20080731AVU to Staff 205-208, 210-212, etc.pdf

Avista Corp.
1411 East Mission P.O. Box 3727
Spokane. Washington 99220-0500
Telephone [phone]
Toll Free 800-727-9170
~~JV'STA'
Corp.
A.
,j I
July 29,2008
Idaho Public Utilities Commission
472 W. Washington St.
Boise, il 83720-0074
Attn: Scott Woodbur
Deputy Attorney General
Re: Production Request of the Commission Staff in Case Nos. AVU-E-08-01 and
A VU-G-08-01
Dear Mr. Woodbury,
Enclosed are an original and three copies of Avista's responses to IPUC Staffs production
requests in the above referenced docket. Included in this mailing are Avista's responses to
production requests 205 through 208, 210 through 212, 215 through 217, and 219. The
electronic versions of the responses were emailed on 7/29/08 and are also being provided in
electronic format on the CDs included in this mailing.
If there are any questions regarding the enclosed information, please contact me at (509) 495-
8620 or via e-mail atpat.ehrbar(favistacorp.com
Sincerely,O~~
Patrick Ehrbar
Regulatory Analyst
Enclosures
CC:Brad Purdy, CAP AI (paper and Email)
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
IDAHO
A VU-E-08-01