACTOR % ALLOCATED REF#
45,650 WY-ALL Situs 45,650
(37.211 )WY-ALL Situs (37,211)
1.646 WY-ALL Situs 1,646
10,085 10,085
Adjustment to Rate Base:
Cash Working Capital
Cash Working Capital
Cash Working Capital
ACCOUNT ~
Adjustment Detail:
Type1 Type 2 Type 3
O&M Expense 183,655,773 183,726,631 192,281,424 1.1
Taxes Other Than Income Tax 4,904.875 4,904.875 5,412,229 1.1
Federal Income Tax (5,304,758)(8,190,192)(16,038,668)1.1
State Income Tax (452,206)(515,812)(1.602,135)1,1
Less: Embedded Cost Differential (4,406.069)(4,406,069)(4,406,069)
Total 178,397,616 175,519,433 175,646,782
Divided by Days in Year 365 365 365
Average Daily Cost of Service 488,761 480,875 481,224
Net Lag Days 4.72 4.72 4.72
Cash Working Capital 2,306,459 2,269,248 2,270,894
Unadjusted Cash Working Capital 2,260,810 2,306,459 2,269,248
Cash Working Capital Adjustment 45,650 (37,211 )1,646.
Description of Adjustment:
This adjustment is necessary to compute the cash working capital for the normalized results 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
th number of days in the year to determine the Company's average daily cost of service. The daily cost of service is multiplied by net
lag days to produce the adjusted cash working capital balance. Net lag days are calculated using the Company's December 2007
lead lag study. The Lead/Lag days for Wyoming were calculated as being 2.93 days.
.
Rocky Mountain Power PAGE 8.2
Idaho Results of Operations. December 2008.Trapper Mine Rate Base
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Expense:
Other Tangible Property 399 1 6,344,994 SE 6.449%409,205 Below
399 3 3,635,550 SE 6.449%234,466 Below
9,980,545 643,670
.
.
Adjustment Detail
December 2007 Balance
December 2008 Balance
Average Balance
6,459.832
6,230,157
6.344,994
8.2.1
December 2008 Balance
December 2009 Balance
Average Balance
6,230.157
13,730.933
9,980,545
3.635,550
8.2.1
8.2.1
Adjustment to Dec 08/Dec 09 Average Balance Above
Description of Adiustment:
PacifiCorp owns a 21.40% interest in the Trapper Mine, which provides coal to the Craig generating plant. The normalized coal
cost of Trapper includes all operating and maintenance costs but does not include a return on investment. This adjustment adds
the Company's portion of the Trapper Mine plant investment to rate base, This investment is accunted for on the Company's
books in Account 123,1 - Investment in Subsidiary Company. However, Account 123 is not normally a rate base account. This
adjustment reflects net plant rather than the actual balance in Account 123 to recognize the depreciation of the investment over
time.
.Page 8.2.1
Rocky Mountain Power
Results of Operations - December 2008
Trapper Mine Rate Base
DESCRIPTION Dec-07 Dec-08 Dec-09
Inventones 4,244,472 4,938,442 5,037,211 4,987,826
Prepaid Expenses 475,507 339,449 346,238 342,843
Propert, Plant, and Equipment
Lands and Leases 9,531,921 9,531,921 9,531,921 9,531,921
Development Costs 2,834,815 2,834,815 2,834,815 2,834,815
Equipment and Facilties 79,814,423 82,243,752 123,077,311 102,660,532
Total Propert, Plant, and Equipment 92,181,159 94,610,488 135,44,047 115,027,268
Accumulated Depreciation (76,788,786)(79,479,879)(83,999,247)(81,739.563)
Total Propert, Plant, and Equipment 15,392,373 15,130,609 51,444,800 33,287,705
Restricted Funds: Self-bonding for Black Lung 528,323 522,563 516,802 519,683
Total Restricted Funds 528,323 522,563 516,802 519,683
Deferred GE Royalty Amount 9,545,455 8,181,818 6,818,186 7,500,002
.
.
TOTAL RATE BASE 64,163,237 46,638,05930,186,130 29,112,881
PacifiCorp's Share of Trapper is 21.4%13,730,9336,459,832 6,230,157 9,980,545 to Page 8.2
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Rocky Mountain Power
Idaho Results of Operations - December 2008
Jim Bridger Mine Rate Base
PAGE 8.3
Adjustment to Rate Base:
Other Tangible Property
Other Tangible Property
ACCOUNT ~
TOTAL IDAHO
COMPANY FACTOR FACTOR % ALLOCATED REF#
159,004,771 SE 6.449%10,254,618 Below
13,207,318 SE 6.449%851,773 Below
172.212,089 11,106,391
399
399
1
3
Adjustment Detail
Dec 2007 Balance
Dec 2008 Balance
Dec 2007-2008 Avg Balance
Dec 2008 Balance
Dec 2009 Balance
Dec 2008-2009 Avg Balance
8.3.1
8.3.1
152.126.000
165,883.543
159,004,771
165,883,543
178,540,636
172,212,089
8.3.1
8.3.1
Adjustment to Dec 2009 Avg Bal 13,207,318
Description of Adjustment:
PacifCorp owns a two-thirds interest in the Bridger Coal Company (BCC). which supplies coal to the Jim Bridger generating plant. The
Company's investment in BCC is recorded on the books of Pacific Minerals, INC (PMI), a wholly-owned subsidiary. Because of this
ownership arrangement, the coal mine investment is not included in Account 101 -Electric Plant in Service. The normalized costs for
BCC provide no return on investment. The return on investment for BCC is removed in the fuels credit which the Company has
included as an offset to fuel prices leaving no return in results. This adjustment is necessary to properly reflect the BCC plant
investment in the 12-month period.
.
.
.
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Rocky Mountain Power
Idaho Results of Operations. December 2008
Environmental Settlement (PERCO)
PAGE 8.4
Adjustment to Rate Base:
TOTAL IDAHO
ACCOUNT ~ COMPANY FACTOR FACTOR % ALLOCATED REF#
Unspent Environmental Proceeds SO (625.817) 8.4.25.611%25399 (11.154,121)
Description of Adjustment:
The Company received an insurance settlement of $38 milion for environmental clean-up projects. These funds were
transferred to a subsidiary called PacifiCorp Environmental Remediation Company (PERCO). This adjustment reduces rate
base by the amount of unspent cash proceeds on regulated projects from the insurance settlement.
.
.
.
Page 8.4.1
Rocky Moutain Power
Results of Operations. December 2008
Pacifcorp Environmental Remediation Co.
Spending by Environmental Project
Cash Cumulative Remainin Acual Cumulative Remain
Received Actl Spending Cash at Spendin Actual Spending Cashal
Site WBS 1996 & after thr Dec 31,207 De 31. 2007 Jan-De 08 thr Oec 31, 2008 Dec 31, 2008
American Barel PERCll997/E1001 1,446,295 153,269 1.599,565
Astoria I Unol PERC/1997/E1oo2 1,140,182 187.240 1,327.422
Eugene - PacifCorp PERCl1997/E1003 299.901 13,795 313,696
Everett. Pacifp PERCl19971E004 (36,023)760 (363,263)
Joran I Barbe Tar PERCl19971E005 41,628 41,628
Ogden PERCll997/E100 68,876 68,876
Tacoma A Stree PERCl19971Eoo7 632,197 (3,648)628.549
Tacoma River St PERCl1997IEoo8 1.05,06 1,054,06
Briger GW Sampling PERCl1997IEoo9 525,765 13.123 538,888
Briger LandfiH Repemiling PERCl1997/E110 51,891 51,891
Briger OU Spil PERCl1997/E1011 374,402 374,402
Carb Fue Oil PERCl19971E012 15,781 15,781
Carb Landfin Permit PERC/1997/E/013 23,034 23,034
Carbo Emerg. Ge. Remediation PERCl19971E014 16,598 16,598
Centalia Heavy Equipment Shop PERC/1997/E1013 2,380 2,380
Dave Jotvton GW Sampling PERCl19971E016 231,581 231,581
Dave Jotvton Landfil Repemit PERCll997/E1017 73,439 73,439
Dave Johton Diesel Release PERCl1997/E1018 528 528
Dave Jotvton Landl Closue PERCl19971E019 269,474 269,474
Dave Johton Landl Reclamation PERCl19971E020 288,190 288,190
Far GW Moorin. Hunter PERCl1997/E1021 234.581 590 235.171
Farm GW Monitoring - Hunington PERCl19971E022 273,080 20 273.287
Hunter Fue au PERCl1997/E/023 47,941 14,412 62,353
Hunter Injecion Wells PERCll997/E1024 329,674 329,674
Huner Landfin Perit PERC/1997/E125 56,914 56,914
Hunington injio WeHs PERC/1997/E1026 9,416 9,416
Huntington Land Clour PERCl1997/E127 1,050,753 1.187,039 2,237,792
Huntington Landl Permit PERCl1997/EI028 46,984 46,984
Huntington Lead Paint Removal PERC/1997/E129 1.315,68 1,315,468
Huntington Wellhead Protecion PERCl19971E030 14,052 14,052
Bured Pitch PERCl1997/E/031 78,44 78,446
Tank Farm PERCll997/E1032 13,341 11,167 24,50
Naughton FGD Pond Closure PERCl19971E33 329,680 20,755 350,434
Nauhton GW Mooring PERCl19971E034 257,90 78 257,982
Naughton Landdl Repeit PERCl1997/E135 30,011 30,011
Nauhton LandH Closure PERCl1997/E1036 5,975 5,975
Wyoak Pon Stu PERCl19971E037 n.037 769 n,807
Wyoak Fue Oil PERCll997/E1038 33,542 76 33,617
Bank Stabilizio & Restotation PERCl1997/E139 233,772 3,092 236,86
Restor River Embankmens PERCl1997/E1040 19,498 19,498
Cuter PERCll9971E041 76,56 76,560
Bank Stabiiztion & Restoratio PERCll9971E42
Me Hatchery Fix Erosio Problems PERCl1997/E1 94,425 94,425
Speyai Hatche StabUiz River Bank PERCll997/E1045 668 68
No. Umpq Erosio Repair PERCll997/E1046 32,205 32,205
Klmath Riv Doestic Water Studies PERCl1997/E104 4,176 4.176
No. Umq Remove Contaminated SoUs PERCll997/E1052 46 464
Rogue River Domestic Water Stuies PERCl1997/E1053 1,90 1,90
UST Removal PERCll997/E154 4,786 4,786
Led Pain Removal PERCll9971E055 386,611 386.611
Arvx I PERCll9971E1056 700,711 5,931 706,643
Cedar Diesel PERCll9971E57 73,404 73,404
Holiday Gun Club PERCll9971E058 709,275 709,275
Jodan Substation PERCll9971E1059 425.046 48,627 473,673
Montague Ranch PERCl19971E060 511,195 46,052 557.247
Ross Island Tow Clean-p PERCll997/E1061 332,598 332,598
Spi Prevenion. Conainmnt and Conteieasi PERCll997/E1062 2,829,655 56,574 2,88,229
Ashton Sutatio PERCl1997/E1070 3,271 3,271
Rock Sprngs Plant Substation PERCl1997/E1071 3,733 3,73
Sincair Substation PERCll997/E1072 99 99
Parc Substation PERC/19971E73 4,20 4,206
Garlnd Substatin PERCl19971E074 14,593 14,593
Deter Substation PERCl1997/E1075 43,185 43.185
Wyo Sustation PERCl19971E076 33,705 33,705
Sail Lake Auomolive Shop PERCl1997/E1077 130,033 130,033
Ver Diesel PERCl19971E78 1.40 1,408
Sail Lae Terinal au Spill PERCl19971E1079 9,756 9,756
Brier Col Fue au Spin PERCl19971E/080 48,001 83,605 563,80Ba Pro PERCl1997/E1081 15,873 15,873
Col Creek PERCll997/EI02 1,415 1,415
Page 8.4.2.Rocky Moutain Power
Result of Operations. December 2008
Pacificorp Environmental Remediation Co.
Spendin9 by Environmental Project
Cash Cumulative Remaining Actual Cumulative Remaining
Received Actual Spending Cash at Speing Actual Speing Cash at
Sie WBS 199 & after tti De 31. 207 De 31. 2007 Jan-Dec 08 thru Dec 31. 2008 De 31. 2008
Ekotek I PetroChem PERC/1997/E/083 35,779 35,779
Environmental Pacifc PERC/1997/E/084 1,611 1,611
Montainer Refine PERC/1997/E/085 39 39
Norhwst Tnangle Propert PERC/1997/E/086 388 388
Pineale PERC/1997/E/087 113,985 113,985
PCB,lnc.PERC/1997/E/088 143,312 143.312
Poabe Equipmnt GW PERC/1997/E19 (259,086)(259,086)
Idaho Falls Pol Yard PERC/1997/E/09 I 091 2,775,927 380,280 3,156,207
Astoria Steam Plant PERC/1997/E/092 529,90 529,908
Ber River Erosion Control PERC/1997/E13 3,394 3,394
Bever Bay Drainfeld Cleanup PERC/199094 20,264 20,264
Bnger Boron Contaminated Soil Rem PERC/19981E/095 2,340 2,340
Briger Coal Warese Spil PERC/1998/EI07 2,278 2,278
Brid9er Oi Spi (New Releases)PERC/1998/E/098 480,097 111,733 591,830
Cedar Steam Plant PERC/19981E/099 3,533 3,533
Centalia Mine Pond Reclamation PERC/199E/1oo 503,287 503,287
Coar Shoe Une Repair PERC/1998/E101 29.921 29,921
Mining Cental Warehose Cleanup PERCI19981E/102 60,116 22.512 82,628
De Creek Terce Slablization PERC/19981E/103 12.778 12,778
Doestic Water System Testing and Revie PERC/1998/E/104 64.180 588 64,768
Hale Plant Cleanup PERc/1998/E/105 300,828 30.828
Hunington Ash Storm Runff Pond PERCI199E/106 33,455 33,455
Hunington Lead Paint Removal PERC/19981E/107 143,979 143,979
Lead Paint Removal (1998 Funds)PERC/19981E/108 9,591 9,591
Lews I Sw Reservoir Cleanup PERC/199109 290,538 290,538
Lifon Pumping Station Cleanup PERC/19981E/110 401 401
Merw Oil Houe Removal PERC/199E/111 20.022 20,022
Naughton Souh Ash Pond Reclam PERC/1998/112 239,493 239,493
Ogden Pole Treating Remediation PERC/1998113.Speyai Well PERC/19981E/114 176 176
Big For PCB Soi Cla"-p PERC/203/123 103,407 103,407
Pw Deiver UST Compliance Audi PERCI3l/124 12,123 12,123
Bnger FGD Pond 1 Closure PERCIoo7/E/126 24.307 153.200 177,507
Hunington Plant Fue and Lube Oil Tank Farm PERC/2oo7/E/127 113,931 113.931
Olympi, WA PERC/2oo7/E/128 7,151 7,151
Powdale Cleanup PERC/207/E129 13.94 13,944
Linn Steam Plant PERCI13O 56.207 56.207
Porand Harb Source Conrol PERC/200E/131 3,463 3,463
Astoia You's Bay Or 401980 2,313,081 2,313,081
Siver Be I TelllJide (his cost center)Orr 401981 525.275 525.275
Attorney contingenc fee received
REGULATED TOTAL 38,624,232 26,116.849 12,507,383 2.706.522 28.823.372 9.800,860
Deembe 31,2008 BeglEnd Average
12131/07 12,507,383
12/1/08 9,800,860
11,154.121
Page 8.4
.
Rocky Mountain Power PAGE 8.5.Idaho Results of Operations - December 2008
Customer Advances for Construction
TOTAL IDAHOACCOUNT~COMPANY FACTOR FACTOR % ALLOCATED REF#Adjustment to Rate Base:
Customer Advance 252 1 337.812 CN 3,879%13,103Customer Advance 252 1 (130,469)10 Situs (130,469)Customer Advance 252 1 (558,637)OR SitusCustomer Advance 252 1 2,063,571 UT SitusCustomer Advance 252 1 3,090,714 WY-AII SitusCustomer Advance 252 1 653,403 WY-AII SitusCustomer Advance 252 1 (3,214,621 )WY-AII SitusCustomer Advance 252 1 29,124 NUTIL 0.000%Customer Advance 252 1 (51,465)CA SitusCustomer Advance 252 1 (298,807)WA SitusCustomer Advance 252 1 (1,920,625)SG 5.807%(111,531)0 (228,897)8.5.1
.
.
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 accunt.
fl
.
.
Rocky Mountain Power
Results of Operations. December 2008
Customer Advances for Construction
Beginning I Ending Average Basis:
Account Booked Allocation252CN (337.812)2521DU (32.656)2520R (528,986)252UT (9.170,461)252WYP (3.090,714)252WYU (653,403)
252WY-AII
252NUTIL
252CA
252WA
252SG
Total
(3,996)
(15.221 )
(5,039,434)
(18,872,684)
Correct Allocation
(163,125)
(1,087,622)
(7,106,890)
(3,214,621 )
29,124
(55,461)
(314,028)
(6,960,059)
(18,872,683)
Page 8.5.1
Adjustment
337.812
(130,469)
(558.637)
2,063.571
3,090,714
653,403
(3,214,621)
29,124
(51,465)
(298.807)
(1.920,625)
o
Rocky Mountain Power PAGE 8.6.Idaho Results of Operations. December 2008
Pro Forma Major Plant Additions
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Rate Base:
Steam Production 312 2 19,959,197 SG 5.807%1,159,031
Steam Production 312 2 87,554,225 SSGCH 5.663%4,957,771
Hydro Production 332 2 9,034,507 SG-P 5,807%524,634
Hydro Production 332 2 5,195,682 SG-U 5.807%301,713
Other Production 343 2 534.085,663 SG 5.807%31,014,356
Transmission 355 2 83,488,566 SG 5.807%4,848,181
Distribution - California 364 2 3,426,950 CA Situs
Distribution - Oregon 364 2 3,619,064 OR Situs
Distribution - Washington 364 2 1,169,546 WA Situs
Distribution - Utah 364 2 23,693,329 UT Situs
Distribution - Wyoming 364 2 4,278,069 WYE Situs
General Plant - Oregon 397 2 1,381,679 OR Situs
General Plant - Utah 397 2 227,707 UT Situs
General Plant - Idaho 397 2 303,278 10 Situs 303,278
General Plant 397 2 2,357,747 SO 5.611%132,285
General Plant 397 2 382,031 SG 5,807%22,185
General Plant 397 2 190.583 CN 3.879%7,392
Mining Plant 399 2 1,164,678 SE 6.449%75,113
Intangible Plant 303 2 2,636,657 SO 5.611%147,933
Intangible Plant 303 2 5,887,890 SG 5.807%341,910
Intangible Plant 302 2 21,336,421 SG-P 5,807%1,239,006
Total 811,373,470 8,6.2.Steam Production 312 3 66,270,211 SG 5.807%3,848,311
Steam Production 312 3 1,001,954 SSGCH 5,663%56,736
Hydro Production 332 3 15,655,635 SG-P 5.807%909,123
Hydro Production 332 3 1.038,730 SG-U 5.807%60,319
Other Production 343 3 341,969,445 SG 5.807%19,858,167
Transmission 355 3 78,555,578 SG 5.807%4,561,723
Distribution - California 364 3 2,129,079 CA Situs
Distribution - Oregon 364 3 5,941,867 OR Situs
Distribution - Utah 364 3 26,229,072 UT Situs
Distribution - Wyoming 364 3 5,887,314 WYE Situs
General Plant - Oregon 397 3 4,584,377 OR Situs
General Plant - Utah 397 3 2,241,717 UT Situs
General Plant - Wyoming 397 3 1,983,057 WYE Situs
Intangible Plant 303 3 1,700,000.00 SO 5.611%95,381
Total 555,188,034 8,6.2
Description of Adjustment:
This adjustment places into rate base one-half of the major plant additions totaling greater than $2 millon for the period January
2008 to December 2008. This adjustment also places into rate base one-half of the major plant additions totaling greater than
$2 millon for the period January 2009 to December 2009. 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 6.2
.
Rocky Mountain Power PAGE 8,6.1
Idaho Results of Operations. December 2008.Tax. plant additions
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR %ALLOCATED REF#
Adjustment to Tax:
Schedule M Additions SCHMAT 2 31,165,552 SG 5.807%1,809,784
Schedule M Additions SCHMAT 2 1,039,555 SSGCH 5,663%58,865
Schedule M Additions SCHMAT 2 44,164 SE 6.449%2,848
Schedule M Additions SCHMAT 2 14,793 CN 3.879%574
Schedule M Additions SCHMAT 2 1,032,117 ID Situs 7,336
Schedule M Additions SCHMAT 2 327,192 SO 5.611%18,358
Deferred Tax Expense 41010 2 (11,827,639)SG 5.807%(686,831 )
Deferred Tax Expense 41010 2 (394,521)SSGCH 5.663%(22,340)
Deferred Tax Expense 41010 2 (16,761)SE 6.449%(1,081)
Deferred Tax Expense 41010 2 (5,614)CN 3.879%(218)
Deferred Tax Expense 41010 2 (391,700)ID Situs (2,784)
Deferred Tax Expense 41010 2 (124,172)SO 5.611%(6,967)
Accum Def Income Tax Balance 282 2 5,913,820 SG 5.807%343,416
Accum Def Income Tax Balance 282 2 197,261 SSGCH 5.663%11,170
Accum Def Income Tax Balance 282 2 8,381 SE 6.449%541
Accum Def Income Tax Balance 282 2 2,807 CN 3.879%109
Accum Def Income Tax Balance 282 2 195,851 ID Situs 1,392
Accum Def Income Tax Balance 282 2 62.086 SO 5.611%3,483
Schedule M Additions SCHMAT 3 17,323,555 SG 5,807%1,005,979
Schedule M Additions SCHMAT 3 15,108 SSGCH 5,663%855.Schedule M Additions SCHMAT 3 1,318,973 ID Situs
Schedule M Additions SCHMAT 3 109,897 SO 5.611%6,166
Schedule M Deductions SCHMDT 3 483,766,196 SG 5.807%28,092,304
Schedule M Deductions SCHMDT 3 991,308 SSGCH 5.663%56,133
Schedule M Deductions SCHMDT 3 49,450,804 ID Situs
Schedule M Deductions SCHMDT 3 1,699,915 SO 5.611%95,376
Deferred Tax Expense 41010 3 177,019,646 SG 5.807%10,279,531
Deferred Tax Expense 41010 3 370,478 SSGCH 5.663%20,978
Deferred Tax Expense 41010 3 18,266,511 ID Situs
Deferred Tax Expense 41010 3 603,428 SO 5.611%33,856
Accum Def Income Tax Balance 282 3 (88,509,823)SG 5.807%(5,139,766)
Accum Def Income Tax Balance 282 3 (185,239)SSGCH 5.663%(10,489)
Accum Def Income Tax Balance 282 3 (9,133,256)ID Situs
Accum Def Income Tax Balance 282 3 (301,714)SO 5.611%(16,928)
Description of Adjustment:
Continued tax adjustment from pro-forma plant additions adjustment 8.6
.
Pag 8.6.2.Rocky Mountain Power
Results of Operllons . December 2008
Major Plant Additon Summar
JanD 10 Dee08 Plan Ads Ja9 to Dee9 Plan Adds Total Plant Adds
Desription Factor Plant Additions Monlhs Included in Adj Plant Addllions Mons Included in Adj Inclued In Ad!
Steam Production Planl:
Various SG 39,918,395 6 19,959.197 132,54,422 6 66,270,211 66.229,408
Various SSGCH 26,226,388 6 13,113.194 2,003,908 6 1.001,954 14,115,148
ChoUa 4 Environmental SSGCH 148.882,063 6 74.441.031 6 74.441.031
Totl Steam Planl 215,026,645 107,513,422 134,54,330 67,272,165 174,785,588
Hydro Procllon Plant:Vari SG.p 18,069,014 6 9,034.507 31.311,269 6 15,65.635 24.690.142
Varous SG-U 10,391.365 6 5.195.682 2,077,459 6 1,038,730 6.234,412
Total Hydro Plant 28,460,379 14.230,190 33,38,728 16,89,364 30,924,554
Other Production Plan:
Man90 II Wind Exnsion SG 124,972,998 6 62,486,499 6 62,486,99
Goono HiUs Wind Proect SG 183.751,191 6 91.875.596 6 91.875.596
High Plains Wind Prect SG 6 245,508,239 2 40,918.40 40,918.40
Rolling Hils Wind Project SG 6 205,145,490 12 205,145,490 205.145,490
Glenrock Wind Plant SG 199,426,199 6 99,713,100 4,419.221 6 2,209,611 101.922,710
Sevn Mile Hill Wind Plant SG 192,525,178 6 96.262.589 3,627,744 6 1,813,872 98.076,61
Glerok II Wind Project SG 6 86,643,499 12 66,84,499 66,643,499
Seven Mie Hil II Wind Proct SG 41,391,245 6 20.695.623 309,04 6 154,520 20,85,143
Chehalis SG 300,383,503 6 148,973,968 6 148,973,96
Chehalis Overhaul SG 10.217,58 6 5.108,792 6 5,108,792
Varous Wind Other SG 6 2,208,43 6 1,104,215 1,104,215
Varius SG 17,93.993 6 8,969,497 7,56,397 6 3,780.198 12.749,695
Tot Othe Plant 1,070,606,892 53,085,663 555,622,059 341,96,445 876,055,107
Transmission Plant:
Various SG 166.977.133 6 83.488.566 157.111.155 6 78.55,578 162.044.144
Tot Tranission Planl 166,977,133 83,488,566 157,111,155 78,555,578 162,044,144
Distrbution Planl:
Callomia CA 6,853,900 6 3,26,950 4,258.158 6 2.129.079 5.558.029.Oreon OR 7,23,128 6 3.619.06 11,883,733 6 5.941,867 9.56.931
Washingon WA 2,339,093 6 1,169,54 6 1.169.54
Utah UT 47,386,657 6 23,693,329 52,458.144 6 26,22,072 49.922,401
Idaho 10 6 6
Wyomin9 WYE 8,55,139 6 4,278,069 11.774,629 6 5,887.314 10.165,364
Totl Dlsirlbullon Plant 72,373.917 36,186,959 80,374,66 40.187,332 76,374,291
Genl Plant:
Calffomia CA 6 6
Oreon OR 2,763,357 6 1.381,679 9,168,754 6 4,58,377 5,966.055
Washington WA 6 6UtUT455,414 6 227,707 4,483,43 6 2;241,717 2,469,424
Idho 10 606,55 6 303,278 6 303,278
Wyin WYE 6 3,96,114 6 1,983,057 1,983,057
Genera SO 4,715,494 6 2,357,747 6 2,357,747GelCN381,167 6 190.583 6 190,583
General SG 764,063 (;382.031 6 382.031
Totl G_ral Planl 9,68,050 4,843,025 17,618,02 8,809,151 13.652,176
Mining Planl:
Coal Mie SE 2,329,356 6 1,164.678 6 1,164.678
Tot Mining Planl 2,329,356 1,164,678 1,164,678
Intible Plan:
General SO 5,273,314 6 2,636,657 3,40.000 6 1,700,000 4,336.657
Geeral SE 6 6
Geeral SG 11,775,780 6 5,887,890 6 5.887,890
Hydro Reliceiising SG-P 42,672.641 6 21,33,421 6 21,336,421
Total Intangible Plant 59.721,935 29,86,968 3,400,000 1,700,000 31,56,96
Tota Elecc Plant in Service 1,625,182,507 811,373,470 982,059,239 555,188,034 1,36,561,505
Ref8.6.4 Ref#8.6 Ref8.6.6 Ref 8.6
.
Page 8.6.3 .Rocky Moi,.mtain Power
Result of Operations. December 2008
Major Plant Addition Detail. Jan2008 to Dec2008
Jan08 to Dec08 Plant
Project Description Account Factor In-Service Date Additions
Steam Production
BlundeU Bottming Cycle 312 SG 2008 2,403,332
Carbn: U2 GENERATOR ROTOR REPLACEMENT 312 SG 2008 2,117,176
Cholla: CHOLUO Coal Unloading&Handling 312 SSGCH 2008 6,503,226
Cholla: CHOLU4 CAl Environmental Projects 312 SSGCH May-08 148.882,063
Chol 4: Finishing Reheater Replacemen 312 SSGCH 2008 2,897,012
Cholla: Choll Com:135 Car Rail Siding 312 SSGCH 2008 2,024,172
ChoUa 4: Economizer Replacement 312 SSGCH 2008 3,116,040
Cholla Unil4: TURBINE COMPONENT REPl.312 SSGCH 2008 4,865,996
Cholla Unil4: GENERA TOR STATOR REWED 312 SSGCH 2008 2,195,376
Cholla Unil4: BOILER OVERHAUL.312 SSGCH 2008 2,309,813
Cholla Comm: Well Field Int Water 312 SSGCH 2008 2,314,152
Dave Johnston: U1 - Turbine/Generator Inspectin 312 SG 2008 3,743,303
Dave Johnston: U2 Turbine-enerator Refurbishment 312 SG 2008 3,939,705
Dave Johnston: U1 - SSH Pendant Replace 312 SG 2008 3,174,945
Huntington: U1 Scrubber Tower Ex1emal Coating 312 SG 2008 2,113,652
Jim Briger: U4 Excittin Contrl Replacement 312 SG 2008 2.673,492
Jim Briger: U4 Clean Air - NOx 312 SG 2008 6,134,176
Jim Briger: U4 Reheater Replacement 312 SG 2008 6,220,063
Jim Briger: U4 Rewnd Main Generator Stator 312 SG 2008 2,929,200
Jim Briger: U4 SHPP Replace Lowr Bends 312 SG 2008 2,223,695
Jim Briger: U4 Coutant Slope Replacement 312 SG 2008 2,184,456
Steam Production Total 215,026,845
Hydro Production
Copeo 2 Eletral Overhaul 332 SG-P 2008 6,759,099
Nort Umpqua Implementation 332 SG.p 2008 11,309,916
Cutlr 2 Runner 332 SG-U 208 3,471,638
Cutlr 1 Overhaul 332 SG-U 2008 6,919,727
Hydro Production Total 28.460,379.Oter Prouction
Cunant Creek: UO OpFlex Cold Day Penormance 343 SG 2008 8,488,692
Chehali: U2 HGP Overhaul on CT2 343 SG 2008 10,217,584
lake Side Capitl Build 343 SG 2008 4,080,788
LAKE SIDE POWER OUTPUT IMPROVEMENT 343 SG 2008 5,369,514
Goonoe Hils Wind Project (94 MW)343 SG May-08 183,751,191
Glenrok Wind Plant (99 MW)343 SG Dec-08 199,426.199
Marengo II Wind Expansion (70.2 MW)343 SG Jun-08 124.972.998
Seven Mil Hil Wind Plant (99 MW)343 SG Dec-O 192,525,178
Seven Mil Hil II Wind Plant (19.5 MW)343 SG Dec-O 41,391,245
Chehalis 343 SG Sept.Q8 300,383,503
Other Prouctin Total 1,070,606,892
Transmission
Oakley-Kamas New 46kV line 355 SG 2008 2,553,791
Pleasant Grove Sub Conv to 138kV and 2nd 355 SG 2008 2,994,197
Yew Avenue Sub Const New Sub(Tetherow)355 SG 2008 199,018
Elk Hom InsO 115-12.5kV Two Fdr Sub 355 SG 2008 2,039,556
Commerce Sub: 138-12 5kV Sub 355 SG 2008 118,790
line 1 Conv to 115kV line 14 Cap Relief 355 SG 2008 12.746,358
CampbeU Sub Increase Capacit 355 SG 2008 4,258
Cozyle Build New 138-12.5kV Sub 355 SG 2008 18.36
Herrman Purch Sub Prop & Trans ROW 355 SG 2008 4.055,798
Tooele Depot IncrTmsfmr-Trans Capacit 355 SG 2008 538.117
Copeo 2 Eleal Overhaul 355 SG 208 1.367.463
BlundeH Bottoming Cycle 355 SG 2008 570,843
Copco 2 Install 230/115 Tranfir & Bi1r 355 SG 2008 7,405.690
Thre Mile Knoll Sub: New 345-138kV Sub 355 SG 2008 43,287,038
Path 18 Reliabillt Improvements 355 SG 2008 4,149,921
Chappel Ci1 Provide Svc to Jonah Field 355 SG 2008 11,927,716
Transmissio Relay Rep! Zone 3 Sellng 355 SG 2008 3,407,797
Troutale TRF Repl125MVA 230-69kV Tmsf 355 SG 2008 2,457,588
Craner Flat Substation - Instan 138 kV 355 SG 20 10,017,233
Goonoe Hills Wind Project (94 MW)355 SG 2008 10,571,895
Glenrok Wind Plant (99 MW)355 SG 2008 23,021.882
Marngo II Wind Expansion (70.2 MW)355 SG 2008 6.750,113.Seven Mile HiD Wind Plant (99 MW)355 SG 2008 16,173,976
Transmission Total 166,917,133
Page 8.6.4 .Rocky Mountain Power
Result of Operations - December 200a
Major Plant Addition Detail. Jan200a to Dec200a
JanOa to DecOa Plant
Project Description Account Factor In-Servce Date Additions
Distribution
Oakley-Kamas New 46kV Line 364 UT 2008 308,392
Wasatch Front Automated Meter Reading 364 UT 2008 20,009,167
Pleasant Grove Sub Conv to 138kV and 2nd 364 UT 2008 5,876,203
Yew Avenue Sub Const New Sub(Tetherow)364 OR 2008 2,138,230
Rivertn Sub Capacit Increase 25MV A 364 WY 208 4,748,956
Elk Hom Instl115-12.5kV Two Fdr Sub 364 WYE 2008 3,807,183
Commerce Sub: 138.12 5kV Sub 364 UT 208 5,539,510
Line 1 Conv to 115kV Line 14 Cap Relief 364 CA 2008 1,077,145
Wee Substation Increase Capacit 364 CA 2008 5.776,755
Campbell Sub Increase Capacit 364 OR 2008 2,994,531
Cozydale Build New 138-12.5kV Sub 364 UT 2008 3,786,927
Sutherlin Sub 5U36 Incr Cap Murphy LVL 364 OR 2008 2,105,368
Herrman Purch Sub Prop & Trans ROW 364 UT 2008 5.543,239
Toole Depot Incr Tmsfmr.Trans Capacit 364 UT 2008 2,429,173
Nort Salt Lake - Increase Capacit 364 UT 2008 3,894,046
Hopland Sub Increase Capacit 15.6MVA 364 WA 2008 2,339,093
Distribution Total 72,373,917
General
Wlliamette Ops Svc Ctr Land & Impivmnts 397 OR 2008 2,701,080
Yew Avenue Sub Const New Sub(etherow)397 SO 2008 414
Elk Hom Instl115.12.5kV Two Fdr Sub 397 SO 2008 595
Herrman Purch Sub Prop & Trans ROW 397 SG 2008 36,232
Lake Side Capitl Build 397 SG 2008 634
PO IVRAAR Agent Access Rtr 397 CN 2008 381,167
PO IVRAAR Agent Access Rtr 397 SO 2008 2,305,230
Contrl Center Disaster Recvei Improve 397 SG 2008 53,814
Contrl Center Disaster Recovery Improve 397 SO 208 2,403.775
Blundell Bottoming Cycle 397 SG 2008 14,030
Copeo 2 Install 230/115 T ranfrr & Brkr 397 OR 2008 62,277.Copeo 2 Install 2301115 Tranfrr & Boo 397 SG 2008 5,929
Three Mil Knoll Sub: New 345.138kV Sub 397 10 2008 606,556
Thre Mil Knol Sub: New 345.138kV Sub 397 SG 2008 390.922
Thre Mile Knoll Sub: New 345-138kV Sub 397 UT 2008 351,652
Chappel Crk Proide Svc to Jonah Field 397 SO 2008 5,479
Transmissi Relay Repl Zone 3 Settng 397 SG 208 43,557
Craner Flat Substatin - Install 138 kV 397 SG 208 38,716
Craner Flat Substatin - Install 138 kV 397 UT 2008 103,761
Glenrock Wind Plant (99 MW)397 SG 2008 24,824
Seven Mile Hil Wind Plant (99 MW)397 SG 208 47,370
Chehalis 397 SG 208 108,035
General Total 9.6116,050
Mining
DEER CREEK M!NE-(l) CONTINUOUS MINER 399 SE 2008 2,329,356
Mining Total 2,329,356
Intangible
Wasak:h Front Autmate Meter Reading 303 SO 2008 2,880,061
LI Lew River Reliensing Superir 302 SG.p 2008 14,388.841
Mei Relicensing of Projet 302 SG-P 200 11.043,345
Swi Reliensing of Proect 302 SG-P 2008 10,468.149
LI Rogue Relicensing-Hydro South 302 SG-P 2008 6,772,506
Lake Side Capitl Build 303 SG 2008 (476)
PO IVRAAR Agent Access Rtr 303 SO 2008 2.393,252
Htg Water Effiency Mgt Project 303 SG 2008 11,776,256
Intangible Totl 59,721.935
1,625,1112,507
Ref# 8.6.2
.
Page 8.6.5.Rocky Mountain Power
Results of Operations - December 2008
Major Plant Addition Detail. Jan2009 to Dec2009
Jan09 to Dec09 Plant
Project Description Account Factor In-Service Date Additions
Steam Production
Dave Johnston: UO-CY Fire PROT RPLCE - TRPER Decks BSTR PMP 2009 312 SG Dec-09 2,174,909
Hunter: 300 Gen Coal Handling CY 2009 312 SG Nov-09 2,937,098
Hunter: 300 Adobe Wash Reservoir 312 SG Dec-09 2,561.163
Carbon: U1 Condenser Re- Tube 312 SG Jun-09 2,177,650
Cholla Com:BA Water System Capacity Imp 312 SSGCH Dec-09 2,003,908
Dave Johnston: U4 - BLR CNTRLSITURBINE CTRLS 312 SG Jul-09 11,157,761
Dave Johnston: U4 - BOILER WW TUBE PANEL REPLACEMENT 312 SG Jun-09 4,678.505
Dave Johnston: U4 - REPLACE BOILER COUTANT SLOPE 312 SG Jun-09 3,690,317
Dave Johnston: U4 - REPLACE REHEA TER 312 SG Jun-09 8,323,302
Dave Johnston: U4 - Cooling Tower Rebuild 312 SG Dec-09 5.932,994
Dave Johnston: U4-Boiler Economizer/Low Temp SH Upgrade 312 SG Jul-09 22,727,822
Dave Johnston: U4 - Generator Refurbishment 312 SG Dec-09 2.752,413
Dave Johnston: U4 - Turbine Inspection 312 SG Dec-09 2,629,980
Jim Bridger: Soda liquor Storage 312 SG Apr-09 3,595.172
Jim Bndger: U2 Excitation Control Replacement 312 SG Jun-09 3,034.132
Jim Bndger: U2 Reheater Outlet Terminal Tubes 312 SG Jun-09 4.140,628
Jim Bndger: U2 Coutant Slope Replacement 09 312 SG Jun-09 2,500,050
Naughton: U3 OH Boiler Waterwall Tube Replacement 312 SG Apr-09 3,508,925
Naughton: U3 OH Replace 3 LP FWHs 312 SG Jun-09 2,288,778
Naughton: U3 OH Generator Rotor Replacement (Seed 312 SG May-09 2,919,490
Naughton: U30H Replace Rotating Exciter 312 SG May-09 2,128,450
Naughton: U3 OH Base Turbine Overhaul HP/iP/LP 312 SG May-09 3,823,009
Naughton: U3 OH Coutant Slope Tubing Replacement 312 SG May-09 2,364,420
Naughton: U3 OH Cooling Tower Rebuild & Upgrade 312 SG Apr-09 4,796.684
Dave Johnston: U4 NOX 312 SG Dec-09 8,993.773.Jim Bndger: U2 S02 & PM Em Cntrl Upgrades 312 SG Sep-09 16.702.997
Steam Production Total 134,54,330
Hydro Production
ILR 10,2 Swift Land Fund 332 SG-P Jun-09 3,880,544
Lifton Pump #2 Motor Rewind 332 SG-U Sep-09 2,077,459
ILR 6.1.2 Lewis River Upper Flow Release 332 SG-P Sep09 2,918,735
ILR 8.7 Lewis Hatchery Pond 15 Mod/Cn 332 SG-P Sep-08 4,243,442
INU 14.2 CW2 Canal Shutoff & Drain 332 SG-P Mar-09 4,902.363
INU 14.2 Lemolo 2 Canal Shutoff & Drain 332 SG-P Dec-09 7,956.092
INU 11.5 Lemolo 1 Forebay Expansion & We 332 SG.p Oct-09 4,023,710
INU NU Communications Watson Ridge 332 SG-P Nov-09 3,386,383
Hydro Production Total 33,388,728
Other Production
Currant Crek: UO GSU Main Transformer Spare. ST 343 SG Dec-09 2,669,645
Chehalis: U1 CSA Vanable fee. CT1A 343 SG JuI-09 4,890,752
Glenrok Wind Plant (99 MW)343 SG Dec-08 4,419,221
GSU Tmsfrr Capital Spare 343 SG Oct-09 2,208,430
Glenrock II Wind Plant Project (39 MW)343 SG Jan-09 86,843,499
High Plains Wind Plant Projec (99 MW)343 SG Nov-09 245.508.239
Rollng Hils Wind Project (99 MW)343 SG Jan-09 205,145,490
Seven Mile Hil Wind Plant (99 MW)343 SG Dec-08 3,627,744
Seven Mile Hil II Wind Plant (19.5 MW)343 SG Dec-08 309,040
Other Production Total 555,622,059
.
.
Rocky Mountain Power PAGE 8.7
Idaho Results of Operations.December 2008.Miscellaneous Rate Base
TOTAL IDAHO
ACCOUNT ~COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment Rate Base:
1 - Cash OWC131 (11,667,121)SNP 5.506%(642,372)2.33
2 . Fuel Stock 151 3 26,916,186 SE 6.449%1,735,893
2 - Fuel Stock 151 3 4,943,656 SSECH 6.089%301,038
31,859,842 1,394,559 8.7.1
.
.
Description of Adjustment:
1 - In order to avoid earning its ROR rate on its cash balance. the company is removing the balance from rate base via this adjustment.
2 - The cost of the company's coal plant fuel stock is increasing due to increases in the cost of coal and the number of tons stored at each
site. This adjustment reflects the increase in the fuel stock balance into results.
.
.
.
IXo~..
~
3
~ GI II.. . II 3
GI II IV C!=CCDIVOO..Glii
i: :¡ IV CDc I! ir .¥Š !. II gco 5'":S.. GI eno 0 c-::1I~!
::': ãi u..¥:SU-g=.!~ir ir :: 0
Ol N CD co 0)"" 0 0 LO,. (õ~S GlLO~LONo)~M~""CDLONOl~1X~ g ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ 0GlE~~g~~~~~~~~~~~~~IV ,. ,. 0) NOM M M..o) ..0 ,. IX1iCD . .. . exÑ Ñ ~:s .. l"... ~
~ C(
_ ~,. 0) N CD 0) N co N N ~ co CD LO.. OlOlN""COo)O""O'OOMLO~g~ GI~~q~~q~~~~~~~~~~ g~~~~~~~~8~~~~ff_ c 1v00CONCOCO""LO~c...NMLOM~~iiÑ~M "'~~Ñ"'Ò ÓÑ~~~CD~.. ~N.. N ~
CD
(l enEo.. 0ONU. U
e GIii Q
ff ~ ~ g r: ~ ~ ~ ~ ~ ¡g.~ ió ~GI,,CX~~~~~~~~LO_~~~U ~ M .. ~ M 0 ,. CD c. 0 .. CO M NCOO ~ LO .. ,. M 0 LO 0 CO CO 0) LO1v0M..o)CD,.0~LO,.....~MiiC"Ñ~ "'~C"Ñ"'Ò "'Ñ~CD~.. LON.. N LO~
C)
~ ~ GI0"C UN C C;:W~0_ IV~ ~CD
CD
~~~~rõu;~~ig~g~~gs,.MMCDMMNMO..MOO)O
Ó ~.... ex ex ~ Ò~ C" ò Ño;ÒCO LO ,. NON NON N N N .. 0~..NC'CO~N..CD..MMMLO~~ex C"~r-Ó"'o; exC"o;~ NN.. 0..
M CO CO LO N CD 0 .. M N N ,. 0) c.N c. ~ CO 0 LO ~ ,. N M LO LO N LOIX GlO..NO'LOLON,.C'O'NLONOg U r- ex .. ex ai r- ex .. ~ cè ~ Ñ C" r-~ ¡18erer:~~¡gec.~c:;¡ig~
!iiiÑ~..- ~~exÑ"'o; cèÑr-..CD~.. MN .. NQ ....
cO
Q)
~rni6:s~ eO~~~~~g~~~~~~,. GI~c.~MN..MO'LOM~~c.Ol00 u "'"'"'Ór-ai"'~~o;ai~cèÑN COlOlLOMM~""o)O..o)O""M. IV ",CO N LO ~.. M,. c.,. N.. 0) c.!iiiOl ~ Ñ~cèr-..ex óC"~Õ CD .. .. N O'.. :iS U~WUJ~WWWWWWWWWW
u. en en en en en en en en en en en en en
ë:sou ..~~~~,.~ 'r'''''' ,.,.,.,.
LO LO LO LO LO LO LO LO LO LO LO LO'r ,. ,.,.,. ,.,. or ,.,. ,.,.
i:i: ~-~~§§~ffæ
..(¡§(l.g. !ä(¡i:ii1:Ua:(!C Cl.c = J! .2l"g"E 'Ë i: gi (¡ o.tj~:g æ~ 0 e: (l:S:S"Õ (l Q) ~ 0i: a: u U u u :i :i :i .. z c ii a:
.
.
Description of Adustment:
This adjustment reflects the treatment approved by the Commission in Docket No. PAC-E-07-04 to account for the
decommissioning of the Powerdale hydroelectric plant due to damage caused by a flood in November 2006. During 2007,
the net book value (including an offset for insurance proceeds) of the assets to be retired was transfered to the
unrecovered plant regulatory asset. In addition, future decommissioning costs are deferred as they are spent and
amortized over ten years, beginning in the subsequent year after they are spent.
.
.
.
Rocky Mountain Power
Results of Operations. Decmeber 2008
Powerdale Removal
Page 8.8.1
Description
Operation & Maintenance
OPER SUPERV & ENG
HYDROIOTH REC FAC
MSC HYD PWR GEN EX
RENTS (HYDRO GEN)
ACCESS ELEC EQUIP
MAINT HYDRO-OTHER
12 Months Ended
Account Factor Dec 2008 Expense Ongoing Expense Expense to Remove Ref
535 SG-P
537 SG-P
539 SG-P
540 SG-P
544 SG-P
545 SG-P
150.000
6,492
15.942
6,394
138
249
11,040
40,255 To 8.8
6,492
15,942
156,394
138
249
11.040
190,255 150,000
.Roc Mouln PowrR... of Openton.. Oebe 2_
Pøwrd Remol
P..nilo U_ro Piont Rear As'"
Gil Account Balance D/splay
\l ~urn!f Cur~Di"_ntcunc I,' SU""'
225.601,0
221 ,220.14 I
221,220,14
221,220,14 .
221.220.14
221,220.14 I
221.220,14 ,
221,220.1' i
221,220.14 i
~~~ :~~:: ~: i
i 221,220.1. i-"-r---'
1
4.387,36
I
2.59,029.04 I
Debe 207 Bane 7,86.925
Decbe 200 Balanc 5,30.283Debe 200 A"! Balanc 6.83.604
12 ME De 20 Amotio 2.85.642 RoII.8.3
Debe 200 Balo 2,85,64
De 08 ~ Dec 09 Avg Ba_ne 3.961,96.Ad to Dec 09 A"! Bane (2.85.642)To I..
.
cumiianiL
7,963.925,00 1
221,220'14- 7.742,704.861
221,220.14- 7,521,484.121
221.220,'4- 7,30,284.58 i
221.220,'4- 7,l79,04U4
221,220,'4- 1,857,824,30
221,220,14- 1.131.en4,16
221.220,14- 8,4'5.
221,220.'4-1 8,194,
22.220.14- 5,8
221,220.'4- 5.151.723.60:
-n ,220, ,¡: 5,530,503,~ i
221.220,1 ¡: 5.309.283,32 ,-- 5,i;ï:i
5.309.28332 ,
5.309.283,2 i
5.309.283,32 i
2.654.64U8-j 5.309.283,321
Powrd Unrcore Plant Amzaon
Gil Account Balance Display
o ! : .~'.'d:D_~~~_;;~(¿_~;n~~t'" ~'-;i_'-~~~ntë,Uf.i1~~irâõõ~~..nt~: ¡ :~,---~¡~
247.064.12 i
~~::::;: :~~:::~::: i
289,996,76 1.117.05i4õ
289,996.76 1.407.051,6!
289.991.76 1.697.047,92 i
289,996.76' ~:~~~:::::64-84-!.
j 289,896.76
. -2šS.16 2,5&7,038.iÕ¡
-, 289.996.78 2.857.034.96 J
289,99678 3.147.031,21
289,996,8 .__,~4.~7,~?8:~_i
3,437.02U8 i
3.437.02U81
3.437,02U8 ¡
3,437,02U8 i
3,437,02U8 ¡3,437,028.48 :
t
3,437,028.48 ¡
P_ 8.8.2
J...F_--oAprMo)"J..
JilOSAugSop
Oc-ONo..0..Totl
247.0S
289,997
289,997
289,997
28,997
289,997
289.997
289,997
289.997
289.997
289.997
289.997
3,437.028Toa.
.
.
.
Rocky Mountain Power
Results of Operations . Decmeber 2008
Powerdale Removal
Beg Balance
Amort May 07 . Dec 07
Balance Remaining to Amortize
Monthly Amort Exp
May-07
Jun-07
Jul-07
Aug-07
Sep-07
Oct-07
Nov-07
Dec-07
Jan-08
Feb-D8
Mar-D8
Apr-08
May-08
Jun-08
Jul-08
Aug-08
Sep-08
Oct-08
Nov-08
Dec-08
Amort
104,017
104,017
104,017
104,017
104,017
104,017
104,017
104,017
221,220
221,220
221,220
221,220
221,220
221,220
221,220
221,220
221,220
221,220
221,220
221,220
8,796,061
(832,136)
7,963,925
221,220
Balance
8,692,044
8,588,027
8,484,010
8,379.993
8,275,976
8,171,959
8,067,942
7,963,925
7,742,705
7,521,485
7,300,265
7,079,044
6,857,824
6,636,604
6,415,384
6,194,164
5,972,944
5,751,724
5,530,503
5,309,283
Jan-09 221,220 5,088,063
Feb-09 221,220 4,866,843
Mar-09 221,220 4,645,623
Apr-09 221,220 4,424,403
May-09 221,220 4,203,183
Jun-09 221,220 3,981,963
Jul-D9 221,220 3,760,742
Aug-09 221,220 3,539,522
Sep-09 221,220 3,318,302
Oct-D9 221,220 3,097,082
Nov-09 221,220 2,875,862
Dec-D9 221,220 2,654,642
Jan-10
Felr10
Mar-10
Apr-10
May-10
Jun-10
Jul-10
Aug-10
Sep-10
Oct-10
Nov-10
Dec-10
221,220
221,220
221,220
221,220
221,220
221,220
221,220
221,220
221,220
221,220
221,220
221,220
8,796,061
2,433,422
2,212,201
1,990,981
1,769,761
1,54,541
1,327,321
1,106,101
884,881
663,660
442,440
221,220
(0)
Page 8.8.3
Dec 2009 Amort = 2,654,642 To 8.8.2
llOCkY Mountain Poweresults of Operations. Decmeber 2008
Idaho Regulatory Treatment of Decommissioning Costs
Amortize actual cash spent over 10 years beginning in the year subsequent to the cash being spent.
Case No. PAC-E-07-04
Total
6,323,966
Cash Spend
Dec 2007
38,236
Dec 2008
840,718
Monthly Amortization Through December 2009
Dec 2007 Dec 2008
Spend Spend
.
Date
Dec-07
Jan-OS
Feb-OS
Mar-QS
Apr-OS
May-OS
Jun-QS
Jul-08
Aug-OS
Sep-OS
Oct-OS
Nov-OS
Dec-OS
Jan-09
Feb-09
Mar-09
Apr-09
May-09
Jun-09
Jul-09
Aug-Q9
Sep-09
Oct-09
Nov-09
Dec-09
Jan-10
Feb-10
Mar-10
Apr-10
May-10
Jun-10
Jul-10
Aug-10
Sep-10
Oct-10
Nov-10
Dec-10.
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
319
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
7,006
Dec 2009
323,62S
Dec 2009
Spend
2,697
2,697
2,697
2,697
2,697
2,697
2,697
2,697
2,697
2,697
2,697
2,697
Dec 2010
4,841,44S
Amort
Total
319
319
319
319
319
319
319
319
319
319
319
319
Dec 2011
92,424
Regulatory
Asset Balance
38,236
S75131
Page 8.8.4
Dec 2012
187,512
Average
Balance Reference
456684,,
7,325 "'
7,325
7,325
7,325
7,325
7,325 ~Decomm Amort = $87,895 Ref# 8.8 I7,325
7,325
7,325
7,325
7,325
7,325 I)1,110,863 992,997 Ref# 8.8
10,022
10,022
10,022
10,022
10,022
10,022
10,022
10,022
10,022
10,022
10,022
10,022 5,832,053 3,471,458
Rocky Mountain Power PAGE 8,9
Idaho Results of Operations. December 2008.Goose Creek Transmission
TOTAL IDAHO
ACCOUNT Type COMPANY FACTOR FACTOR % ALLOCATED REF#
Adjustment to Rate Base:
Remove CY 2008 Balances:
Transmission Plant In Service 350 1 (328,105)SG 5.807%(19,053)8,9.1
Accum, Provo for Depr 108TP 1 216,546 SG 5.807%12,575 8.9.1
Remove Future Retirement:
Transmission Plant In Service 350 1 (432,913)SG 5.807%(25,139)8.9,1
Accum. Provo for Depr 108TP 1 233,417 SG 5.807%13,555 8.9,1
Adjustment to Depreciation Expense:
Depreciation Expense 403TP 1 (11,656)SG 5.807%(677)8.9,1
Gain on Sale of Transmission Assets:
Reverse Amount as Booked 254 1 156,434 ID Situs 156,434
Unamortized Gain Balance 254 1 (87,038)ID Situs (87,038)8,9.3
Gain on Sale of Transmission Assets 421 1 (49,736)ID Situs (49,736)8.9.3
Schedule M SCHMDT 1 49,736 ID Situs 49,736
Deferred Tax Expense 41010 1 18,875 ID Situs 18.875
Accumulated Def Tax Balance 190 1 33,032 ID Situs 33,032.
Description of Adjustment:
On April 1, 2008, the Company sold 13.85 miles of transmission line, running from the Company's Goose Creek switching
station and extending north to the Decker 230 kV substation near Decker, Montana. The assets sold included structures.
miscellaneous support equipment, easements and rights-of-way associated with the transmission line. The sale of the
transmission line resulted in the Goose Creek switching station no longer being useful to the Company. The Company is
currently removing the Goose Creek switching station including all above ground facilties and leveling the site. This
adjustment amortizes the net gain associated with the sale over three years and reduces rate base by the net book value
of the assets sold.
.
.Rocky Mountain Power Page 8.9,1
Results of Operation. December 2008
Goose Creek Transmission Sale
Rate Base (Assets Retired)
Balance Balance Beg/End
FERCAcct Factor Dec 2007 Dec 2008 Average Reference
Transmission Line 350 SG 656,211 328,105 Page 8,9
Transmission Line Accum Depr 108TP SG (433,091 )(216,546)Page 8,9
Transmission Line Book Value 223,119 111,560
Switching Station 350 SG 432,913 432,913 432,913 Page 8,9
Switching Station Accum Depr 108TP SG (229,638)(237,197)(233,417)Page 8.9
Switching Station Book Value 203,275 195,716 199,496
12 Months Ended
FERCAcct Factor December 2008 Reference
Depreciation Expense 403 SG 11,656 Page 8.9
.
.
.
.
.
Rocky Mountain Power
Results of Operation. December 2008
Goose Creek Transmission Sale
Calculation of Gain
Proceeds from Sale:
Gross proceeds from sale
Closing Costs (tax proration & legal)
Net Proceeds from Sale
Less: Book Value of Transmission Line Sold
Book Value Dec 31, 2007
Depreciation for January 1, 2008 - April 1, 2008
Total Book Value as of April 1, 2008
Less: Book Value of Switching Station
Book Value Dec 31,2007
Depreciation for January 1, 2008 - April 1, 2008
Total Book Value as of April 1, 2008
Less: Cost to Remove Switching Station
Est. Cost of Removing Switiching Station
Net Gain on Sale of Transmission Line Assets
2,881,833
(32,680)
2,849,153
(223,119)
3,168
(219,951)
(203,275)
2,122
(201,153)
(94,750)
2,333,299
Page 8.9.2
.
..
.
,,
Jan-09 4,145 107,762
Feb-09 4,145 103,617
Mar-09 4,145 99,472
Apr-09 4,145 95,328
May-09 4,145 91,183
Jun-09 4,145 87,038
Jul-09 4,145 82,894
Aug-09 4,145 78,749
Sep-D9 4,145 74,604
Oct-09 4,145 70,460 20
Nov-D9 4,145 66,315
Dec-09 4,145 62,170 i.-
Rocky Mountain Power
Results of Operation. December 2008
Goose Creek Transmission Sale
Idaho. 3 Year Amortization Schedule
Total Gain from Sale of Asset
10 SG Factor % (Dec 2007)
10 Allocated Portion of Gain
Date
Jun-07
Jul-07
Aug-07
Sep-07
Oct-07
Nov-07
Dec-07
Jan-08
Feb-08
Mar-08
Apr-08
May-08
Jun-08
Jul-D8
Aug-D8
Sep-08
Oct-08
Nov-D8
Dec-08
Jan-10
Feb-10
Mar-10
Apr-10
May-10
Jun-10
Jul-10
Aug-10
Sep-10
Oct-10
Nov-10
Dec-10
Jan-11
Feb-11
Mar-11
2,333,299
6.395%
149,208
To 8.9.2
Amortization Unamort Balance
4,145
4,145
4,145
4,145
4,145
4,145
4,145
4,145
4145
145,064
140,919
136,774
132,630
128,485
124,340
120,196
116,051
111906
4,145
4,145
4,145
4,145
4,145
4,145
4,145
4,145
4,145
4,145
4,145
4,145
4,145
4,145
4,145
58,026
53,881
49,736
45,591
41,447
37,302
33,157
29,013
24,868
20,723
16,579
12,434
8,289
4,145
o
Beg/End Avg =
09 Amort Expense =
87,038
Ref#8.9
49,736
To 8.9
.
.
.
Rocky Mountain Power
Idaho Results of Operations. December 2008
FERC 105 (PHFU)
PAGE 8.10
Adjustment to Rate Base:
RemovePHFU
Remove PHFU
Remove PHFU
Remove PHFU
ACCOUNT ~
TOTAL IDAHO
COMPANY FACTOR FACTOR % ALLOCATED REF#
(11.866.680)SG 5,807%(689,098)
(953,014)SE 6.449%(61,462)
(1,193,035)UT Situs
(373,134)OR Situs
(14,385,863)(750,560) 8.10.1
105
105
105
105
1
1
1
1
Description of Adjustment:
This adjustment removes all Plant Held for Future Use (PHFU) assets from FERC account 105. The company is making this
adjustment in compliance with Title 16 of Public Utilty Regulation, chapter 5 "Powers and Duties of Public Utilties
Commission" section 61-502A,
.
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Rocky Mountain Power
RESULTS OF OPERATIONS
Page 9.1
USER SPECIFIC INFORMATION
STATE:
PERIOD:
IDAHO
DECEMBER 2008
FILE:
PREPARED BY:
DATE:
TIME:
10 JAM De 2008 Results
Revenue Requirement Department
4/24/200
4:31:17 PM
TYPE OF RATE BASE:
ALLOCATION METHOD:
Beinning/Ending
ROLLED-IN
FERC JURISDICTION:Separate Jurisdiction
80R 12 CP: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%
4.54%
1.614
37.951%
CAPITAL STRUCTURE INFORMATION
CAPITAL
STRUCTURE
EMBEDDED
COST
WEIGHTED
COST
DEBT
PREFERRED
COMMON
49.00Æi
0.40%
50.60%
100,00%
6.11%
5.41%
10.25%
2.993%
0.022%
5.187%
8.201%
OTHER INFORMATION
ROLLED.IN Page 9.2
BeginninglEnding
RESULTS OF OPERATIONS SUMMARY
UNADJUSTED RESULTS IDAHO
Ref TOTAL OTHER IDAHO ADJUSTMENTS ADJ TOTAL
1 Operating Revenues
2 General Business Revenues 2.3 3,444,033,189 3,246,290,278 197,742,910 4,363,364 202,106,275
3 Interdepartmental 2.3 °°°°°
4 Special Sales 2.3 860,950,758 811,459,199 49,491,559 10,095,239 59,586,798
5 Other Operating Revenues 2.4 189,602,040 181,259,429 8,342,611 391,899 8,734,510
6 Total Opeting Revenues 2.4 4,494,585,986 4,239,008,906 255,577,080 14,850,502 270,427,582
7
8 Operating Expenses:
9 Steam Production 2.5 894,912.140 838,909,429 56.002,710 1,854.320 57,857,031
10 Nuclear Production 2.6 °°°°°
11 Hydro Production 2.7 37,594,583 35,411,466 2,183,118 54,162 2,237,279
12 Oter Powr Supply 2.9 1,322,716,164 1,241,391,753 81,324,410 7,895,784 89.220,194
13 Transmission 2.10 174,010,394 163,881,399 10,128,995 631,470 10,160,465
14 Distribution 2.12 215,364,277 205,055.987 10,308,289 379,509 10,687,799
15 Customer Accounting 2.12 99,309,086 94,941,740 4,367,346 152,525 4,519,871
16 Customer Service & Infor 2.13 14,039,833 12,308,144 1,731,689 9,171 1,740,860
17 Sales 2.13 °°°°°
18 Administrative & General 2.14 170,044,138 162,723,926 7,320,212 3.210,955 10,531,167
19
20 Total 0 & M Expenses 2.14 2.927,990,614 2,754.623,845 173.366,769 14,187,897 187,554,666
21
22 Depreciation 2.16 408,039,444 385,895,925 22,143,520 2,850,222 24,993,742
23 Amortzation 2.17 57,142,964 54,333,177 2,809,786 14,037 2,823.823
24 Taxes Other Than Income 2.17 112,424,490 107,517,714 4,906,776 507,553 5,414,329
25 Income Taxes - Federal 2.20 17,832,747 19,616,406 (1,783.659)(12,679,889)(14,463,548)
26 Income Taxes - State 2.20 2,494,223 2,663,536 (169,313)(1,342,749)(1.512,062)
27 Income Taxes - Def Net 2.19 261,104,676 246,238,349 14.866,327 10,726,400 25,592,727
28 Investment Tax Credit Adj.2.17 (1,874,204)(1,654,465)(219,739)°(219,739)
29 Mise Revenue & Expnse 2.4 (7,004,252)(6,585,082)(419,170)33,282 (385,888)
30
31 Total Operating Expenses 2.20 3,778,150,701 3,562,649,403 215,501,298 14,296,752 229,798,050-Operating Revenue for Return 716,435,285 676,359,503 40,075,782 553,750 40,629,532
Rate Base:
36 Electric Plant in Service 2.30 17,252,000.564 16,283,674,484 968,326,080 86,267,707 1,054,593,787
37 Plant Held for Future Use 2.31 14,385,862 13,635,301 750.560 (750,560)(0)
38 Mise Deferrd Debits 2.33 148,502,262 144,105,516 4,396,747 (48,929)4,347,818
39 Elec Plant Acq Adj 2.31 69,085,936 65.074,116 4,011,821 °4,011,821
40 Nuclear Fuel 2.31 °°°°°
41 Prepayments 2.32 38,987,409 36,748,192 2,239,217 °2,239,217
42 Fuel Stock 2.32 115,236,521 107,804,628 7,431,893 2.054,721 9,486,615
43 Material & Supplies 2.32 159,789,695 150,455.201 9.334,494 °9,334,494
44 Working Capital 2.33 64,419,097 60,959,280 3,459,818 (690,757)2,769,060
45 Weatherization Loans 2.31 15,127.554 10,056,802 5,070,752 °5.D0,752
46 Miscellaneous Rate Base 2.34 4,314,182 4,006,87 307,695 °307,695
47
48 Total Electric Plant 17,881,849,083 16,876.520,006 1,005,329,077 86,832,182 1,092,161,259
49
50 Rate Base Deductions:
51 Accum Prov For Depr 2.38 (6.250,117,933)(5,886,507,374)(363,610,559)(1,398,263)(365,008,822)
52 Accum Prov For Amort 2.39 (406,297,379)(385,064,106)(21,233,272)(12,415)(21,245,687)
53 Accum Def Income Taxes 2.35 (1,476,614,252)(1,386,590,689)(90,023,563)(3,545.806)(93,569,369)
54 Unamortzed ITC 2.35 (9.730.900)(9,680,697)(50,203)164,585 114,382
55 Customer Adv for Const 2.34 (18,872,683)(18,534,285)(338,399)(228,897)(567,296)
56 Customer Service Deposits 2.34 °°°°°
57 Misc. Rate Base Deductions 2.34 (57,806,226)(54,647,331)(3,158,895)(3,401,506)(6,560,401)
58
59 Total Rate Base Deductions (8,219,439,373)(7,741,024,481 )(478,14,892)(8,422,301)(486,837,193)
60
61 Total Rate Base 9,662,409,709 9,135,495,525 526,914,185 78,409,881 605,324,066
62
63 Return on Rate Base 7.415%7.606%6.712%
64
65 Return on Equity 8.697%9.074%7,308%
66 Net Power Costs 1,107,954,703 72,002,931 65,353,826
67 100 Basis Points in Equity.Revenue Requirement Impact 78,795,457 4,296,904 4,936,324
Rate Base Decrease (617,268,812)(32,868,190)(42,43,568)
ROLLED-IN Page 9.3
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL..Sales to Ultimate Customers
440 Residential Sales
°5 1,345,013,663 1,286,561,943 58,451,721 (27,456)58,424,265
74 81 1,345,013,663 1,286,561,943 58,451,721 (27,456)58,424,265
75
76 442 Commercial & Industrial Sales
77 °5 2.060,710,026 1,921,886,078 138,823,948 4,390,820 143,214,768
78 P SE
79 PT SG
80
81
82 81 2,060,710,026 1,921,886,078 138,823,948 4,390,820 143,214,768
83
84 44 Public Street & Highway Lighting
85 °5 19,865,594 19.398,352 467.242 467,242
86 °SO
87 81 19,865,594 19,398,352 467,242 467,242
88
89 445 Other Sales to Public Authonty
90 °5 18,443.905 18,443,905
91
92 81 18,44,905 18,443,905
93
94 448 Interdepartmental
95 DPW 5
96 GP SO
97 81
98
99 Total Sales to Ultimate Customers B1 3,44,033.189 3.246.290.278 197,742,910 4,363,364 202,106.275
100
101
102
103 447 Sales for Resale-Non NPC
104 WSF 5 8,626,127 8,626,127
105 8,626,127 8,626,127.447NPC Sales for Resale-NPC
WSF SG 852,781.657 803,260,624 49,521,033 10,065,764 59,586,798
109 WSF SE (457,026)(427,552)(29,475)29,475 (0)
110 WSF SG
111 852,324,631 802,833,072 49,491,559 10,095,239 59,586,798
112
113 Total Sales for Resale 81 860,950,758 811,459,199 49.491,559 10,095,239 59,586,798
114
115 449 Provision for Rate Refund
116 WSF 5
117 WSF SG
118
119
120 81
121
122 Total Sales from Eleccit B1 4,304.983.947 4,057,749.478 247.234,469 14,458.603 261,693,072
123 45 Foneited Discounts & Interest
124 CUST 5 7,486,736 7,028,154 458,582 458,582
125 CUST SO
126 81 7,486,736 7,028,154 458,582 458,582
127
128 451 Misc Electric Revenue
129 CUST 5 7,051,612 6,892,092 159.520 159,520
130 GP SG
131 GP SO 28,158 26,578 1,580 1,580
132 81 7,079,770 6,918,669 161.100 161,100
133
134 453 Water Salas
135 P SG 26,405 24,872 1,533 1,533
136 B1 26,405 24,872 1,533 1,533
137
138 454 Rent of Electric Propert
139 DPW 5 11,890,427 11.579.610 310.817 310,817
140 T SG 5,426,451 5.111,337 315.114 315,114
41
GP SO 3,262.547 3,079,426 183,121 183,121
81 20,579,425 19,770,373 809,052 809,052
ROLLED-IN Page 9.4
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
145.456 Other Elecln Revenue
DM5C 5 37,234,750 37.233,784 966 966
CU5T CN
149 OTH5E 5E 16,625,527 15,553,305 1,072,222 22,775 1,094,997
150 OTH50 SO 469,412 443,065 26,347 26,347
151 OTH5GR 5G 100.100,013 94,287,205 5,812,808 369,123 6,181,931
152
153
154 61 154,429,703 147,517,359 6,912,343 391,899 7,304,242
155
156 Total Other Electric Revenues B1 189,602,040 181,259,429 8,342.611 391,899 8,734,510
157
158 Total Electric Operating Revenues B1 4,494.585.986 4,239,008,906 255,577.080 14,850,502 270,427,582
159
160 Summary of Revenues by Factor
161 S 3,516,322,840 3,317,650,046 198,672,795 4,363,364 203.36,159
162 CN
163 5E 16,168,501 15,125,754 1,042.747 52,250 1,094,997
164 SO 3,760,118 3,549,069 211,049 211,049
165 SG 958,334,527 902,684,038 55,650,489 10,434,887 66,085,376
166 DGP
167
168 Total Electric Operating Revenues 4,494,585,986 4,239,008,906 255,577,080 14,850,50~~7ö.27 .582
169 Miscellaneous Revenues
170 41160 Gain on Sale of Utilty Plant - CR
171 DPW 5
172 T 5G
173 G SO
174 T 5G
175 P 5G
176 61
177
178 41170 Loss on Sale of Utilty Plant
179 DPW 5
180 T 5G.61
4118 Gain from Emission Allowances
184 P 5
185 P SE (4,889,027)(4,573,722)(315,306)109,571 (205,735)
186 61 (4,889,027)(4,573,722)(315,306)109,571 (205,735)
187
188 41181 Gain from Disposition of NOX Creits
189 P 5E
190 61
191
192 4194 Impact Housing Interest Income
193 P 5G
194 61
195
196 421 (Gain) I Loss on Sale of Utilty Plant
197 DPW 5 (344,622)(344,622)(49,736)(49,736)
198 T SG
199 T SG (378,094)(356,138)(21,956)(21,956)
200 PTD CN 2,169 2.085 84 84
201 PTD SO 516,915 487,902 29,014 (26,553)2,461
202 P 5G (1,911,594)(1,800,587)(111,006)(111.006)
203 61 (2,115,225)(2.011.360 )(103,864)(76,289)(180.153)
204
205 Total Miscellaneous Revenues (7,004,252)(6.585,082)(419,170)33,282 (385,888)
206 Miscellaneous Expenses
207 4311 Interest on Customer Deposits
208 CU5T 5
209 61
210 Total Miscellaneous Expenses
211
212 Net Mise Revenue and Expense B1 (7,004,252)(6.585,082)(419,170)33.282 (385,888)
213.
ROLLED-IN Page 9.5
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
214 500 Operation Supervision & Engineering.P SNPPS 20,414,209 19,228,756 1,185,453 219,028 1,404,481
P SNPPS 1,424,208 1,341,504 82,704 82,704
82 21,838,417 20,570,260 1,268,157 219,028 1,487.185
218
219 501 Fuel Related-Non NPC
220 P SE 13,030,759 12,190,372 840,386 3.346 843,733
221 P SE
222 P SE
223 P SE
224 P SE 2.171,201 2,031,175 140,026 140.026
225 82 15,201,960 14,221,547 980,413 3,346 983,759
226
227 501NPC Fuel Related-NPC
228 P SE 562,030,147 525,783,408 38,246,739 1,001,606 37,248,345
229 P SE
230 P SE
231 P SE
232 P SE 47,679,955 44,604,955 3,075,000 3,075,000
233 82 609,710,102 570,388,362 39,321,740 1,001,606 40,323,346
234
235 Total Fuel Related 624,912,062 584,609,910 40,302,152 1.004,952 41,307,105
236
237 502 Steam Expenses
238 P SNPPS 32,863,919 30,955,511 1,908,408 1,908,408
239 P SNPPS 4,623,599 4,355,107 268,492 268,492
240 82 37,487,518 35,310,617 2,176,900 2,176,900
241
242 503 Steam From Other Sources-Non-NPC
243 P SE
244 82
245
246 503NPC Steam From Other Sources-NPC
247 P SE 3,371,385 3,153,956 217,429 (2,787)214,642
248 82 3,371,385 3,153,956 217,429 (2,787)214,642
249.505 Electrc Expenses
P SNPPS 2,737,130 2,578,184 158,945 158,945
P SNPPS 1,566,174 1,475,226 90,98 90,948
253 82 4,303,303 4,053,410 249,893 249,893
254
255 506 Misc. Steam Expense
256 P SNPPS 40,299,217 37,959,041 2.340,176 2,340,176
257 P SE
258 P SNPPS 3,273,208 3,083,133 190,075 190,05
259 B2 43,572,425 41,042,174 2,530,251 2,530,251
260
261 507 Rents
262 P SNPPS 277,611 261,490 16,121 16.121
263 P SNPPS 3.770 3,551 219 219
264 82 281,381 265,041 16,340 16,340
265
266 510 Maint Supervision & Engineering
267 P SNPPS 3,996,072 3,764,020 232,02 489,455 721,506
26 P SNPPS 2,012.831 1,895,946 116.885 116,885
269 B2 6,008,903 5,659,966 348,937 489,455 838,392
270
271
272
273 511 Maintenance of Structures
274 P SNPPS 23,718,380 22.341,053 1,377,326 1,377,326
275 P SNPPS 1,115,728 1.050,938 64,790 64,790
276 82 24,834,108 23,391,991 1,442,117 1,442,117
277
278 512 Maintenance of Boiler Plant
279 P SNPPS 80,611.372 75,930.270 4.681,103 143.673 4,824,775
280 P SNPPS 6,064,085 5,711,943 352,141 352,141
281 B2 86,675,457 81,642,213 5,033,244 143,673 5,176,917
282
283 513 Maintenance of Electric Plant
284 P SNPPS 27,262,127 25,679,015 1,583,112 1,583,112
4 P SNPPS 1.611,953 1,518,347 93,606 93,606
82 28,874,080 27.197,362 1,676,718 1,676,718
514 Maintenance of Misc. Steam Plant
289 P SNPPS 9,219,334 8,683,967 535,367 535,367
290 P SNPPS 3,533.767 3,328,561 205,206 205,206
291 82 12,753,101 12,012,528 740,573 740,573
292
293 Total Steam Power Generation 82 894,912.140 838,909,429 56,002,710 1.854,320 57,857,031
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
294 517 Operation Super & EngineeringIIPSNPPN
82
298 518 Nuclear Fuel Expense
299 P SE
300
301 82
302
303 519 Coolants and Water
304 P SNPPN
305 82
306
307 520 Steam Expenses
308 P SNPPN
309 82
310
311
312
313 523 Electnc Expenses
314 P SNPPN
315 82
316
317 524 Misc. Nuclear Expnses
318 P SNPPN
319 82
320
321 528 Maintenance Super & Engineenng
322 P SNPPN
323 82
324
325 529 Maintenance of Structures
326 P SNPPN
327 82
328
329 530 Maintenance of Reactor Plant.P SNPPN
82
333 531 Maintenance of Electric Plant
334 P SNPPN
335 82
336
337 532 Maintenance of Misc Nuclear
338 P SNPPN
339 82
340
341 Total Nuclear Power Generation B2
342
343 535 Operation Super & Engineenng
344 P DGP
345 P SNPPH 7,893,949 7,435,547 458,402 48,710 507,111
346 P SNPPH 932,247 878,112 54,136 54,136
347
348 82 8,826,196 8,313,659 512,537 48.710 561,247
349
350 536 Water For Power
351 P DGP
352 P SNPPH 292,471 275,487 16.984 16,984
353 P SNPPH 8.916 8.399 518 518
354
355 82 301,387 283,886 17,502 17,502
356
.
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
357 537 Hydraulic Expenses.P DGP
P SNPPH 3,695,558 3,480,957 214,601 214,601
P SNPPH 394,896 371,964 22.932 22,932
361
362 82 4,090,454 3,852,922 237,533 237,533
363
364 538 Electrc Expenses
365 P DGP
366 P SNPPH
367 P SNPPH
368
369 82
370
371 539 Misc. Hydro Expenses
372 P DGP
373 P SNPPH 11,978,982 11.283,363 695.620 (2,338)693,282
374 P SNPPH 5,866,793 5.526,108 340,685 340,685
375
376
377 82 17,845,775 16,809,471 1,036,304 (2,338)1,033,967
378
379 540 Rents (Hydro Generation)
380 P DGP
381 P SNPPH 141,883 133,644 8.239 8,239
382 P SNPPH (645)(607)(37)(37)
383
384 82 141,238 133,037 8,202 8,202
385
386 541 Maint Supervision & Engineering
387 P DGP
388 P SNPPH 2,681 2,525 156 156
389 P SNPPH
390
391 82 2,681 2,525 156 156
392.542 Maintenance of Structures
P DGP
P SNPPH 1,136.789 1,00.775 66,013 66,013
396 P SNPPH 88,380 83.248 5,132 5,132
397
398 82 1,225,169 1,154.023 71,146 71,146
399
400
401
402
403 543 Maintenance of Dams & Waterways
404 P DGP
405 P SNPPH 992,623 934,981 57,642 57.642
406 P SNPPH 44,661 418.840 25,821 25,821
407
408 82 1.437,284 1,353,821 83,463 83,463
409
410 544 Maintenance of Electric Plant
411 P DGP
412 P SNPPH 1,056,967 995.589 61,378 61,378
413 P SNPPH 515,650 485,706 29,944 29,944
414
415 82 1,572,616 1,481,295 91,322 91,322
416
417 545 Maintenance of Misc. Hydro Plant
418 P DGP
419 P SNPPH 1,44,329 1,364,225 84,104 7,790 91,894
420 P SNPPH 703,452 662,602 40,849 40,849
421
422 82 2,151,781 2,026,827 124,954 7,790 132,743
423
424 Total Hydraulic Power Generation B2 37.594.583 35.411,466 2.183.118 54.162 2.237.279
.
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
425.546 Operation Super & Engineering
P SNPPO 218,466 205,780 12,686 12,686
P SNPPO
429 82 218,466 205,780 12.686 12,686
430
431 547 Fuel-Non-NPC
432 P SE
433 P SE
434 82
435
436 547NPC Fuel-NPC
437 P SE 431,973,414 404,114,361 27,859,053 2,448,706 30,307,759
438 P SE 34,989,341 32,732,790 2,256,551 2,256,551
439 82 466,962,755 436,847,151 30,115,604 2,44,706 32,564,310
44
441 548 Generation Expense
442 P SNPPO 13,283,098 12,511.749 771,350 (153,335)618,015
44 P SNPPO 4,561,937 4,297,026 264,912 264,912
444 82 17,845,036 16,808,774 1,036,261 (153,335)882,926
445
446 549 Miscellaneous Other
447 P SNPPO 10,943,849 10,308,340 635,509 821,118 1,45,627
448 P SNPPO
449 82 10,943,849 10,308,340 635,509 821.118 1,456,627
450
451
452
453
454 550 Rents
455 P SNPPO 2,156,539 2,031,308 125,230 (266,152)(140,922)
456 P SNPPO 4,583,304 4,317,152 266,152 266,152
457 82 6,739,843 6,348,460 391,383 (266.152)125,230
458
459 551 Maint Supervision & Engineering
460 P SNPPO.82
552 Maintenance of Strctures
46 P SNPPO 1,000,631 942.524 58,107 (9.656)48.451
465 P SNPPO 279,717 263,474 16,243 16,243
466 82 1,280,348 1,205,998 74,350 (9,656)64,694
467
468 553 Maint of Generation & Electrc Plant
469 P SNPPO 5,023.341 4.731,636 291,705 339,681 631,386
470 P SNPPO 887,917 836,356 51,561 51,561
471 82 5,911,258 5,567,991 343,267 339,681 682,947
472
473 554 Maintenance of Misc. Other
474 P SNPPO 140,290 132,143 8,147 (7,202)945
475 P SNPPO 342,636 322,739 19,897 19,897
476 82 482,926 454,882 28,043 (7,202)20,842
477
478 Total Other Power Generation 82 510.384.480 477,747,376 32,637,104 3,173,160 35,810,264
479
480
481 555 Purchased Power-Non NPC
482 DMSC S (4,878,060)(5,431,791 )553,731 (553,731)
483 (4,878,060)(5,431,791)553,731 (553,731)
484
485 555NPC Purchased Power-NPC
486 P SG 650,037,045 612,289.392 37,747,653 2,243,439 39,991,092
487 P SE 109.030,864 101.999,189 7,031,675 (2,790,023)4,241.652
488 Seasonal Co P SG
489 DGP
490 759,067,909 714,288,581 44,779,328 (546,585)44,232,743
491
492 Total Purchased Power 62 754,189,849 708,856,790 45,333,059 (1,100,316)44,232,743
493
494 556 System Control & Load Dispatch
495 P SG 1,997,891 1,881,873 116,018 116.018.82 1,997,891 1,881,873 116,018 116,018
499
t,
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BegInning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
500.557 Other Expenses
p S (183,792)(150,819)(32,973)6,05,556 5,972,582
p SG 55,161,624 51,958,389 3,203,236 (182,616)3,020.619
504 P SGCT 1,122,425 1,056,994 65,431 65,31
505 P SE
506 P SG 43,687 41,150 2.537 2,537
507 P TROJP
508
509 B2 56,143,944 52,905,714 3,238,230 5,822,939 9,061,170
510
511 Embedded Cost Differentials
512 Company Owned Hyd P DGP
513 Company Owned Hyd P SG
514 Mid-e Contract P MC
515 Mid-e Contract P SG
516 Existing OF Contracts P S
517 Existing OF Contracts P SG
518
519
520
521 Total Other Power Supply B2 812,331,684 763,64,317 48,687,307 4.722,624 53,409,930
522
523 Total Production Expense B2 2,255.222,887 2.115,712,649 139,510,238 9,804.266 149,314.504
524
525
526 Summary of Production Expense by Factor
527 S (5,061,852)(5,582,610)520,758 5,451,825 5,972,582
528 SG 707,240,247 666,170,804 41,069,443 2,060,822 43,130,266
529 SE 1,204,271 ,066 1,126,610,206 71,666,860 660,848 78,321,708
530 SNPPH 37.594,583 35,411,466 2.183,118 54,162 2,237,279
531 TROJP
532 SGCT 1,122,425 1,056,994 65,431 65,431
533 DGP
534 DEU
535 DEP.SNPPS 266.628,693 251,145,564 15,483,129 852,155 16,335,284
SNPPO 43,421,725 40,900,225 2,521,500 724,454 3,245.954
DGU
539 MC
540 SSGCT
541 SSECT
542 SSGC
543 SSGCH
544 SSECH
545 Total Production Expense by Factor B2 2,255,222.887 2,115,712,649 139,510,238 9,804,266 149,314,504
546 560 Operation Supervision & Engineering
547 T SNPT 7.808,710 7,355,258 453,452 57,536 510,988
548
549 B2 7.808,710 7,355,258 453,452 57,536 510,988
550
551 561 Load Dispatching
552 T SNPT 8,536,145 8,040,451 495,694 (4,722)490,972
553
554 B2 8.536,145 8,040,451 495,694 (4,722)490,972
555 562 Station Expense
556 T SNPT 1,869,851 1,761,268 108,582 108,582
557
558 B2 1,869,851 1,761,268 108,582 108,582
559
560 563 Overhead Line Expense
561 T SNPT 93,337 87,917 5,420 5,420
562
563 B2 93,337 87,917 5,420 5,420
564
565 564 Underground Line Expense
566 T SNPT
567
568 B2
569
..
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BeginninglEndlng
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
570 565 Transmission of Electricity by Others.T SG
T SE
574
575 565NPC Transmission of Electricity by Others-NPC
576 T SG 117,397,550 110,580.273 6,817,276 775,200 7,592,476
577 T SE 3,769,633 3,526,520 243,113 (230.06)13,107
578 121,167,183 114,106,793 7,060,389 545,194 7.605,583
579
580 Total Transmission of Electricity by Others B2 121,167,183 114,106,793 7,060,389 545,194 7,605,583
581
582 566 Misc. Transmission Expense
583 T SNPT 1.795,131 1,690,888 104.243 104,243
584
585 B2 1,795,131 1,690,888 104,243 104,243
586
587 567 Rents. Transmission
588 T SNPT 822,667 774,894 47,772 47,772
589
590 B2 822,667 774,894 47,772 47,772
591
592 568 Maint Supervision & Engineering
593 T SNPT 9,822 9,252 570 57Q
594
595 B2 9,822 9,252 570 570
596
597 569 Maintenance of Strctures
598 T SNPT 4,128,899 3,889,134 239,765 239,765
599
600 B2 4,128,899 3,889,134 239,765 239,765
601
602 570 Maintenance of Station Equipment
603 T SNPT 11,093,119 10,44,941 64,177 644,177
604
605 B2 11,093,119 10,448,941 644,177 644,177
4 571 Maintenance of Overhead Lines
T SNPT 16,204,998 15,263,974 941,024 33,463 974,487
610 B2 16,204,998 15,263.974 941,024 33,463 974,487
611
612 572 Maintenance of Underground Lines
613 T SNPT
614
615 B2
616
617 573 Maint of Misc. Transmission Plant
618 T SNPT 480,533 452.628 27.905 27,905
619
620 B2 480,533 452,628 27,905 27,905
621
622 Total Transmission Expense B2 174,010.394 163,881,399 10,128,995 631,470 10,760,465
623
624 Summary of Transmission Expense by Factor
625 SE 3,769,633 3,526,520 243,113 (230,006)13,107
626 SG 117,397,550 110,580,273 6,817,276 775,200 7,592,476
627 SNPT 52,843,211 49,774,606 3,068,605 86,277 3,154,882
628 Total Transmission Expense by Factor 174,010,394 163,881399 10,128,995 631,470 10,760,465
629 580 Operation Supervision & Engineering
630 DPW S 176,450 219,560 (43,110)62,828 19,718
631 DPW SNPD 20,120,363 19,182,315 938,049 131,478 1,069,527
632 B2 20,296,814 19,401,875 894,939 194,306 1,089,245
633
634 581 Load Dispatching
635 DPW S
636 DPW SNPD 12,782,671 12,186.719 595,952 (4,165)591,787
637 B2 12,782,671 12,186,719 595,952 (4,165)591,787
638
639 582 Station Expense64DPW S 4,548,284 4,294,351 253,933 253,933
641 DPW SNPD 25,883 24,676 1.207 1,207.B2 4.574,167 4,319,027 255,140 255,140
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
Ii 583 Overhead Line Expenses
DPW S 5,378,951 5,216,983 161,967 161,967
DPW SNPD 13,397 12,772 625 625
47 62 5,392,347 5,229,756 162,592 162,592
648
649 584 Underground Line Expense
650 DPW S 403 403
651 DPW SNPD
652 62 403 403
653
654 585 Street Lighting & Signal Systems
655 DPW S
656 DPW SNPD 222,030 211,679 10,351 10,351
657 62 222,030 211,679 10,351 10,351
658
659 586 Meter Expenses
660 DPW S 6,033,669 5,690,925 342,745 342,745
661 DPW SNPD 1,171,018 1,116,423 54,595 54,595
662 62 7,204,688 6,807,348 397,340 397,340
663
664 587 Customer Installation Expenses
665 DPW S 11,063,638 10,354.314 709,324 709,324
666 DPW SNPD
667 62 11,063,638 10,354,314 709,324 709,324
668
669 588 Misc. Distribution Expenses
670 DPW S 2,878,136 2,764,905 113,231 113,231
671 DPW SNPD 5,511,145 5,254,206 256,940 256,940
672 62 8,389,281 8,019,111 370,170 370,170
673
674 589 Rents
675 DPW S 2,775,451 2,760,505 14,946 14,946
676 DPW SNPD 262,718 250,470 12.248 12,248
677 62 3,038,169 3,010,975 27.195 27,195
678
679 590 Maint Supervision & Engineenng.DPW S 655.797 621,844 33.953 33,953
DPW SNPD 5,766,096 5,97,270 268,826 3,274 272,100
62 6,21,892 6,119,114 302,779 3,274 306,052
683
684 591 Maintenance of Structures
685 DPW S 1,794,408 1,686,481 107,927 107.927
686 DPW SNPD 235,753 224,762 10,991 10,991
687 62 2,030,161 1.911,243 118,918 118,918
688
689 592 Maintenance of Station Equipment
690 DPW S 9,638,957 9,063.789 575.168 575,168
691 DPW SNPD 1,908,269 1,819,302 88,967 6,413 95,380
692 62 11,547,226 10,883,091 664,135 6,413 670,547
693 593 Maintenance of Overhead Lines
694 DPVV S 83,73,495 79,010,806 4,462,689 148,506 4,611.195
695 DPW SNPD 1,527,842 1.456,611 71,231 31,176 102,407
696 62 85,001,337 80,467,417 4,533,920 179,682 4.13,602
697
698 594 Maintenance of Underground Lines
699 DPW S 23,522.169 22,876.326 645,43 645,843
700 DPW SNPD 17.740 16,913 827 827
701 62 23,539.909 22,893,239 64,670 646,670
702
703 595 Maintenance of Line Transformers
704 DPW S
705 DPW SNPD 1,116,622 1,064,563 52,059 52,059
706 62 1,116,622 1,064,563 52,059 52,059
707
708 596 Maint of Street Lighting & Signal Sys.
709 DPW S 4.138,856 3,975,816 163,040 163,040
710 DPW SNPD
711 62 4,138,856 3,975,816 163,040 163,040
712.
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Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
713 597 Maintenance of Meters.DPW S 4.232,548 3,960,506 272,042 272,042
DPW SNPD 979,626 933,954 45,672 45,672
82 5,212,174 4,894,460 317,714 317,714
717
718 598 Maint of Misc. Distribution Plant
719 DPW S 3,853,384 3,745,816 107,568 107,568
720 DPW SNPD (461,493)(439,978)(21,516)(21,516)
721 82 3.391,891 3,305,839 86,052 86,052
722
723 Total Distribution Expense 82 215.364,277 205,055,987 10.308,289 379.509 10,.687,799
724
725
726 Summary of Distribution Expense by Factor
727 S 164,164,596 156,243,331 7,921,265 211,334 8,132,599
728 SNPD 51,199,681 48,812,657 2,387.024 168,175 2,555,200
729
730 Total Distribution Expense by Factor 215,364,27 205,055,987 10,308,289 379,509 10,687,799
731
732 901 Supervision
733 CUST S 168,874 166,227 2,647 2,647
734 CUST CN 2,309,075 2,219,510 89,565 89,565
735 82 2,477,949 2,385,737 92,212 92,212
736
737 902 Meter Reading Expense
738 CUST S 23,763,080 22,015,137 1,747.942 1,747.942
739 CUST CN 1,526,632 1,467,417 59,215 59.215
740 82 25,289,712 23,482,554 1,807,158 1,807,158
741
742 903 Customer Receipts & Collections
743 CUST S 6,381,549 6,175,307 206,242 80,928 287,170
744 CUST CN 50,255,601 48,306,279 1,949,322 71,597 2,020,919
745 82 56,637,149 54,481,586 2,155,564 152.525 2,308,089
746
747 904 Uncollectible Accounts
748 CUST S 14,663,103 14,359,698 303,406 303,406.P SG
CUST CN 11,611 11,161 450 450
82 14,674,714 14,370,858 303,856 303,856
752
753 905 Misc. Customer Accounts Expense
754 CUST S 8,966 8,966
755 CUST CN 220,595 212,039 8,556 8,556
756 82 229,561 221,005 8,556 8,556
757
758 Total Customer Accounts Expense B2 99.309,086 94.941.740 4.367,346 152,525 4,519.871
759
760 Summary of Customer Accts Exp by Factor
761 S 44,985,572 42,725,334 2,260,237 80,928 2,341,165
762 CN 54,323,514 52,216,406 2,107,108 71,597 2,178,706
763 SG
764 Total Customer Accounts Expense by Factor 99,309,086 94,941.40 4,361,346 152,525 4,519,871
765
766 907 Supervision
767 CUST S
768 CUST CN 247,987 238,368 9,619 9,619
769 82 247,987 238,368 9,619 9,619
770
771 908 Customer Assistance
772 CUST S 7,089,335 5,622,341 1,46,994 18,741 1,485,734
773 CUST CN 2.537.065 2,438,657 98,408 5,849 104,257
774
775
776 82 9,626,400 8,060,998 1.565.402 24,589 1,589.991
777
.
ROLLED-lN Page 9.13
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
778 909 Informational & Instructional Adv.CUST S 127.723 127,670 53 3,165 3,218
CUST CN 3,973,866 3,819,727 154.139 (18,583)135,556
B2 4,101,589 3,947,397 154,192 (15,418)138,774
782
783 910 Misc. Customer Service
784 CUST 5
785 CUST CN 63,857 61.380 2,477 2,477
786
787 B2 63,857 61,380 2,477 2,477
788
789 Total Customer Service Expense 82 14,039,833 12,308,144 1,731,689 9,171 1,740,860
790
791
792 Summary of Customer Service Exp by Factor
793 S 7,217,058 5,750,011 1,467,046 21,906 1,488,952
794 CN 6,822,775 6,558,132 264,643 (12,735)251.908
795
796 Total Customer Service Expense by Factor B2 14,039,833 12,308,144 1,731,689 9,17 1,740,860
797
798
799 911 Supervision
800 CUST 5
801 CUST CN
802 B2
803
804 912 Demonstration & Selling Expense
805 CUST S
806 CUST CN
807 82
808
809 913 Advertising Expense
810 CUST S
811 CUST CN
812 82
813.916 Misc. Sales Expense
CUST 5
eUST eN
817 82
818
819 Total sales Expense 82
820
821
822 Total Sales Expense by Factor
823 S
824 CN
825 Total Sales Expense by Factor
826
827 Total Customer ServIce Exp Including Sales B2 14,039,833 12,308,144 1,731,689 9,171 1.740,860
828 920 Administrative & General Salaries
829 PTD S 1,567,043 3,295,617 (1,728,574)2,370,439 641,864
830 CUST CN
831 PTO SO 65.633,747 61,949,834 3,683,913 497,063 4,180,976
832 B2 67.200,789 65,245,451 1,955,339 2,867,502 4,822,841
833
834 921 Offce Supplies & expenses
835 PTO S (1,003,755)(1,003,905)150 150
836 CUST eN
837 PTO SO 12,474,744 11,774,557 700',187 (5,449)894,737
838 82 11,470,988 10,770,652 700,337 (5,449)694,887
839
840 922 A&G Expenses Transferred
841 PTD S
842 eUST CN
843 PTO SO (21,538,493)(20,329,573)(1,208,920)(1,208,920)
844 82 (21,538,493)(20,329,573)(1,208,920)(1,208,920)
845
.
ROLLED-IN Page 9.14
Beginning/nding
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
846 923 Outside Services.PTD S 2,442 2,442
CUST CN
PTD SO 11,888,434 11,221,156 667,278 (13,208)654,070
850 B2 11,890,876 11,223,598 667,278 (13,208)654,070
851
852 924 Propert Insurance
853 PTD SO 31,882,383 30,092,878 1,789,505 1,789,505
854 B2 31,882,383 30,092,878 1,789,505 1,789,505
855
856 925 Injuries & Damages
857 PTD SO 9,475,122 8,943,299 531,823 28,321 560,144
858 B2 9,475,122 8,943,299 531,823 28,321 560,144
859
860 926 Employee Pensions & Benefits
861 LABOR S
862 CUST CN
863 LABOR SO
864 B2
865
866 927 Franchise Requirements
867 DMSC S
868 DMSC SO
869 B2
870
871 928 Regulatory Commission Expense
872 DMSC S 9,727,505 9,294,502 433,003 (11,285)421,718
873 CUST CN
874 DMSC SO 2,819 2,661 158 158
875 FERC SG 1,899,938 1,789,609 110,329 110,329
876 B2 11,630,262 11,086,771 543,491 (11,285)532,206
877
878 929 Duplicate Charges
879 LABOR S
880 LABOR SO (3,987,182)(3,763,388)(223,794)(223,794)
881 B2 (3,987,182)(3,763,388)(223,794)(223,794).930 Mise General Expenses
PTD S 5,465,839 5,459,839 6,000 (444,549)(438,549)
885 CUST CN 4,500 4,325 175 175
886 LABOR SO 13,105,319 12,369,739 735,580 790,675 1,526,255
887 B2 18,575,658 17,833,903 741,754 346.126 1,087,881
888
889 931 Rents
890 PTD S 934,443 934,443
891 PTD SO 5,384,260 5.082,051 302,210 (1,02)301,157
892 B2 6,318,703 6,016,494 302,210 (1,052)301,157
893
894 935 Maintenance of General Plant
895 G S 23,039 23,039
896 CUST CN
897 G SO 27,101,992 25,580,802 1,521,190 1,521,190
898 B2 27,125.031 25,603,841 1,521,190 1,521,190
899
900 Total Administrative & General Expense B2 170,044.138 162,723,926 7,320,212 3,210.955 10,531,167
901
902 Summary of A&G Expense by Factor
903 S 16,716,555 18,005,977 (1,289,421 )1,914,605 625,184
904 SO 151,423,144 142,924,015 8,99,129 1,296,349 9,795,479
905 SG 1,899,938 1,789,609 110,329 110,329
906 CN 4,500 4,325 175 175
907 Total A&G Exense by Factor 170,044,138 162,72,926 7,320,212 3,210,955 10,531,167
908
909 Total O&M Expense B2 2,927,99,614 2, 754,623,845 17,366,769 14,187,897 187,554,666
.
ROLLED.IN Page 9.15
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
910 4035P 5team Depreciation.p 5G 23,44,765 22,083,327 1,361,438 1,361,438
P 5G 26,153,806 24,635,055 1,518,752 1,518,752
P 5G 48,167,206 45,370,136 2,797,070 178,632 2.975,702
914 P 5G 7,258,124 6,836,645 421,479 421,479
915 83 105,023,901 98,925,163 6,098,738 178,632 6,277,371
916
917 403NP Nuclear Depreciation
918 P 5G
919 83
920
921 403HP Hydro Depreciation
922 P 5G 3,842,758 3,619,609 223,149 223,149
923 P 5G 1,032,617 972,652 59,964 59,964
924 P 5G 7,010,380 6,603,287 407,093 41,118 448,210
925 P 5G 3,092,147 2,912,586 179,561 179,561
926 83 14,977.901 14,108,135 869,767 41,118 910,884
927
928 4030P Other Producton Depreciation
929 P 5G 125,965 118,651 7.315 7,315
930 P 5G 51,340,909 48,359,542 2.981.367 2,419,739 5,401,106
931 P 5G 2,521,119 2,374,718 146.401 146,401
932 P 5G
933 83 53,987,993 50,852,911 3,135,083 2,419,739 5.554,822
934
935 403TP Transmission Depreciation
936 T 5G 11,375,581 10,715,001 660,580 660,580
937 T 5G 12,624,038 11,890,960 733.078 733,078
938 T 5G 34,235,508 32,247,452 1,988,056 190,822 2,178,878
939 83 58,235,127 54,853,413 3,381,714 190,822 3,572,536
940
941
942
943 403 Distrbution Depreciation
944 360 Lond & Land Rig'" DPW 5 278,131 261,874 16.257 16,257
945 361 Sir DPW 5 906,304 893,399 12.904 12,904.362 Stli E.... DPW 5 16,347,160 15,728,098 619,062 619,02
363 StllBaler Eqo DPW 5 91,113 91,113
364 Pole & Tower DPW 5 32,093,095 30,172.791 1,920,304 1,920,304
949 365 OH Cond DPW 5 18,328,255 17.390.184 938,072 938,072
950 366 UG Co DPW 5 7,213,537 7,062,392 151,145 151,145
951 367 UG Condr DPW 5 16.692,267 16,233,432 458.835 458,835
952 368 Line Tra DPW 5 25,531.690 24,172,626 1.359,064 1,359,064
953 369 Ser DPW 5 10,936,723 10,448,593 488,130 488,130
954 370 Meer DPW 5 6,445,250 6.03,031 442,219 442,219
955 371 lna CUtPrem DPW 5 497,587 490,081 7,505 7,505
956 372 L_f'",y DPW 5 162 146 16 16
957 373 Stee LighUng DPW 5 2.192,792 2,164,319 28,474 28,74
958 83 137,554,066 131,112,080 6,441,986 6,441,986
959
960 403GP General Depreciation
961 G-5ITU5 5 13,352,607 12,521,151 831,456 7,336 838,792
962 PT 5G 573,517 540,213 33,304 33,304
963 PT 5G 1,211,376 1,141,032 70,345 70,345
964 P 5E 34,771 32.528 2,242 2,242
965 CU5T CN 1,549,132 1,489,044 60,088 574 60,662
966 G-5G 5G 4,889,513 4,605,579 283,934 355 284,289
967 PTD 50 16,468,319 15,543,980 924,339 8.798 933,137
968 G-5G 5G 8,619 8.119 501 501
969 G-5G 5G 172,600 162,578 10,023 10,023
970 83 38,260,455 36,044,223 2,216,232 17,063 2,233.295
971
972 403GVO General Vehicles
973 G-G 5G
974 83
975
976 403MP Mining Depreciation
977 P 5E 2,848 2,848
978 83 2.848 2,848
979.f
ROLLED.IN Page 9.16
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
980 403EP Experimental Plant Depreciation.P SG
P SG
B3
984 4031 ARO Depreciation
985 P S
986 B3
987
988
989 Total Depreciation Expense B3 408,039,44 385,895,925 22,143,520 2,850.222 24.993,742
990
991 Summary S 150,906,673 143,633,232 7,273,442 7,336 7,280,777
992 DGP
993 DGU
994 SG 239,080,549 225,197,141 13.883,408 2.830,666 16,714,075
995 SO 16,468,319 15,543,980 924,339 8,798 933,137
996 CN 1,549,132 1,489,044 60,088 574 60,662
997 SE 34.771 32,528 2,242 2.848 5,091
998 SSGCH
999 SSGCT
1000 Total Depreciation Expense By Factor 408,039,444 385,895,925 22,143,520 2,850,222 24,9§3,742
1001
1002 404GP Amort of L T Plant - Capital Lease Gen
1003 1-SITUS S 1,220.394 1,220,394
1004 I-SG SG
1005 PTD SO 1,097,914 1,036,290 61,624 61,624
1006 P SG
1007 CUST CN 234,320 225,231 9,089 9,089
1008 P SG
1009 B4 2,552,628 2,481,915 70,713 70,713
1010
1011 404SP Amort of L T Plant - Cap Lease Steam
1012 P SG
1013 P SG
1014 B4
1015.!4041P Amort of L T Plant - Intangible Plant
I-SITUS 5 71,714 45,542 26,171 26,171
P SE 10,380 9,710 669 669
1019 I-SG SG 8,136,385 7,663,905 472,480 204,571 677,051
1020 PTD SO 21,539,117 20,330,162 1,208,955 15.735 1.224,690
1021 CUST CN 5,843,372 5,616,719 226.654 226,654
1022 l-SG SG 2,073,941 1,953,507 120,434 120,434
1023 l-SG SG 309,688 291.704 17,984 17,984
1024 P SG
1025 l-SG SG
1026 l-SG SG 21,850 20,581 1,269 1,269
1027 P SG 16,678 15,709 968 968
1028 B4 38,023,124 35,947,541 2,075,584 220,306 2,295,890
1029
1030 404MP Amort of L T Plant - Mining Plant
1031 P SE
1032 B4
1033
1034 4040P Amort of L T Plant - Othr Plant
1035 P SG 115.060 108,378 6,682 (6,682)°
1036 B4 115,060 108,378 6,682 (6,682)°
1037
1038
1039 404HP Amortization of Other Electric Plant
1040 P SG 2,279 2,147 132 132
1041 P SG 39,066 36,797 2,269 2,269
1042 P SG
1043 B4 41,345 38,944 2,401 2,401
1044
1045 Total Amortization of Umited Term Plant B4 40,732,157 38,576.778 2,155,379 213.625 2.369,004
1046
1047
1048 405 Amortization of Other Electric Plant
1049 GP S
1050
.~B4
ROLLED.IN Page 9.17
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL
1053 406 Amortization of Plant Acquisition Adj.~P S
P SG
P SG
1057 P SG 5,479,353 5,161,167 318,186 318,186
1058 P SO
1059 64 5,479,353 5,161,167 318,186 318,186
1060 407 Amort of Prop Losses, Unrec Plant, etc
1061 DPW 5 5,175,354 5,175,354
1062 GP SO
1063 P SG 3,437,028 3,237,44 199,588 199.588
1064 P SE
1065 P SG 305,346 287,615 17,731 (199,588)(181,857)
1066 P TROJP 2,013,725 1,894,824 118,902 118,902
1067 64 10,931,454 10,595,233 336,221 (199,588)136,633
1068
1069 Total Amortization Expense B4 57,142,96 54,333,177 2,809,786 14,037 2,823,823
1070
1071
1072
1073 Summary of Amortization Expense by Factor
1074 5 6,467,462 6,441,291 26,171 26,171
1075 SE 10,380 9,710 669 669
1076 TROJP 2,013,725 1,894,824 118,902 118,902
1077 DGP
1078 DGU
1079 SO 22,637,031 21,366,452 1,270,579 15.735 1,286,314
1080 SSGCT
1081 SSGCH
1082 SG.p
1083 CN 6,077,693 5,841,950 235,742 235,742
1084 SG 19,936,673 18,778,951 1,157,723 (1,699)1,156,024
1085 Total Amortization Expense by Factor 57,142,964 54,333,171 2,8õ9,786 14.037 2,823,823
1086 408 Taxes Other Than Income
1087 DMSC S 25,128,171 25,128,171
1088 GP GPS 77,529,279 73,177,690 4,351,589 507,553 4,859,142
.~GP SO 8,932,612 8,431,239 501,373 501,373
P SE 834,427 780,613 53.814 53,814
P SG
1092 DMSC OPRV-ID
1093 GP EXCTAX
1094 GP SG
1095
1096
1097
1098 Total Taxes Other Than Income B5 112,424.490 107,517,714 4.906,776 507.553 5,414,329
1099
1100
1101 41140 Deferrd Investment Tax Credit - Fed
1102 PTD DGU (1,874,204)(1,654,465)(219,739)(219,739)
1103
1104 67 (1,874,204)(1,654,465)(219,739)(219,739)
1105
1106 41141 Deferred Investment Tax Creit -Idaho
1107 PTD DGU
1108
1109 67
1110
1111 Total Deferrd ITC 87 (1,874,204)(1,654,465)(219,739)(219.739)
1112
.
ROLLED-IN Page 9.18
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
If 427 Interest on Long-Term Debt
GP 5 1,527.432 1,527,432
116 GP 5NP 313,572,989 296,304,989 17,268,000 17,268,000
1117 B6 313,572,989 296,304,989 17,268,000 1,527,432 18,795,432
1118
1119 428 Amortization of Debt Disc & Exp
1120 GP 5NP 7,295,949 6,894,171 401,777 401,777
1121 B6 7,295,949 6,894,171 401,777 401,777
1122
1123 429 Amortization of Premium on Debt
1124 GP 5NP (2,718)(2,568)(150)(150)
1125 B6 (2,718)(2,568)(150)(150)
1126
1127 431 Other Interest Expense
1128 NUTIL OTH
1129 GP 50
1130 GP 5NP 14,625,063 13,819,682 805,381 805,381
1131 B6 14,625,063 13,819,682 805,381 805,381
1132
1133 432 AFUDC - Borrowed
1134 GP 5NP (34,280,545)(32.392,766)(1,887,779)(1,887,779)
1135 (34,280,545)(32,392,766)(1,887,779)(1,887.779)
1136
1137 Total Elec. Interest Deductions for Tax B6 301,210,738 284,623,508 16,587,229 1,527,432 18,114,662
1138
1139 Non-Utilty Portion of Interest
1140 427 NUTIL NUTIL
1141 428 NUTIL NUTIL
1142 429 NUTIL NUTIL
1143 431 NUTIL NUTIL
1144
1145 Total Non-utilty Interest
1146
1147 Total Interest Deductions for Tax B6 301,210,738 284,623,508 16,587,229 1,527,432 18,114,662
1148.~419 Interest & Dividends
GP 5
1152 GP 5NP
146,616,392)
(44,049,296)(2,567,096)(2,567,096)
1153 Total Operating Deductions for Tax B6 46,616,392)(44,049,296)(2,567,096)(2,567.096)
1154
1155
1156 41010 Deferred Income Tax - Federal-DR
1157 GP 5 518.758,661 490,992,868 27,765,794 (27,645,563)120,231
1158 P TROJD
1159 PT DGP 368 368
1160 LABOR 50 33,48,751 31.604,364 1,879,387 (928,835)950,552
1161 GP 5NP 1,555.049 1,555,049
1162 P 5E 14,696,870 13,749,032 947,838 194,456 1,142,295
1163 PT 5G 11,550,960 10,880,196 670,764 9,414,867 10,085,631
1164 GP GP5 70,380 66,429 3,950 1,735,556 1,739,506
1165 TAXDEPR TAXDEPR 24,453,431 24,453,31
1166 P 5G
1167 CU5T CN 23,817 22,893 924 (218)706
1168 P IBT 214,379 228,932 (14,552)14,552 (0)
1169 DPW 5NPD 85,117 81.148 3,968 3,968
1170 B7 578,884,303 547,626,229 31,258,073 8,793,296 40.051,370
1171
.
ROLLED.IN Page 9.19
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1172.:41110 Deferred Income Tax - Federal-CR
GP S (271.085,647)(257,386,834)(13,698,813)12.893,414 (805,399)
1176 P SE (13.365,892)(12,503.892)(862.000)(30,844)(892,844)
1177 P SG
1178 GP SNP (1,602,752)(1,514,491)(88,261)(1.275,145)(1,363,07)
1179 PT SG (3.849,639)(3,626.091 )(223,549)334,035 110,486
1180 DPW CIAC (1,154,455)(1,154,455)
1181 LABOR SO (26,337,587)(24.859,302)(1,478,285)1,217,356 (260,929)
1182 PT SNPD (38,860)(38.860)
1183 CUST BADDEBT (334,769)(327,837)(6,932)(6,32)
1184 P SGCT (356,220)(335,55)(20,766)(20,766)
1185 BOOKDEPR SCHMDEXP (9,992.623)(9,992,623)
1186 P TROJD (555,830)(522,915)(32,915)(32.915)
1187 P IBT (291,290)(311,063)19,773 (19,773)0
1188
1189
1190 B7 (317,779,627)(301,387,881 )(16,391,746)1,933.104 (14,458,643)
1191
1192 Total Deferred Income Taxes B7 261,104,676 246,238,349 14,866,327 10,726,400 25.592,727
1193 SCHMAF Additions. Flow Through
1194 SCHMAF S
1195 SCHMAF SNP
1196 SCHMAF SO
1197 SCHMAF SE
1198 SCHMAF TROJP
1199 SCHMAF sa
1200 B6
1201
1202 SCHMAP Additions - Petmanent
1203 P S
1204 P SE 84,185 78,756 5,429 5,429
1205 LABOR SNP
1206 SCHMAP.SO SO 9,298,119 8,776,231 521,888 521,888
1207 SCHMAP SG.DPW BADDEST
B6 9,382,305 8,854,987 527,317 527,317
1211 SCHMAT Additions - Temporary
1212 SCHMA T .SITUS S 81,206.348 80,412,557 793,791 7,336 801,127
1213 P sa
1214 DPW CIAC 65,247,545 62,205,584 3,041,962 3,041,962
1215 SCHMAT-SNP SNP 65,237,720 61,645,175 3,592,545 3,592.545
1216 P TROJD 1,464,60 1,377,869 86,731 86,731
1217 P SGCT 54,717 54,717
1218 SCHMAT.SE SE 31,701,99 29,657,457 2,044,542 310,930 2,355,472
1219 P SG 3,959,859 3,729,910 229,949 2,207,277 2,437,226
1220 CUST CN 574 574
1221 SCHMAT-SO SO 12,249,451 11,561,910 687,541 24,533 712,074
1222 SCHMAT.SNP SNPD 2,196,309 2,093,913 102,396 102,396
1223 DPW BADDEBT 882,108 863,84 18,265 18,265
1224 P SG 938,632 884,126 54,506 54,506
1225 BOOKDEPR SCHMDEXP 485,189,989 458,859,658 26,330,332 26,330,332
1226 B6 750,274,561 713.292,002 36,982,559 2,605,366 39,587,925
1227
1228 TOTAL SCHEDULE - M ADDITIONS B6 759,656,866 722,146,989 37,509,877 2,605,366 40,115,243
1229
.
ROLLEo.lN Page 9.20
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1230 SCHMDF Deductions - Flow Through.SCHMDF S
SCHMDF DGP
SCHMDF DGU
1234 B6
1235 SCHMDP Deductions - Permanent
1236 SCHMDP S
1237 P SE 2,592,202 2,425,024 167,176 167,176
1236 PTD SNP 381,063 360,076 20,965 20,965
1239 SCHMDP IBT
1240 P SG (0)(0)(0)(0)
1241 SCHMDP-SO SO 12,093,766 11,414,984 676,604 676,604
1242 B6 15,067,053 14,200,066 666,966 666,966
1243
1244 SCHMDT Deductions - Temporary
1245 GP S 62,693,744 62,365,765 507,976 (609,956)(301,976)
1246 DPW BADDEBT
1247 SCHMDT-SNP SNP 74,407.631 70,310,113 4,097,516 4,097,516
1246 SCHMDT CN 62,756 60,322 2,434 2,434
1249 SCHMDT SG
1250 CUST DGP 970 970
1251 P SE 45,523,602 42,567,670 2,935.932 76,636 3,012,766
1252 SCHMDT-SG SG 16,460,740 17,407,564 1,073,177 26,379,234 29,452,410
1253 SCHMDT-GPS GPS 61.662,106 77,076,546 4,563,556 4,563,556
1254 SCHMDT-SO SO 53,669,546 50,657,164 3,012,362 (463,166)2.529,216
1255 TAXDEPR TAXDEPR 1,095,617,690 1,031,163,670 64,434,220 64,434,220
1256 DPW SNPD 224,260 213,624 10,456 10,456
1257 B6 1,432,543,265 1,351,665,609 60,657,656 27,162,947 107,620,603
1256
1259 TOTAL SCHEDULE - M DEDUCTIONS B6 1,447,610,316 1,366,065,695 61,524,622 27,162,947 106,667,570
1260
1261 TOTAL SCHEDULE - M ADJUSTMENTS B6 (687.953,452)(643,938,706)(44.014,746)(24,557,581)(68,572.327)
1262
1263
1264
1265 40911 State Income Taxes4IBT IBT 2,494,223 2,663,536 (169,313)(1,306,769)(1,476,62)
IBT SE
REC P SG (33,960)(33,960)
IBT IBT
1270 Total State Tax Expense 2,49,223 2,663,536 (169,31)(1,342,749)(1,512,062)
1271
1272
1273 Calculation of Taxabe Income:
1274 Operating Revenues 4,494,565,966 4,239,006,906 255,577,060 14,650,502 270,427,562
1275 Operating Deductions:
1276 o & M Expenses 2,927,990,614 2,754,623,645 173,366,769 14,167,697 167.554,666
1277 Depreciation Expense 406,039,444 365,695,925 22,143,520 2,650,222 24,993,742
1276 Amortization Expense 57,142,964 54,333,117 2,609,766 14,037 2,623,623
1279 Taxes Other Than Income 112,424,490 107,517,714 4,906,176 507.553 5,414,329
1260 Interest & Dividends (AFUDC-Equity)(46.616,392)(44,049,296)(2.567,096)(2.567,096)
1261 Misc Revenue & Expense (7,004,252)(6,565,062)(419,170)33,262 (365,666)
1262 Total Operating Deductions 3,451,976,667 3,251,736,262 200,240,566 17,592,991 217,633,576
1263 Oter Deductions:
1264 Interest Deductions 301,210,738 264,623,506 16,567,229 1.527,432 16.114,662
1265 Interest on PCRBS
1266 Schedule M Adjustments (687,953,452)(643,936,706)(44,014,746)(24,557,561 )(66,572,327)
1267
1266 Income Before State Taxes 53,44,929 56,710,410 (5,265,460)(28.627,503 )(34,092,983)
1269
1290 State Income Taxes 2,494,223 2,663,536 (169,313)(1,342,749)(1,512,062)
1291
1292 Total Taxable Income 50,950,706 56,046,674 (5,096,167)(27,464,753)(32,560,921 )
1293
1294 Tax Rate 35.0%35.0%35.0%35.0%35.0%
1295
1296 Federal Income Tax. Calculated 17,832,747 19,616,406 (1.763,659)(9,619.664)(11,403,322)
1297
1298 Adjustments to Calculated Tax:
1299 40910 PMI P SE
1300 4010 REC P SG (3,060,226)(3,060,226)
1301 40910 P SO.40910 IRS Se LABOR S
Federal Income Tax Expense 17,832,747 19,616,406 (1,783.659)(12.679,889)(14,46i,S48)
1305 Total Operating Expenses 3,778,150,701 3,562,649,403 215.501,298 14,296,752 229,798.050
ROLLED.IN Page 9.21
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1306 310 Land and Land Rights.P SG 2.329,517 2.194,242 135,275 135,275
P SG 34,798,44 32,777.700 2,020,746 2,020,746
P SG 54,572,394 51,403,375 3,169,019 3,169,019
1310 P S
1311 P SG 1,830,732 1,724,422 106,311 106,311
1312 B8 93,531,089 88,099,739 5,431,351 5,431,351
1313
1314 311 Structures and Improvements
1315 P SG 234.971,513 221,326,717 13,644,796 13,644,796
1316 P SG 327,274,883 308,270,030 19,004,853 19,004,853
1317 P SG 193,191,542 181,972,909 11.218,633 11,218,633
1318 P SG 54,198,086 51,050,803 3,147,283 3,147,283
1319 B8 809,636,024 762,620,458 47,015,566 47,015.566
1320
1321 312 Boiler Plant Equipment
1322 P SG 722,926,960 680,94,589 41,980,371 41,980,371
1323 P SG 666,159,969 627,476,058 38,683,911 38,683,911
1324 P SG 1,248,663,407 1,176,153,519 72,509,888 10,149,800 82,659,687
1325 P SG 272,747,792 256,909,327 15.838,465 15,838,465
1326 B8 2,910,498,128 2,741,485,493 169,012,635 10,149.800 179,162,435
1327
1328 314 T urbogenerator Units
1329 P SG 145,478,089 137,030,176 8,447,913 8,447,913
1330 P SG 144,735,461 136,330,672 8.404,789 8,404,789
1331 P SG 430,173,624 405,193,441 24,980,184 24,980,184
1332 P SG 59,113,516 55,680,794 3,432,722 3,432,722
1333 B8 779,500,690 734,235,082 45,265,607 45,265,607
1334
1335 315 Accessory Electric Equipment
1336 P SG 88,074,089 82,959,626 5,114,463 5.114,463
1337 P SG 139,182,485 131,100,158 8,082,327 8,082,327
1338 P SG 69,328,10 65,302,509 4,025,901 4,025,901
1339 P SG 55,948,683 52,699,742 3,248,940 3,248,940
1340 B8 352,533,666 332,062,035 20,471,631 20,471,631
1341.316 Misc Power Plant Equipment
1345 P SG 4.917,199 4,631,657 285,542 285,542
1346 P SG 5.311,573 5.003,130 308,443 308,443
1347 P SG 12,798,588 12,055,374 743,214 743,214
1348 P SG 3,153,831 2,970,688 183,143 183,143
1349 B8 26,181,190 24,660,848 1,520,342 1,520,342
1350
1351 317 Steam Plant ARO
1352 P S
1353 B8
1354
1355 SP Unclassified Steam Plant - Account 300
1356 P SG 3.141,303 2.958,888 182,415 182,415
1357 B8 3,141.303 2.958,888 182,415 182,415
1358
1359
1360 Total Steam Production Plant B8 4.975.022.090 4.686,122,542 288,899.54 10.149.800 299,049,347
1361
1362
1363 Summary of Steam Production Plant by Factor
1364 S
1365 DGP
1366 DGU
1367 SG 4,975,022,090 4,686,122,542 288,899,548 10,149,800 299,049,347
1368 SSGCH
1369 Total Steam Production Plant by Factor 4,975,022,090 4,686,122,542 288,899,548 10.149,800 299,049,347
1370 320 Land and Land Rights
1371 P SG
1372 P SG
1373 B8
1374
1375 321 Structures and Improvements
1376 P SG.P SG B8
ROLLED.IN Page 9.22
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL.322 Reactor Plant Equipment
P SG
P SG
1383 68
1384
1385 323 Turbgenerator Units
1386 P SG
1387 P SG
1388 68
1389
1390 324 Land and Land Rights
1391 P SG
1392 P SG
1393 68
1394
1395 325 Misc. Power Plant Equipment
1396 P SG
1397 P SG
1398 68
1399
140
1401 NP Unclassified Nuclear Plant - Acct 300
1402 P SG
1403 68
1404
1405
1406 Total Nuclear Production Plant B8
1407
1408
1409
1410 Summary of Nuclear Production Plant by Factor
1411 DGP
1412 DGU
1413 SG
1414.Total Nuclear Plant by Factor
330 Land and Land Rights
1418 P SG 10,626.875 10,009,773 617,103 617,103
1419 P SG 5,307,562 4,999,351 308,210 308,210
1420 P SG 3,122,555 2,941,228 181,327 181,327
1421 P SG 635,700 598,785 36,915 36,915
1422 68 19.692,691 18,549,136 1,143,555 1,143,555
1423
1424 331 Strctures and Improvements
1425 P SG 21,453,996 20,208,163 1,245,834 1,245.834
1426 P SG 5.321,263 5.012,257 309,006 309,006
1427 P SG 51.364,477 48.381,742 2,982,735 2,982,735
1428 P SG 7,247,543 6,826,678 420,865 420,865
1429 68 85,387,280 80,428,840 4,958,44 4,958,44
1430
1431 332 Reservoirs, Dams & Waterways
1432 P SG 151,599,706 142,796,310 8,803,395 8,803,395
1433 P SG 20,314,745 19,135.068 1.179,677 1,179,677
1434 P SG 81,431,400 76,702,678 4.728,722 1,795,789 6,524,511
1435 P SG 34,719,453 32,703,294 2,016,159 2,016,159
1436 68 288,065,303 271,337,350 16,727,953 1,795,789 18,523,742
1437
1438 333 WaterWheel, Turbines, & Generators
1439 P SG 32,865,646 30,957,138 1,908,508 1,908.508
1440 P SG 9,119.942 8,590,347 529,595 529,595
1441 P SG 35,766.382 33,689,428 2,076,954 2,076,954
1442 P SG 18,966,583 17,865,194 1,101,390 1,101,390
144 68 96,718,553 91,102,107 5,616,447 5,616,447
144
1445 334 Accessory Electric Equipment
1446 P SG 4,884.346 4,600,712 283,634 283,634
1447 P SG 3,929,298 3,701,123 228,174 228,174
144 P SG 34,265,028 32,275,257 1,989,770 1,989,170
1449 P SG 4,595,701 4,328,828 266,872 266,872
.~68 47,674,372 44,905,921 2,768,451 2,768,451
ROLLED-IN Page 9.23
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DE SCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
II. 145:
335 Misc. Power Plant Equipment
P SG 1,272,609 1,198,709 73,900 73,900
1456 P SG 196,141 184,751 11,390 11,390
1457 P SG 988,829 931,07 57,421 57,421
1458 P SG 13,718 12,922 797 797
1459 B8 2,471,296 2,327,788 143,508 143,508
1460
1461 336 Roads, Railroads & Bridges
1462 P SG 4,663,151 4,392,362 270,789 270,789
1463 P SG 828,976 780,837 48,139 48,139
1464 P SG 8,179,286 7,704,315 474,971 474,911
1465 P SG 608,436 573,104 35,332 35,332
1466 88 14,279,848 13,450,617 829,231 829,231
1467
1468 337 Hydro Plant ARO
1469 P 5
1470 B8
1471
1472 HP Unclassified Hydro Plant - Acct 300
1473 P 5
1474 P SG
1475 P SG
1476 P SG
1477 B8
1478
1479 Total Hydraulic Production Plant B8 554,289.344 522,101,760 32,187,584 1,795,189 33.983,373
148
1481 Summary of Hydraulic Plant by Factor
1482 5
1483 SG 554.289,344 522,101,760 32,187,584 1,795,789 33,983,313
1484 DGP
1485 DGU
1486 Total Hydraulic Plant by Factor 554,289,344 522,101,760 32,187,584 1,795,789 33,983,373
1487.i 340 Land and Land Rights
P SG 21,542.794 20,291,603 1,250,990 1,250,990
P SG
1491 P SG
1492 88 21,542,194 20,291,803 1,250,990 1,250,990
1493
1494 341 Strctures and Improvements
1495 P SG 105,937,740 99,785,935 6.151,605 6,151,805
1496 P SG 168,512 158,727 9,786 9,786
1497 P SG 4,179,820 3,937,098 242,722 242.722
1498 88 110,286,072 103,881,760 6,404,313 6,404,313
1499
1500 342 Fuel Holders, Producers & Accessories
1501 P SG 6,693,078 6.304,411 388,667 388,667
1502 P SG 121,339 114,293 7,046 7,046
1503 P SG 2,270,875 2,139,006 131,870 131,870
1504 88 9,085,292 8,557,709 527,583 527,583
1505
1506 343 Prime Movers
1507 P 5
1508 P SG 773,304 728,398 44.906 44,906
1509 P SG 1,211,613.127 1,141,254,749 70,358,378 50,841,716 121,200.94
1510 P SG 51,085.812 48,119,258 2,986,553 2,966,553
1511 B8 1,263,472,242 1,190,102,405 73,369,837 50,841,716 124,211,553
1512
1513 344 Generators
1514 P 5
1515 P SG
1516 P SG 213,416,293 201,023,208 12,393,085 12,393,085
1517 P SG 15,873,643 14,951,861 921,783 921,783
1518 88 229,289,936 215,975,069 13,314,867 13,314,867
.
ROLLED-IN Page 9.24
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL~345 Accssory Electric Plant
52~
P SG 122,29,594 115,189,179 7.101,415 7,101,415
P SG 156.586 147,493 9.093 9,093
1523 P SG 3,012,036 2,837,127 174,909 174,909
1524 88 125,459,216 118,173,799 7,285,417 7,285,417
1525
1526
1527
1528 346 Misc. Power Plant Equipment
1529 P SG 6,912,640 6,511,223 401,417 401,417
1530 P SG 11,813 11,127 686 686
1531 88 6.924,453 6,522,350 402.103 402,103
1532
1533 347 Other Production ARO
1534 P S
1535 88
1536
1537 OP Unclassified Other Prod Plant-Acct 300
1538 P S
1539 P SG 151,409,535 142,617,183 8,792,352 8,792,352
1540 151,409,535 142,617,183 8,792,352 8,792,352
1541
1542 Total Other Production Plant B8 1,917,469,54 1,806,122.078 111,347,462 50,841,716 162,189,178
1543
1544 Summary of Other Production Plant by Factor
1545 S
1546 DGU
1547 SG 1,917 ,469,540 1,806,122,078 111,347,462 50,841,716 162,189,178
1548 SSGCT
1549 Total of Other Prouction Plant by Factor 1,917,469,540 1,806,122,078 11,347,462 50,841,716 162,189.178
1550
1551 Experimental Plant
1552 103 Experimental Plant
1553 P SG
1554 Total Expenmental Production Plant B8
.~Total Production Plant B8 7,446.780,973 7,014,346,380 432,43,594 62.787,304 495.221,898
350 Land and Land Rights
1558 T SG 21,194,069 19,963,330 1,230,740 1,230,740
1559 T SG 48,573,482 45,752,820 2.820,662 2,820,662
1560 T SG 24,582,184 23,154,696 1,427,487 (44,192)1,383,295
1561 88 94,349,735 88,870,845 5,478.889 (44.192)5,434.697
1562
1563 352 Strctures and Improvements
1564 T S
1565 T SG 7,694,937 7,248,092 44,845 446,84
1586 T SG 18,309,921 17,246,664 1,063,257 1,063,257
1567 T SG 41,188,064 38,796,273 2,391,791 2,391,791
1568 B8 67,192,922 63,291,029 3.901,893 3,901,893
1569
1570 353 Station Equipment
1571 T SG 133,265,659 125,526,922 7,738,737 7,738,737
1572 T SG 193,113,579 181,899,473 11,214,106 11,214,106
1573 T SG 761,485,009 717,265,572 44,219,437 44.219,437
1574 88 1,087,864,247 1,024,691,967 63,172,280 63,172,280
1575
1576 354 Towers and Fixtures
1577 T SG 156,331,416 147,253,250 9,078,166 9,078,166
1578 T SG 126,710,448 119,352.372 7,358,076 7,358,076
1579 T SG 144,434,707 136,047,383 8,387,324 8,387,324
1580 88 427,476,570 402,653,005 24,823,566 24,823.566
1581
1582 355 Poles and Fixtures
1583 T SG 67,678,061 63,747,996 3,930.065 3,930,065
1584 T SG 118,054,192 111,198,785 6,855,407 6,855,407
1585 T SG 347.528,690 327.347,698 20,180,992 9,409,904 29,590,896
1586 88 533,260,943 502,294,478 30.966,465 9,409,904 40.376,368
1587.
ROLLED-IN Page 9.25
BeginninglEnding
FERC BUS UNADJUSTED RESULTS IDAH
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.356 Clearing and Grading
T SG 202,398,474 190,645,194 11,753.280 11,753,280
T SG 158,329,552 149,135,355 9.194,198 9,194,198
T SG 345,441,828 325,382,020 20,059,808 20,059,808
1592 B8 706,169,854 665,162,568 41,007,286 41,007.286
1593
1594 357 Underground Conduit
1595 T SG 6,371 6,001 370 370
1596 T SG 127,199 119,812 7,386 7,386
1597 T SG 3,110,028 2,929,428 180,599 180,599
1598 B8 3,243,597 3,055.241 188,356 188,356
1599
1600 358 Underground Conductors
1601 T SG
1602 T SG 1,053,107 991.954 61,154 61,154
1603 T SG 6,374,736 6,004,555 370,181 370,181
1604 B8 7,427,844 6,996,509 431,335 431,335
1605
1606 359 Roads and Trails
1607 T SG 1,876,730 1.767,748 108,982 108,982
1608 T SG 467,634 44,478 27,155 27,155
1609 T SG 9,118,473 8,588.963 529,510 529,510
1610 B8 11,462,837 10,797,190 665,647 665.641
1611
1612 TP Unclassified Trans Plant - Acct 300
1613 T SG 26,145,671 24,627,392 1,518,279 1,518,279
1614 B8 26,145,671 24,627,392 1,518,279 1,518,279
1615
1616 TSO Unclassified Trans Sub Plant - Acct 300
1617 T SG
1618 B8
1619
1620 Total Transmission Plant B8 2,96,594,220 2.792,440,224 172,153,995 9.365,712 181,519,707
1621 Summary of Transmission Plant by Factor
1622 DGP
1623 DGU.SG 2,964,594,220 2,792,440,224 172,153,995 9,365,712 181,519,707
Total Transmission Plant by Factor 2,964,594,220 2,792,44,224 17,153,995 9,365,712 181,519.707
360 Land and Land Rights
1627 DPW S 46,101,103 44,845,561 1,255,542 1,255,542
1628 B8 46,101,103 44,845,561 1,255,542 1,255,542
1629
1630 361 Structures and Improvements
1631 DPW S 54,801,132 53,649,815 1,151,317 1,151,317
1632 B8 54,801,132 53.649,815 1,151,317 1,151,317
1633
1634 362 Station Equipment
1635 DPW S 707,536.192 681,412,293 26,123,899 26,123,899
1636 B8 707,536,192 681,412,293 26,123,899 26,123,899
1637
1638 363 Storage Battery Equipment
1639 DPW S 1,457,805 1,457,805
1640 B8 1,457,805 1,457,805
1641
1642 364 Poles, Towers & Fixtures
1643 DPW S 852,220,217 796,061,097 56,159,120 56,159,120
1644 B8 852,220,217 796,061.097 56,159,120 56,159,120
1645
1646 365 Overhead Conductors
1647 DPW S 610,312,712 577.339,585 32,973,127 32,973,127
1648 B8 610,312,712 577,339,585 32,973.127 32,973,127
1649
.
ROLLED-IN Page 9.26
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL.,366 Underground Conduit
DPW S 272,932,062 265,989,584 6,942,477 6,942,477
68 272,932,062 265,989,584 6,942,477 6,942,477
1654
1655
1656
1657 367 Underground Conductors
1658 DPW S 657,548,834 634,906,532 22,642,301 22,642,301
1659 68 657,548,834 634.906,532 22,642,301 22,642,301
1660
1661 368 Line Transfonners
1662 DPW S 988.749,117 926,686,876 62,062,240 62,062.240
1663 68 988,749,117 926,686,876 62,062,240 62,062,240
1664
1665 369 Services
1666 DPW S 519,158,428 493,474,609 25,683,819 25,683,819
1667 68 519,158,428 493,474,609 25.683,819 25,683,819
1668
1669 370 Meters
1670 DPW S 185,783,461 171,965,927 13,817,534 13,817,534
1671 68 185,783,461 171,965,927 13,817,534 13,817,534
1672
1673 371 Installations on Customers' Premises
1674 DPW 5 8,837,226 8,674,620 162,607 162,607
1675 68 8,837,226 8,674,620 162,607 162,607
1676
1677 372 Leased Propert
1678 DPW S 24,829 22,392 2,437 2,437
1679 68 24,829 22,392 2,437 2,437
1680
1681 373 Street Lights
1682 DPW 5 60,412,919 59,820,436 592,483 592,483
1683 68 60,412,919 59,820,436 592,483 592,483
1684
1685 DP Unclassified Dist Plant - Acct 3004DPWS 29,000,576 27,607,894 1,392,682 1,392,682
68 29,000,576 27,607,894 1,392,682 1,392,682
DSO Unclassified Dist Sub Plant - Acct 300
1690 DPW S
1691 68
1692
1693
1694 Totl Dlstnbution Plant B8 4.994,876.612 4,743,915,027 250,961,585 250,961,585
1695
1696 Summary of Distribution Plant by Factor
1697 S 4,994,876,612 4,743,915,027 250,961,585 250,961,585
1698
1699 Total Distrbution Plant by Factor 4,994,876,612 4,743,915,027 250,961,585 250,961,585
.
ROLLED-IN Page 9.27
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1700 389 Land and Land Rights.G-SITUS S 8.960,984 8,763,345 197,639 197,639
CUST CN 1,128,506 1,064,733 43,773 43,773
PT SG 332 313 19 19
1704 G-SG SG 1,228 1,156 71 71
1705 PTD SO 5,598,055 5.283,845 314,210 314,210
1706 88 15,689,104 15.133,393 555,712 555,712
1707
1708 390 Structures and Improvements
1709 G-SITUS S 107,525,675 97.785,161 9,740,514 9,740,514
1710 PT SG 358,127 337,331 20,796 20,796
1711 PT SG 1,573,572 1,482,195 91,317 91,317
1712 CUST CN 12,092,854 11,623,794 469,059 469,059
1713 G-SG SG 3,992,709 3,760,852 231,857 231,657
1714 PTD SO 102,539,957 96,784.560 5,755,397 5,755,397
1715 88 228,082,895 211,173,894 16,309,001 16,309,001
1716
1717 391 Offce Furniture & Equipment
1718 G-SITUS S 14,469,238 13,520,356 948,881 948,881
1719 PT SG 146,768 138,245 8,523 8,523
1720 PT SG 151,643 142,837 8,06 8,06
1721 CUST CN 7,284,434 7,001,885 282,550 282,550
1722 G-SG SG 4,772,077 4,494,962 277,115 277,115
1723 P SE 141,948 132,794 9,155 9,155
1724 PTD SO 65,472,287 61,797,437 3,674.851 3,674,651
1725 G-SG SG 149,689 140,997 8,692 8,692
1726 G-SG SG 6,733 6,342 391 391
1727 88 92,594,817 87,375,854 5,218,963 5.218,963
1728
1729 392 Transportation Equipment
1730 G-SITUS S 71,167,779 66,239,302 4,928,477 4,928,417
1731 PTD SO 8,302,189 7,836,201 465,988 465,986
1732 G-SG SG 15,664,860 14,755,202 909,658 909,656
1733 CUST CN
1734 PT SG 969,353 913,062 56,290 56,290
1735 P SE 704,061 658,654 45,407 45,407.PT SG 138,132 130,110 8,021 8,021
G-SG SG 366,892 345,587 21,305 21,305
PT SG 44,655 42,062 2,593 2.593
1739 88 97,357,921 90,920,160 6,437,741 6,437,741
1740
1741 393 Stores Equipment
1742 G-SITUS S 8,827.725 8,234,269 593,456 593,456
1743 PT SG 221,981 209,091 12,890 12,890
1744 PT SG 649,740 612,010 37,730 37.730
1745 PTD SO 441,665 416,875 24,790 24,790
1746 G-SG SG 3,327,215 3,134,004 193,211 193.211
1747 PT SG 80,482 75,808 4,674 4,674
1748 68 13,548,809 12,682,057 866,752 866,752
.
ROllED-lN Page 9.28
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAl OTHER IDAHO ADJUSTMENT ADJTOTAl
1749.!394 Tools, Shop & Garage Equipment
G-SITUS S 31.393,987 29,763,311 1,630,676 1,630,676
PT SG 2.555,122 2,406,746 148,376 148,376
1753 G-SG SG 18.791,620 17,700,390 1,091,229 1,091,229
1754 PTD SO 4,099,455 3,869,360 230,096 230.096
1755 P SE 7,106 6,648 458 458
1756 PT SG 3,941,589 3,712,701 228,888 228,888
1757 G-SG SG 1,700,098 1,601,373 98,725 98,725
1758 G-SG SG 80,583 75,903 4,679 4,679
1759 B8 62,569,560 59,136,432 3.433,127 3,433,127
1760
1761 395 laboratory Equipment
1762 G-SITUS 5 27,235,892 25,899,356 1.336,536 1,336,536
1763 PT SG 112,594 106,056 6,538 6,538
1764 PT SG 503,523 474,283 29,240 29,240
1765 PTD SO 5,458,605 5,152,222 306,382 306,382
1766 P SE 42,438 39,701 2,737 2,737
1767 G-SG SG 5,882,451 5,540,857 341,594 341,594
1768 G-SG SG 253,001 238,309 14,692 14,692
1769 G-SG SG 62,070 58,66 3,604 3,604
1770 B8 39,550,574 37,509,250 2,041,324 2,041,324
1771
1772 396 Power Operated Equipment
1773 G-SITUS 5 91,078,979 84,258,324 6,820,655 6,820,655
1774 PT SG 981,699 924,692 57,007 57,007
1775 G-SG SG 27,825,498 26,209,671 1,615,827 1,615,827
1776 PTD SO 1,625.409 1,534,177 91,231 91,231
1777 PT SG 1,944.579 1,831,658 112,922 112,922
1778 P SE 73,823 69,062 4,761 4,761
1779 P SG
1780 G-SG SG 846,777 797,605 49.172 49,172
1781 B8 124,376,765 115,625,189 8,751,576 8,751,576
1782 397 Communication Equipment
1783 COM_EQ 5 104,664,435 98,048,898 6,615.537 303,278 6,918,815
1784 COM_EQ SG 5,558,946 5,236,138 322.808 322,808
.~COM_EQ SG 10,430,523 9,824,823 605,701 605,701
COM_EQ SO 50,030,157 47,222,048 2.808.109 132,336 2,940,446
COM_EQ CN 4,536,381 4,360,423 175,958 7,392 183,350
1788 COM_EQ SG 65,034,602 61,258,042 3.776,560 22,185 3,798,744
1789 COM_EQ SE 113.823 106,482 7,341 7,341
1790 COM_EQ SG 948,992 893,884 55,108 55,108
1791 COM_EQ SG 44,584 41,995 2,589 2,589
1792 B8 241,362,443 226,992,733 14,369,710 465,191 14,834,901
1793
1794 398 Misc. Equipment
1795 G-SITUS S 1.146,629 1,086,484 60,145 60,145
1796 PT SG 15,384 14,491 893 893
1797 PT SG 13,908 13,101 808 808
1798 CUST CN 197,260 189,609 7,651 7,51
1799 PïD SO 3,306,549 3,120,958 185,591 185,591
1800 P SE 2,600 2,432 168 168
1801 G-SG SG 1,451,292 1,367,016 84,277 84,277
1802 G-SG SG 1,325 1,248 77 77
1803 B8 6.134,947 5.795,338 339,610 339,610
1804
1805 399 Coal Mine
1806 P SE 267,496,478 250,244,957 17,251,521 11,825,175 29,076,696
1807 MP P SE
1808 B8 267,496,478 250.244,957 17.251,521 11,825,175 29,076,696
1809
1810 399l WIDCO Capita/lease
1811 p SE B8
1812
1813
1814 Remove Capita/leases
1815 B8
1816
ef
ROLLED.IN Page 9.29
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1817 1011390 General Capital Leases.~G-SITUS S 13,145,093 13,145,093
P SG 14,737,388 13.881,588 855,800 855,800
PTD SO 12,902,451 12,178,258 724,193 724,193
1821 69 40,784,932 39,204,939 1,579.993 1,579,993
1822
1823 Remove Capital Leases (40,784,932)(39,204.939)(1,579,993)(1,579,993)
1824
1825
1826 1011346 General Gas Line Capital Leases
1827 P SG
1828 69
1829
1830 Remove Capital Leases
1831
1832
1833 GP Unclassified Gen Plant - Acct 300
1834 G-SITUS S
1835 PTD SO 449,864 424,614 25,250 25,250
1836 CUST CN
1837 G-SG SG
1838 PT SG
1839 PT SG
1840 68 449,864 424,614 25,250 25,250
1841
1842 399G Unclassified Gen Plant - Acct 300
1843 G-SITUS 5
1844 PTD SO
1845 G-SG SG
1846 PT SG
1847 PT SG
1848 68
1849
1850 Total General Plant B8 1,189,214,176 1,113,613.890 75,600,286 12,290,366 87.890,652
1851
1852 Summary of General Plant by Factor
C S 479,616,416 44,743,899 32,872,517 303,278 33,175,796
DGP
DGU
SG 196,334,337 184,933,201 11,401,136 22,185 11,423,320
1857 SO 260,226,643 245,620,554 14,606,088 132.336 14.738,425
1858 SE 268,582,277 251,260,729 17,321,547 11,825,175 29,146.722
1859 CN 25,239,435 24,260,444 978,991 7,392 986,383
1860 DEU
1861 SSGCT
1862 SSGCH
1863 Less Capital Leases (40,784,932)(39,204,939)(1,579,993)(1,579,993)
1864 Total General Plant by Factor 1.189,214,17 1,113,613,890 75,600,286 12,290,366 87,890,652
1865 301 Organization
1866 1-SITUS S
1867 PTD SO
1868 I-SG SG
1869 68
1870 302 Franchise & Consent
1871 1-SITUS S 1,724,600 1,724,600 1,724,600
1872 I-SG SG 5,353,521 5,042.642 310,879 1,239,006 1,549,885
1873 I-SG SG 80,028,44 75,381,193 4,647,252 4,647,252
1874 I-SG SG 9,240,742 8,704,132 536,610 536,610
1875 P SG
1876 P SG 600,993 566,093 34,900 34,900
1877 68 96,948,301 89,694,060 7,254,241 1,239,006 8,493,247
1878
.
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL..303 Miscellaneous Intangible Plant
1-SITUS 5 1,805,661 1,413,280 392,381 392,381
I-SG 5G 69,007,965 65,000,672 4,007,293 341,910 4,349,203
PTD 50 370,355,652 349,568,206 20,787,446 243,409 21,030,856
1883 P 5E 3,623.519 3,389,829 233,690 233,690
1884 CUST CN 112,067,234 107,720,354 4,346,880 4,346,880
1885 P 5G 34,575 324,566 20,009 20,009
1886 P 5G
1887 B8 557,204,607 527,416,907 29,787,700 585,319 30,373,019
1888 303 Less Non-Utilty Plant
1889 I-SITUS S
1890 557,204,607 527,416,907 29,787,700 585,319 30,373,019
1891 IP Unclassified Intangible Plant - Acct 300
1892 I-SITUS 5
1893 I-SG SG
1894 P SG
1895 PTO SO 2,381,676 2.247,996 133,679 133,679
1896 2,381,676 2,247,996 133,679 133,679
1897
1898 Total Intangible Plant B8 656.534.583 619.358.963 37,175.620 1,824,325 38,999,945
1899
1900 Summary of Intangible Plant by Factor
1901 S 3,530,261 1,413,280 2,116,981 2,116.~81
1902 OGP
1903 OGU
1904 SG 164,576,241 155,019,298 9,556,943 1,580,916 11,137,859
1905 SO 372,737,328 351,816,202 20,921,126 243,409 21,164,535
1906 CN 112,067,234 107,720,354 4,346,880 4,346,880
1907 SSGCT
1908 S5GCH
1909 SE 3,623,519 3,389,829 233,690 233,690
1910 Total Intangible Plant by Factor 656,534,583 619,358,963 37,175,620 1.824,325 38,999,945
1911 Summary of Unclassified Plant (Account 106)
1912 OP 29,000,576 27,607,894 1,392,682 1,392.682
1913 OSO
1914 GP 449,864 424,614 25,250 25,250.HP
NP
OP 151,409,535 142,617,183 8,792,352 8,792,352
1918 TP 26,145,671 24,627,392 1,518,279 1,518,279
1919 T50
1920 IP 2,381,676 2,247,996 133,679 133,679
1~21 MP
1922 SP 3,141,303 2,958,888 182,415 182,415
1923 Total Unclassified Plant by Factor 212,528,625 200,483,966 12,044,659 12,044,659
1924
1925 Total Electric Plant In Service B8 17.252,000,564 16,283.674,484 96,326.080 86,267,707 1,054,593,787
.
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
1926 Summary of Electric Plant by Factor.S 5,478,023,29 5,192,072.206 285,951,083 303,278 286,254,361
SE 272,205,796 254,650,559 17,555,237 11,825,175 29,380,412
DGU
1930 DGP
1931 SG 10,772,285,771 10,146,739,103 625,546,667 73,756,116 699,302,784
1932 SO 632,963,971 597,436,756 35,527,214 375,746 35,902,96
1933 CN 137,306,669 131,980,798 5,325,871 7,392 5,333,263
1934 DEU
1935 SSGCH
1936 SSGCT
1937 Less Capital leases (40,784,932)(39,204,939)J1,579,993)(1,579,993)
1938 17,252,000,564 16.283,674,484 9 8,326,080 86,267,707 1,054,593.87
1939 105 Plant Held For Future Use
1940 DPW S 1,566,169 1,566,169
1941 P SNPPS
1942 T SNPT 7,405,028 6,975,018 430,010 (689,098)(259,088)
1943 P SNPP 4,461,651 4,202,563 259,088 259,088
1944 P SE 953,014 891,552 61,462 (61,462)°
1945 G SNPG
1946
1947
1948 Total Plant Held For Future Use B10 14,385,862 13,635,301 750,560 (750,560)(0)
1949
1950 114 Electric Plant Acquisition Adjustments
1951 P 5
1952 P SG 142,633.069 134,350,366 8,282,703 8,282,703
1953 P SG 14,560,711 13,715,170 845,541 845,541
1954 Total Electric Plant Acquisition Adjustment B15 U7,193,780 148,065,536 9,128,243 9,12.243
1955
1956 115 Accum Provision for Asset Acquisition Adjustments
1957 P 5
1958 P SG (76,874,453)(72,410,353)(4,46,100)(4,464,100)
1959 P SG (11.233,390)(10,581,067)(652,323)(652,323)
1960 815 (88,107,844)(82,991,421 )(5,116.423)(5,11,42)
1961.120 Nuclear Fuel
P SE
Total Nuclear Fuel B15
1965
1966 124 Weatherization
1967 DMSC 5 3,881,062 3,843,192 37,870 37,870
1968 DMSC SO +2,464)(2,325)(138)(138)
1969 816 3,8 8,598 3,840,867 31.731 37,731
1970
1971 182W Weatherization
1972 DMSC S 11,248,956 6.215,935 5,033,021 5,033,021
1973 DMSC SG
1974 DMSC SG
1975 DMSC SO
1976 816 11,248,956 6,215,935 5,033,021 5,033,021
1977
1978 186W Weatherization
1979 DMSC S
1980 DMSC CN
1981 DMSC CNP
1982 DMSC SG
1983 DMSC SO
1984 816
1985
1986 Total Weatherization B16 15,127.554 10,056,802 5,070.752 5,070,752
.
ROLLED-IN Page 9.32
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT AOJ TOTAL
1987.151 Fuel Stock
P DEU
P SE 109,294,160 102,245,504 7,048,656 2,054,721 9,103,377
1991 P SE
1992 P SE 8,274,373 7,740,737 533,635 533,635
1993 Total Fuel Stock B13 117,568,532 109,986,241 7,582,291 2,054,721 9,637,012
1994
1995 152 Fuel Stock - Undistributed
1996 P SE
1997
1998
1999 25316 DG& T Working Capital Deposit
2000 P SE (712,500)(666,549)(45,951)(45,951)
2001 613 (712,500)(666,549)(45,951)(45,951)
2002
2003 25317 DG& T Working Capital Deposit
2004 P SE (1,619,511)(1,515,065)(104,446)(104,446)
2005 613 (1,619,511)(1.515,065)(104,446)004,446)
2006
2007 25319 Provo Working Capital Deposit
2008 P SE
2009
2010
2011 Total Fuel Stock 613 115,236,521 107,804,628 7,431,893 2,054,721 9,486,615
2012 154 Materials and Supplies
2013 MSS S 82,786,565 78,005,253 4,781,312 4,781,312
2014 MSS SG 2,015,664 1,898,614 117,050 117,050
2015 MSS SE 4,485,530 4,196,247 289,283 289,283
2016 MSS SO 28,328 26,738 1,590 1,590
2017 MSS SNPPS 74,964,378 70,611,196 4,353,182 4.353,182
2018 MSS SNPPH (1,860)(1,752)(108)(108)
2019 MSS SNPD (4,617,053)(4,401,797)(215,256)(215,256)
2020 MSS SNPT
2021 MSS SG
2022 MSS SG.MSS SNPPS
MSS SNPPO 401,143 377,848 23,294 23,294
MSS SNPPS
2026 Total Materials and Supplies B13 160,062,695 150,712,348 9,350,347 9,350,347
2027
2028 163 Stores Expense Undistributed
2029 MSS SO
2030
2031 613
2032
2033 25318 Provo Working Capital Deposit
2034 MSS SNPPS (273,000)(257.147)(15,853)(15,853)
2035
2036 613 (273,000)(257,147)(15,853)(15.853)
2037
2038 Total Matenals & Supplies 613 159,789,695 150,455,201 9,334,494 9,334.494
2039
2040 165 Prepayments
2041 DM5C 5 3,256,834 3,054,764 202,069 202,069
2042 GP GP5 8,530,421 8,051,623 478,798 478,798
2043 PT 5G 4,434,208 4.176,714 257,494 257,494
2044 P 5E 2,754,616 2,576,964 177,652 177,652
2045 pro 50 20,011,329 18,888,126 1,123,203 1,123,203
2046 Total Prepayments B15 38,987,409 36,748,192 2,239,217 2,239.217
2047
.
ROLLED-IN Page 9.33Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTALti182MMise Regulatory Assets
051
DDS2 S 64,867,163 65,134,658 (267,496)(5,642)(273,138)DEFSG SG 6,201,060 5,840,964 360,096 (96,492)263,604
P SGCT 10,195,361 9.601,031 594,330 594,330
2052 DEFSG SG
2053 P SE
2054 P SG
2055 DDS02 SO 7,045,209 6,649,773 395,436 395,436
2056 B11 88,308.792 87,226.427 1,082,366 (102,134)980,232
2057
2058 186M Mise Deferred Debits
2059 LABOR S 4,035,508 4.035,508
2060 P SG
2061 P SG
2062 DEFSG SG 47,760,691 44,987,227 2,773,463 2,773,463
2063 LABOR SO 76,977 72,657 4,321 4,321
2064 P SE 8,320,293 7,783.697 536,597 53,205 589,802
2065 P SNPPS
2066 GP EXCTAX
2067 Total Misc. Deferred Debits 811 60,193,470 56,879,089 3,314,381 53,205 3,367,586
2068
2069 Working Capital
2070 ewc Cash Working Capital
2071 CWC S 41,655,381 39,375,775 2,279,606 (48,266)2,231,339
2072 CWC SO
2073 CWC SE
2074 B14 41,655.381 39,375,775 2,279,606 (48,266)2,231,339
2075
2076 OWC Ot Wor. cap.
2077 131 Cas GP SNP 11,667,121 11,024,630 642,491 (642,491)(0)
2078 135 Woring Fun GP SG 2,151 2.026 125 125
2079 141 Note Recabli GP SO 190,713 180,008 10,704 10,704
2080 143 Ot AI GP SO 26,532,240 25,043,030 1,489,210 1,489,210
2081 232 Al PTD S
2082 232 Al PTD 50 (5,452.206)(5,146,183)(306,023)(306,023)
2083 232 Al P SE (1.332,966)(1,246,999)(85,966)(85.966).i 232 Al T SG
2533 Othe Msc, Of. Cr.. P S
2533 Olhe _, Of, Cr P SE (5,835,725)(5,459,364)(376.361)(376,361)
2087 230 As Relir.Otlig.P SE (2,460,800)(2,302,097)(158,703)(158,703)
2088 230 As Relir. Otlig. P 5
2089 254105 ARC Reg liabiity P S
2090 254105 ARO Reg Liabiity P SE (546,812)(511,547)(35,265)(35,265)
2091 2533 Ch. Recamtion P 5E
2092 B14 22,763,716 21,583,504 1,180,212 (642,491)537,721
2093
2094 Total Working Capital 814 64.419,097 60,959,280 3,459,818 (690,757)2,769,60
2095 Miscellaneous Rate Base
2096 18221 Unrec Plant & Reg Study Costs
2097 P S
2098
2099 B15
2100
2101 18222 Nuciear Plant. Trojan
2102 P 5 (887,941)(887,941)
2103 P TROJP 2,111.016 1,986,370 124,646 124,646
2104 P TROJD 3,091,107 2,908,058 183,049 183,049
2105 B15 4,314,182 4,006,487 307,695 307,695
2106
2107
.
ROLLED.IN Page 9.34
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2108.1869 Mise Deferred Debits-Trojan
P 5
P 5NPPN
2112 B15
2113
2114 Total Miscellaneous Rate Base B15 4.314,182 4,006,487 307,695 307,695
2115
2116 Total Rate Base Additions B15 629,848.519 592,845,522 37.002,997 56,475 37,567,472
2117 235 Customer Servce Deposits
2118 CU5T 5
2119 CU5T CN
2120 Total Customer Service Deposits B15
2121
2122 2281 Prop Ins PTD 50
2123 2282 Inj& Dam PTD 50 (7,277,878)(6,869,383)(408,495)(408.95)
2124 2283 Pen & Ben pro 50 (20,615,854)(19,458,720)(1,157,134)(1.157,134)
2125 254 Reg Liab pro 5G
2126 254 Reg Liab PTO 5E (1,526,930)(1,428,455)(98.76)(37,793)(136,268)
2127 254 Ins Prov PTD 50
2128 B15 (29,420,662)(27.756,558)(1,664, i 04)(37,793)(1,701,897)
2129
2130 22844 Accum Hydro Relicensing Obligation
2131 P 5
2132 P 5G
2133 B15
2134
2135 22842 Prv-Trojan P TROJO (1,242,005)(1,168,456)(73,549)(73,549)
2136 230 ARO P TROJP (2.159,328)(2,031,829)(127,499)(127,499)
2137 254105 ARO P TROJP (2,119,578)(1,994,426)(125,152)(125,152)
2138 254 P 5
f,049.034)
(970,817)(78,217)69,396 (8,821)
2139 B15 6,569.945)(6,165,528)(404,417)69,396 (335,021)
2140
2141 252 Customer Advances for Construction
2142 OPW 5 (13,495,438)(13,462,782)(32,656)(130,469)(163,125)
2143 OPW 5E.T 5G (5.039,434)(4,746,794)(292,640)(111,531)(404,171)
OPW 50
CU5T CN (337,812)(324.709)(13,103)13,103 (0)
2147 Total Customer Advances for Construction B19 (18,872,683)(18,534,285)(338,399)(228,897)(š67,296)
2148
2149 25398 502 Emissns
2150 P 5E (2,744,693)(2,744,693)
2151 B19 (2,744,63)(2,744.63)
2152
2153 25399 Other Deferred Credits
2154 P 5 (4.615,986)(4,538,939)(77,048)(77,048)
2155 LABOR 50 (266,187)(251,246)(14,941)(626,062)(641,003)
2156 P 5G (14,588,478)(13,741,325)(847,153)(62,353)(909,506)
2157 P 5E 2,344,968)(2,193,735)(151,233)(151,233
2158 B19 1, 1 , 1 ,7 5 1,,46 1,7 ,7
.
ROLLED-IN Page 9.35
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2159.190 Accumulated Deferred Income Taxes
P S 6,096,945 5,645,485 451,460 (259,585)191,876
CUST CN 100,289 96,399 3,890 3,890
2163 P 18T
2164 LABOR SO 40,832,990 38,541,102 2,291,888 (127,301)2,164,587
2165 P DGP 184 184
2166 CUST BADDEBT 3,006,880 2,944,619 62,261 62,261
2167 P TROJD 137 129 8 8
2168 P SG 40,342,040 37,999,377 2,342,662 94,798 2,437,460
2169 P SE 14,266,483 13,346,402 920,081 1,041,638 1.961.720
2170 PTD SNP (0)(0)(0)(0)
2171 DPW SNPD 735,215 700,938 34,277 34,277
2172 P SSGCT 1,252,667 1,175,252 77,415 77,415
2173 Total Accum Deferred Income Taxes B19 106,633,831 100,449,888 6.183,943 749.551 6,933.494
2174
2175 281 Accumulated Deferrd Income Taxes
2176 P S
2177 PT DGP
2178 T SNPT
2179 B19
2180
2181 282 Accumulated Deferred Income Taxes
2182 GP S (1,311,327)(1,056,793)(254,534)1,392 (253,142)
2183 ACCMDIT DITBAL (1,453,442,766)(1,364,084,266)(89,358,500)(89,358,500)
2184 P SG
2185 LABOR SO (13,464,253)(12,708,526)(755,726)(13,50)(789,176)
2186 CUST CN 109 109
2187 P SE (14,328,925)(13,404,817)(924,108)541 (923,568)
2188 P SG (11,540,157)(10,870,020)(670,137)(4,905,429)(5,575,566)
2189 B19 (1,494,087,428)(1,402,124,422)(91,963,006)(4,916,838)(96,879,843)
2190
2191 283 Accumulated Deferred Income Taxes
2192 GP S (35,389,731)(34,297,130)(1,092,601 )655,897 (436,704)
2193 P SG (9,163,040)(8,630,942)(532,098)72,750 (459,348)
2194 P SE (14,313,463)(13,390,352)(923,111)(107.166)(1,030,277).LABOR SO (5,913,158)(5,581,262)(331,896)(331,896)
GP GPS (14,967,110)(14,127,031)(840,079)(840,079)
PTD SNP (7,142,462)(6,749,138)(393,325)(393,325)
2198 P TROJD 457,965 430,845 27,120 27,120
2199 P SG
2200 P SG (2,729,655)(2,571.144)(158,511)(158,511)
2201 P SG
2202 819 (89,160,655)(84,916,154)(4,244,501)621,481 (3,623.019)
2203
2204 Total Accum Deferred Income Tax B19 (1,476,614,252)(1.386,590.689)(90,023,563)(3,545,806)(93,569,369)
2205 255 Accumulated Investment Tax Credit
2206 PTD S
2207 PTD ITC84 (2,617,973)(2,617,973)
2208 PTD ITC85 (4,062,340)(4,062,340)
2209 PTD ITC86 (1.849,695)(1,849,695)
2210 PTD ITC88 (266,688)(266,688)
2211 PTD ITC89 (575,134)(575,134)
2212'PTD ITC90 (359,070)(308.867)(50,203)(50,203)
2213 PTD IBT 164,585 164,585
2214 Total Accumlated ITC B19 (9,730,900)(9,680,697)(50,203)164,585 114,382
2215
2216 Total Rate Base Deductions (1.563,024,062)(1,469,453,001 )(93.571,061)(7,011,623)(100,582.684)
2217
.
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FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJ TOTAL.108SP Steam Prod Plant Accumulated Depr
2221 P S
2222 P SG (845,561,293)(796,459,546)(49,101.747)(49,101,747)
2223 P SG (919,827,242)(866,412.871)(53,414,371 )(53,414,371 )
2224 P SG (498.460,826)(469,515,204)(28,945,622)(89,316)(29,034,938)
2225 P SG (185,135,732)(174,384,899)(10,750,833)(10,750,833)
2226 617 (2,448,985,093 )(2,306,772,521 )(142,212,572)(89,316)(142,301,888)
2227
2228 108NP Nuclear Prod Plant Accumulated Depr
2229 P SG
2230 P SG
2231 P SG
2232 617
2233
2234
2235 108HP Hydraulic Prod Plant Accum Depr
2236 P 5
2237 P SG (144,632,369)(136,233,567)(8,398,802)(8,398,802)
2238 P SG (28,211,936)(26,573,669)(1,638,267)(1,638,267)
2239 P SG (54,772,999)(51,592,331)(3,180,668)(20,559)(3,201,227)
2240 P SG (9,051,245)(8,525,640)(525,606)(525,606)
2241 617 (236,668,549)(222,925,206)(13,743,343)(20,559)(13,763,902)
2242
2243 1080P Other Production Plant - Accum Depr
2244 P S
2245 P SG (1,583,085)(1,491,155)(91,930)(91,930)
2246 P SG
2247 P SG (110,121,288)(103,726,545)(6.394.744)(1,209,870)(7,604,613)
2248 P SG (16,954,270)(15,969,736)(984,535)(984,535)
2249 817 (128,658,643)(121,187,435)(7,471,208)(1,209,870)(8,681,078)
2250
2251 108EP Expenmental Plant - Accum Depr
2252 P SG
II P SG
Total Production Plant Accum Depreciation B17 (2.814,312,285)(2,650.885.162)(163,427,123)(1,319,745)(164.746,868)56
2257
2258 Summary of Prod Plant Depreciation by Factor
2259 S
2260 DGP
2261 DGU
2262 SG (2,814,312,285)(2.650,885,162)(163,427,123)(1,319,745)(164,746,868)
2263 SSGCH
2264 SSGCT
2265 Total of Prod Plant Depreciation by Factor (2,814,312,285)(2,650,885,162)(163,421,123)(1,31§,745)(164,746,868)
2266
2267
2268 108TP Transmission Plant Accumulated Depr
2269 T SG (376,835,526)(354,952,686)
2270 T SG (377,107,334)(355,208,710)
2271 T SG (333.737,270)314,357,146)
2272 Total Trans Plant Accum Depreciation 817 ,1 8.
.
ROLLED.IN Page 9.37
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL.108360 Land and Land Rights
DPW S (5,426,114)(5.191,977)(234,137)(234,137)
817 (5,26,114)(5,191,977)(234,137)(234,137)
2277 108361 Structures and Improvements
2278 DPW S (14,430,466)(13,945,723)(484,743)(484,743)
2279 817 (14,430,466)(13,945,723)(484,743)(484,743)
2280
2281 108362 Station Equipment
2282 DPW 5 (185,020,533)( 176,682,885)(8.337,648)(8,337.648)
2283 817 (185,020.533)(176,682,885)(8,337,648)(8,337,648)
2284
2285 108363 Storage 8attery Equipment
2286 DPW 5 (749,006)(749,006)
2287 817 (749.006)(749,006)
2288
2289 108364 Poles, Towers & Fixtures
2290 DPW 5 (44,270,441 )(415,917,899)(28,352,542)(28,352,542)
2291 817 (44,270,441)(415,917,899)(28,352,542)(28,352,542)
2292
2293 108365 Overhead Conductors
2294 DPW 5 (247,818,052)(236,697,544)(11.120,508)(11,120,508)
2295 817 (247,818,052)(236,697,544)(11,120,508)(11,120.508)2296
2297 108366 Underground Conduit
2298 DPW 5 (114,081,755)(110,809,280)(3,272,474)(3,272,474)
2299 817 (114,081,755)(110,809,280)(3,272,474)(3,272,414)
2300
2301 108367 Underground Conductors
2302 DPW 5 (248,580,695)(237,936,176)(10,644,519)(10,644,519)
2303 817 (248,580,695)(237,936,176)(10,644.519)(10,644,519)
2304
2305 108368 Line Transformers
2306 DPW 5 (351,372,868)(326,280,612)(25,092,256)(25,092,256)
2307 817 (351,372,868)(326,280,612)(25,092,256)(25,092,256)
2308.108369 5ervices
DPW S (151,972,177)(141,438,180)(10,533,997)(10,533,997)
817 (151,972,177)(141,438,180)(10,533,997)(10,533,997)
2312
2313 108370 Meters
2314 DPW 5 (80,784,138)(73,845,763)(6,938,376)(6,938,376)
2315 817 (80,784,138)(73,845,763)(6,938,376)(6,938,376)
2316
2317
2318
2319 108371 Installations on Customers' Premises
2320 DPW S (6,850,076)(6,712,402)(137,675)(137,675)
2321 817 (6,850,076)(6,712,402)(137,675)(137,675)
2322
2323 108372 Leased Properly
2324 DPW 5 (20,556)(18,213)(2,343)(2,343)
2325 817 (20,556)(18,213)(2,343)(2,343)
2326
2327 108373 5treet Lights
2328 DPW 5 (24,224.319)(23,845,218)(379,101)(379,101)
2329 817 (24,224,319)(23,845,218)(379,101)(379,101)
2330
2331 108000 Unclassified Dist Plant - Acct 300
2332 DPW S
2333 817
2334
2335 10805 Unclassified Dist Sub Plant - Acct 300
2336 DPW 5
2337 B17
2338
2339 108DP Unclassifid Dist 5ub Plant. Acct 300
2340 DPW 5 264,929 257,429 7,500 7,500
2341 817 264,929 257,429 7,500 7,500
2342
2343
~Total Distribution Plant Accum Depreciation 817 (1,875,336.266)(1,769,813,44)(105,522,818)(105,522,818)
5ummary of Distribution Plant Depr by Factor
5 (1,875,336,266)(1,769,813.448)(105,522,818)(105,522,818)
2348
2349 Total Distribution DepreCiation by Factor 817 (1,875,336,266)(1,769,813,44)(105,522,818)(105,522,818)
ROLLED-IN Page 9.38
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2350 108GP General Plant Accumulated Depr.G-SITUS S (150,282,503)(138,259,608)(12.022,895)(3,668)(12,026,563)
PT SG (7,359,036)(6,931,697)(427,339)(427,339)
PT SG (14,294,098)(13,464,039)(830,058)(830,058)
2354 G-SG SG (42,466,304)(40,000,286)(2,466,018)879 (2,465,139)
2355 CUST CN (6,324,731)(6,079,407)(245,325)(287)(245,611)
2356 PTD SO (87,629,616)(82,711,111 )(4,918,504)(4,399)(4,922,903)
2357 P SE (451.561)(422,439)(29,122)(29,122)
2358 G-SG SG (43,709)(41,171)(2,538)(2,538)
2359 G-SG SG (2,417,343)(2,276,968)(140,375)(140,375)
2360 B17 (311,268,900)(290,186,725)(21,082,176)(7,474)(21,089,650)
2361
2362
2363 108MP Mining Plant Accumulated Depr.
2364 P S
2365 P SE (161,520,351)(151,103,497)(10,416,854)(1,424)(10,418,278)
2366 B17 (161,520,351)(151,103,497)(10,416,854)(1,424)(10,418,278)
2367 108MP Less Centralia Situs Depreciation
2368 P S
2369 B17 (161,520,351)(151,103,97)(10,416,854)(1,424)(10,418,278)
2370
2371 1081390 Accum Depr - Capital Lease
2372 PTD SO B17
2373
2374
2375 Remove Capital Leases
2376 B17
2377
2378 1081399 Accum Depr - Capital Lease
2379 P S
2380 P SE B17
2381
2382
2383 Remove Capital Leases
2384 B17
2385.Total General Plant Accum Depreciation B17 (472,789,251 )(441.290.222)(31,499.030)(8,899)(31,507,928)
2389
2390
2391 Summary of General Depreciation by Factor
2392 S (150,282,503)(138,259,608)(12,022,895)(3,668)(12,026,563)
2393 DGP
2394 DGU
2395 SE (161,971,912)(151,525,936)(10,445,976)(1,424)(10,447,401)
2396 SO (87,629,616)(82,711,111)(4,918,504)(4,399)(4,922,903)
2397 CN (6,324,731 )(6,079,407)(245,325)(287)(245,611)
2398 SG (66,580.490)(62,714,161)(3,866,329)879 (3,865,450)
2399 DEU
2400 SSGCT
2401 SSGCH
2402 Remove Capital Leases -
2403 Total General Depreciation by Factor (472,789,251)(441,290,222)(31,499,030)(8,899)(31,507,928)
2404
2405
2406 Total Accum Depreciation. Plant In Servce B17 (6,250,117,933)(5,886,507,374)(363,610,559)(1,398,263)(365,008,822)
2407 111SP Accum Prav for Amort-Steam
2408 P SG
2409 P SG
1311,848)1293,739)
(18,109)18,109 (0)
2410 B18 311,848)293,739)(18,109)18,109 (0)
2411
2412
2413 111GP Accum Prov for Amort-General
2414 G-SITUS S (15,781,365)(15,781,365)
2415 CUST CN (2,091,376)(2,010,255)(81,121)(81, 121)
2416 I-SG SG
2417 PTD SO (9,286,209)(8,764,989)(521,219)(521,219)
2418 P SE'
2419 B18 (27,158,949)(26,556,609)(602,340)(6t2,340)
2420.
ROLLED-IN Page 9.39
Beginning/Ending
FERC BUS UNADJUSTED RESULTS IDAHO
ACCT DESCRIP FUNC FACTOR Ref TOTAL OTHER IDAHO ADJUSTMENT ADJTOTAL
2421.111HP Accum Prov for Amort-Hydro
P SG (344,575)(324,566)(20,009)(20,009)
P SG
2425 P SG (5.298)(4,991)(308)(308)
2426 P SG (330,712)(311,508)(19,204)(19,204)
2427 B18 (680,586)(641,065)(39,522)(39,522)
2428
2429
2430 1111P Accum Prov for Amort-Intangible Plant
2431 I-SITUS S (758,514)(50,195)(708,319)(708,319)
2432 P SG
2433 P SG (307,541)(289,682)(17,859)(17,859)
2434 P SE (981,538)(918.236)(63,302)(63,302)
2435 I-SG SG (37,491,322)(35,314.201)(2.177,121 )(22,656)(2,199,777)
2436 I-5G SG (9,711,174)(9,147.246)(563,928)(563,928)
2437 1-5G SG (2,646,531 )(2,492,847)(153,684)(153,684)
2438 CUST CN (82,052,452)(78,869,790)(3,182,662)(3,182,662)
2439 P SG
2440 P SG (30,904)(29,110)(1,795)(1.795)
2441 PTO SO (244,166,020)(230,461.387)(13.704,632)(7,868)(13,712,500)
2442 B18 (378,145,996)(357,572,694)(20,573,302)(30,524)(20,603,825)
244 1111P Less Non-Utility Plant
2444 NUTIL OTH -
2445 (378,145,996)(357,572,694 )(20,573,302)(30,524)(20,603,825)
244
2447 111390 Accum Amtr - Capital Lease
2448 G-ITUS S (1,015.479)(1,015,479)
2449 P SG (839,977)(791,199)(48,777)(48,777)
2450 PTD SO 2,393,255 2,258,925 134,329 134,329
2451 537,799 452,247 85,552 85,552
2452
2453 Remove Capilli Lease Amtr (537,799)(452,247)(85,552)(85.552)
2454
2455 Total Accum Provision for Amortization B18 (406,297.379)(385,064,106)(21,233,272)(12,415)(21.245.687)
2456.
2460 Summary of Amortization by Factor
2461 S (17,555.357)(16,847,039)(708,319)(708,319)
2462 DGP
2463 DGU
2464 SE (981,538)(918,236)(63.302)(63,302)
2465 SO (251,058,974)(236,967,452)(14,091,522)(7,868)(14,099.390)
2466 CN (84,143,828)(80,880,045)(3,263,783)(3,263,783)
2467 SSGCT
2468 SSGCH
2469 SG (52,019,883)(48,999,088)(3.020,795)(4,547)(3.025,342)
2470 Less Capital Lease (537,799)(452,247)(85,552)(85,552)
2471 Total Provision For Amortization by Factor (406,297,379)(38s;64,106)(21,233,272)(12,415)(21,245,687)
.
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10
.
1
1
.Rocky Moulntn Powr
Result of Operatios
Decembr 2006
DEMAND
Month Day TimeJanOS 24 800Feb 5 80Mar-D 5 80Apr-08 1 80
May-08 19 160JunOS 30 140JuI-D 9 1700Aug-OS 14 1700Sep-os 8 160Oct-OS I 160Noy-08 5 180DecOS 15 180
I ML I LRLIJ LIJADli Il,PI
I Non.Fi:RI;-Fi;RC-
CA OR WA E,WY Total UT 10 W.WY UT NETUT Total
170 2.90 865 1.05 3.315 46 169 28 3,287 8,941
169 2,55 695 1.072 3.149 463 172 26 3.123 8.278
155 2,493 649 98 2.958 445 161 26 2,93 7.848
146 2.523 645 976 2.696 422 175 26 2.86 7.785
158 2.166 634 925 3,856 497 191 35 3.620 8.427
147 2.261 742 1.014 4,253 727 227 40 4.213 9.371
171 2.52 726 99 4.189 68 210 43 4.145 9.501
156 2.59 755 1.001 4.194 528 172 43 4.150 9,396
135 2,207 60 93 3.577 463 162 36 3,54 8,OSl
109 1,876 571 947 3,462 436 186 32 3.431 7,58
136 2.20 623 1,017 3.243 425 193 26 3,215 7.83
163 2,796 846 1.09 3.594 451 235 32 3.56 9.176
1.616 29.09 8.35 12,024 42.68 5.99 2,253 396 42,289 102,231
(less)
Adjusiints fo Curtilment. BuyThroughs and Loa No Longer Served (ReduC1lons 10 Loa)No..Fi:RI; FERC'WA E. WY UT 10 W, WY UT NET UT II
Mont Day Time CA ORJan-24 80Feb580
Mar-OS 5 80
Apr.OS 1 80
MayOS 19 160
JunOS 30 140JuI91700Aug141700
Sep-os 8 180
Oc-D 1 160
Nov-D 5 180
Oeo-OS 15 180
I
Mont Day Time CA OR
Jan-OS 24 80Feb580
Mar-OS 5 80
Apr-OS 1 80May19180Jun-30 1400JuI91700Aug141700Sep61600c1160
Nov-OS 5 180
Dec-D 15 180
Mon Day Time
Jan-OS 24 80.Feb 5 80
Mar-D 5 80
Apr-OS 1 80
May-OS 19 160
JunOS 30 1400
JulOS 9 1700
Aug-D 14 1700
SapOS 6 160
Oc-D 1 160
NovOS 5 180
Dec-D 15 180
Mon Day TimeJan2480Feb-5 80
Mar-D 5 80
Apr-D 1 80
MayOS 19 160
JunOS 30 1400JuI91700
Aug-OS 14 1700Se8160.0e 1 160
Nov-5 180
DecOS 15 180
Tota
(4)
(4)
(4)
(4)
(2)
(178)
(154)
(68)
(91)
(3)
(4)
(92)
1""8)
(4)
(4)
(4)
(4)
(2)
(2)
(2)
(2)
(2)(89)
(3)
(4)
(4)(68)
36 177
=equals
I COINCIDENTAl PEAK SERVED FROM COMPANY RESOURCES
I No..."Rl,Fi:1;
CA--OFt WA E.WY UT lu W.WY UT NETUT Tota
170 2,90 861 1,05 3,315 460 169 28 3,287 8.937
169 2,55 691 1,072 3.149 46 172 26 3.123 8.274
155 2,493 64 98 2,95 445 161 26 2.93 7,643
146 2,523 641 978 2.896 422 175 28 2.86 7.781
158 2.166 632 925 3.856 497 191 35 3,820 8,424
147 2.261 739 1.014 4.253 55 227 40 4,213 9.193
171 2,522 726 99 4.189 53 210 43 4.145 9.347
158 2.59 753 1,001 4.194 442 172 43 4,150 9.307
135 2,207 60 93 3,87 463 162 36 3.451 7.99
109 1.878 56 947 3.462 43 186 32 3.431 7,58
136 2.202 619 1,017 3.243 425 193 28 3,215 7.83
163 2.79 84 1.09 3.507 451 235 32 3,75 9.08
1.816 29.09 8.318 12.024 42.50 5,58 2,253 396 42,113 101.60
+ plus
Adjusment lor Anclla Services Conract Includng Reserves (Additions 10 Loa)Non.""..WA E. WY UT 10 W. WY UT NET UT I
Tota
37 37
37 3
= equals
I LOADS FOR JURISDICTIONAL ALLOCATION (CP) . Prior to Temperature Adjustment I
i NOn-LKl,ERe
CA OR WA E,WY UT iu W,WY UT NETUT Tot
170 2.90 861 1,05 3,315 46 169 28 3,287 8.937
169 2,55 691 1,72 3,149 46 172 26 3,123 8,274
155 2,493 64 98 2,95 445 161 26 2,93 7.843
146 2,523 641 978 2.69 422 175 28 2.86 7,781
158 2.166 63 925 3,85 497 191 35 3,82 8,424
147 2,261 736 1.014 4,253 55 227 40 4,213 9.193
171 2.52 726 99 4,189 53 210 43 4,145 9.347
156 2.59 753 1.001 4,194 479 172 43 4.150 9.34
135 2,2 60 93 3,487 46 162 36 3.451 7.99
109 1.878 56 947 3.46 436 186 32 3.431 7.585
136 2,202 619 1.017 3,243 425 193 28 3,215 7.83
163 2.796 84 1.09 3,507 451 235 32 3.475 9.08
1.816 29.09 8.318 12.024 42.50 5,62 2.253 3961 42.113 101.640
Pag 10.12
.
.
.
Rocky Moulnin Powr
Results of Oprations
Oecomber 2008
ENERGY
Year Moth2008 Jan.08
2008 Feb08
2008 Mar-08
2008 Apr.08
200 May-08
200 Jun-082008 Jul-8
2008 Aug-08
2008 Sop-08
2008 Oct-08
2008 Nov-08
2008 De-08
~FERC l
CA OR WA E.WY Totl UT 10 W.WY UT NeUT Totl
90.456 1,565.128 463.038 741.814 2,192.94 316.241 115.33 18.175 2,174,769 5,464,95
80.533 1,334.624 375,361 686.55 1.96.924 271,253 109.873 15.492 1,953.432 4,827,125
81.30 1.354,987 374.50 698,937 1,910,643 274,007 119,641 16,105 1,894,53 4,814,230
73.659 1.238,017 347,697 651,641 1.833,681 265,901 134,03 16,046 1,817,63 4,544,825
86.753 1.204,665 335,425 648.279 1.880,243 302,991 142.055 15.425 1,864,818 4,600,411
87,99 1.177.051 332,634 642,280 2.052.192 396,669 143,236 18,067 2,034.125 4,832,055
93.404 1.322.620 387.466 691.411 2.444.458 497,879 151,077 21,945 2.422,512 5,588,315
87.273 1.301.349 377.341 694.907 2,372.978 362,676 141.507 21,860 2,351,117 5.338.30
72.647 1.205.649 355.297 627.427 1.935.470 282.36 133.563 16.585 1,918.686 4,612.438
70.919 1.220,679 366.547 687.417 1.874.109 276.043 148.549 15.764 1,858,344 4,64,261
72870 1,230,623 375.175 678.012 1.920.419 251.394 143,134 14,565 1,90,854 4,671,627
90.601 1.513,115 479,491 747.065 2.135,948 279.185 161,031 16.935 2,119.013 5.406.436
988.418 15.668.507 4.569,977 8.195.948 24.522.007 3.776.624 1.643,227 206.965 24,315,042 59.36,7OS
(less)
Adjustmnt for Curtllmonts, Buy- Throug and load No lonr Servd (Reductons to loadlNon -"I(I, FERCE. WY UT 10 W. wY UT
(7.625)
II
Year Month CA
200S Jan-
2008 Feb-
2008 Mar-0200Apr-0
2008 May-08200Jun-
200 Jui-20 Aug08
2008 Sep8
2008 Oo1-OS
2008 No
200S Oec.OS
Year Moth CA OR
2006 Jan-08
2008 Feb-OS
2008 Mar-D8200Apr-D8
2008 May-OS200Jun-820Ju~08
200 Aug
2008 5e200Oo1.OS
200 Nov820000-0
ADS SERVED FRO
Yeir
2008
2008
2008
2008
2008200200
2008
2008200
200
2008
rED FROM COMPA
Year200200
200
2008
200200
20020020
200200
200
NET UT
(7.625)
Totl
(10.751)
(2,864)
(3,OS9)
(2,581)
(1,933)
(5,161)
(9,7OS)
(7,811)
(6,8n)
(2,326)(2,59)
(9,969)
165,6871
OR WA
(3,125)
(2,68)
(3.089)
(2.581)
(1,933)
(1,35)
(Î,ôì5)
(1,529)
(1,661)
(2,326)
(2.599)
(2,748)27.50 (7,221)
138.184)
(7,221)
38,164
(3,809)
(8,032)
(6,282)
(5.215)
(3,60)
(8,032)
(6,282)
(5,215)
=equals
Month
Jan-0Feb-
Mar-0
Apr-D8May-Jun-
Ju~OSAug
Sep-OS001-0N08
00-D8
M COMPANY RESOURCES (NPC)
i Non-F FERC
CA OR WA t:.WY UL 10 W.WY UT NeUT lotl
90.456 1,565.128 459,913 741,814 2.185.318 316,241 115,33 18,175 2.167.143 5.474,203
80.533 1.334,624 372.477 686,55 1.968,924 271,253 109,873 15.492 1,953,432 4.624,241
81,30 1,35,987 371.417 698,937 1.910.643 274,007 119.641 16,105 1.894.53 4.811.141
73.659 1,238.017 345.115 651,641 1,833,681 265.901 134.030 16,046 1,817,635 4.542,244
86.753 1.204,665 333.492 648,279 1,88,243 302,991 142,055 15,25 1,86.818 4.59.478
87,99 1,177,051 331,281 642,260 2,04.36 396,669 143,236 18.67 2,030,316 4,826,895
93.404 1.322,620 385,791 691.411 2.436.426 497,879 151,077 21,945 2.414,481 5,578.6OS
87,273 1,301.349 375,812 694,907 2,36.695 362.676 141,507 21,860 2,344,835 5,330,220
72,647 1,205,649 353,635 627,427 1,930.255 282,385 133.563 16,585 1.913,670 4.605,581
70.919 1,220,679 36,220 687,417 1,874,109 276.043 148,549 15.764 1.858.34 4,641,935
72,870 1,230,623 372,576 678,012 1.920,419 251,39 143.134 14.58 1,905,854 4.669,029
90.601 1,513,115 476,744 747.065 2.128,727 279.185 161,031 16,935 2,111,792 5,396.467
988.418 15.668,507 4.542.474 8.195,948 24.483,623 3.776,624 1.643,227 ~24~276.858 59,299,021
+ plus
Adlustment fo Ancillary Servic Conlraet Including Reserv (Adtins 10 loa
NonFERCWA E,WY UT 10 W.WY687 53982 640751 762869 5741,09 42640S 776482 3.827
291 5.409310 1.702522 1,023127 7,419117 5,68
6,647 28,981
lFERC
UT NelUT
687
982
751
8691,09
408
482
291
310
522
127
117
6,
Totl
1,225
1,822
1,514
1,44
1.525
1,1644.30
5,700
2,012
1,546
7,54
5,01
35,628
= equals
Month
Jan-OSFeb-
Mar-0
Apr-OSMay-
Jun-8Ju1AugSep-
001-D8Nov-00-0
NY RESOURCES (NPC). Prior to Temperature Adjustmnt
i NoFERC 'ERC
CA OR WA t:.W UT 10 W.WY UT UT iotI'
90,456 1.565,128 459,913 741,814 2,186,00 316,779 115,333 18.175 2.167.830 5.475,428
80,533 1,33,624 372,477 686,55 1,969,90 272,093 109,873 15,492 1,954,414 4,826,06
81,309 1,354,987 371,417 698,937 1.911,394 274,770 119,641 16.105 1.895,289 4.812,65
73,659 1,238,017 345,115 651,641 1.834,55 266,475 134.030 16,046 1,818,50 4,543,688
86,753 1,204,665 33,492 648,279 1,881,342 303,418 142,05 15,425 1,865,917 4,600,003
87,99 1,177,051 331,281 642,280 2,048,791 397,445 143,236 18,06 2,03,724 4.828,07
93,404 1.322,620 36.791 691,411 2.436,90 501,705 151,077 21,945 2,414,96 5,582,917
87.273 1,301,349 375,12 694,907 2,366,987 368,OS5 141,507 21,860 2,345,127 5,33,920
72,647 1.2,649 353,63 627.427 1,930,56 264,08 133,56 16.85 1.913,98 4,607,574
70,919 1.220,679 36,220 687,417 1,874,631 27706 148,549 15,764 1.58,86 4,643,480
72870 1.230,623 372.576 678,012 1,920,545 258,814 143,134 14,565 1,90,981 4,676,575
90,601 1,513,115 476,744 747,06 2.128,84 264,86 161,031 16.935 2,111,90 5.402,268
988.418 15.668:!;1l 4,542.474 8.195,948 24.490.470 3.1l5,ti 1,643,227 24,~59.33,649
Pag 10.13
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6~4,
5
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31
6
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27
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15
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1
0
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5
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4
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3
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4
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0
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2~29
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3
9
5
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3
4
7
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2,6
1
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1
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7
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4
9
3~29
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9
3
9
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3
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2
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1
8
6
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0
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5
1,9
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9
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4
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5
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1
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3
4
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3
6
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9
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6
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9
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7
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5
6
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7
4
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6
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1
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0
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5
4
5
2.
1
2
8
,
8
4
4
24
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4
9
0
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4
7
0
°
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,
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,
18
,
1
7
5
15
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9
2
16
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1
0
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16
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0
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4
2
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0
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21
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9
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5
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5
15
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7
6
4
14
.
5
6
5~20
6
,
9
6
5
°
°
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FE
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In
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(1
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3
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9
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7

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9
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3
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4
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7

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5
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7
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4
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34
5

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6
9
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2
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4
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2
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4
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9
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7
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28
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9
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4
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1
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9
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20
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9
6
5
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32
2

I
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R
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f
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In
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32
3

H
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4
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32
6
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IDAHO.ANNUAL EMBEDDED COSTS
December.OS
AVERAGE BALANCE
Company Owne Hydro - West
Accoun Description Amou Mwh $IMwh Dlfrenllal Referenc
53.545 Hyro Option & Maintenanc Expense 29.156.34 Page 2,7. West only 40P Hyro Depratin Expee 11.391.017 Page 2,15. Wesionly
4D4IP Hyd Relicensing Amortn 5.377217 Page 2,16. West only
Total West Hydro Operating Expens 45,924,58
330- 33 Hy Elecc Plan in Se 467.174.426 Page 2.23. West on
302 & 182M Hyro Reficeing 99.703.221 Page 2,29. West only
108HP Hy Acculate Depreatn Reserv (199.674.307)Page 2.36. West only
l111P Hyro Reling Accmulated Reserve (9.991,543)Page 2.39. West ony
154 Materals an Suppli (1.86)Page 2,32, West only
Wesl Hydro Ne Rat Ba 357,209,937P..ta Ret 11,39%
Rate Bas Revenue Requirement 40,672,54
Annual Embedded CosWesl HydroElectric Resorcs 86,597,125 3,68,158 23,51 (65,382,628) MWh from GRID
Mid C Contra
Account Descriion Amount Mwh S/wh Difrential Referenc
55 Annual Mid-C Contac COLS 32.99,847 1.778,35 18.55 (40,36.39) GRIDGrant Reanale Port (10.573.08)(10.573.08) GRID
22.419.763 (50,941,46)
Qualified Facilits
Account Descriptio Amo Mwh Slh Dlffrenllal Referenc55Uta Annual Qualified Faclites Cots 24.$.527 36,09 63,29 8.55.87255Oron Annua Quaifie Faclities CoSIs 37.935,194 261.867 144.86 27.132.59255Idaho Annl Quafifi Facfili Cots 4.09.431 75,96 53,93 963.69655WY Annl Quifi FacHties Cols55WY Annu Quaifi Facties Cots 694.735 11,381 61,04 225,244
555 California Annul Oualfi Fac Co 3.881.45 33,68 115,22 2.491,63155Washingto Annl Quaifi Facfities Cols 1,874,29 13,121 142.85 1.333.024
Tota Ouaillied Faclies COSIs 73.04,63 784,136 93,15 40.697.259 GRIO.All Other Generaon Resourc
(Exct West Hyd. Ml C, an QF)
Account Descriio Amount Mwh Slh Referenc
50- 514 Ste Operatin & Mai Expene 925.126,00 Page 2,5
53.545 East Hy Opern & Maien Expen 9,370,933 Page 2.7. East ony
546- 55 our Gen Operatn & Maintna Expe 56.628,847 Page 2.8
55 our Pur Power Cont 654,58,136 GRID le OF an Mid-C
40910 R.._ Ene Cre (85.643,969)Page 2.20
4118 S02 Emisn A_an (3.190,05)Page 2,4
James Riv I LiI Mounn Oft (9.109.698)James Riv Adj (Tab 5)
Gre Tag Reven (7.991.770)Gre Tag (Tab 3)
40SP Stem Depreat Exe 108,100,05 Pag 2,15
403P East Hy Depren Ex 4,294,95 Page 2,15. East on40Ot G..n Depreat Expee 95,657,34 Page 2.15
4D3P Mini Deretin Ex 44,164 Page 2,15
4D4IP Easi Hyd Rellcensing Amort 326.365 Page 2,16, Easi on
406 Amonitin of Plant Acqn CoSIs 5.479,35 Pag 2.17
T oIal All Other Operating Exnss 2,57,881,674
310- 316 Steam E1ecc Plat In Se 5.149,80,67 Page 2.21
33- 33 Easl Hy EIe Plan in Ser 118,039.471 Page 2,23. East ony
302& 186 East Hyd Relns 9,841,735 Page 2,29. Eat on
34- 346 Ot Elecc Plant in Se 2,792,99,136 Page 2.24
39 Ml 45,85,790 Page 2.26 l08P Ste Aculat Depatn Reser (2,45,52,17)Pag 2.36
lD6P Ot Genrati Acculat Deat Reser (149,493319)Page 2.36
108P Ot Accul Dep Reer (161,542,433)Page 2,38, East on
l08HP Easl Hy Acculte Depatn Res (37,34,2)Page 2.36, East on
llllP Easl Hy Raliceing Acculated Reser (2,95,072)Pag 2.39, East on
114 EIe Plan Acqti Adustmen 157,193.780 Pag 2.31
115 Acul Provin Acqitin Adjtmen (88107,64)Pag 2.31
151 Fue Sib 149,428,374 Page 2.32
253,16-253,19 Jont Owne we Dep (2.605.11 )Page 2.32
253.98 502 Emisio Alloanc (42,55,319)Page 2.34
154 M_ & Su 74,96,378 Page 2.32
154 East Hyd Matls & Su
Totl Net Rat Bas 5,967,99,885P..ta Ret 11,9%
Rat Bas Revenue Requirement 679,52508
Annual Embed_ CosAll Other Generation ReS0S 2,937,407'-71,20,025 4125 MWh fr GRID.Total Annual Embeddd Cost 3,119,469,021 77.452,678 4028
Page 10.23
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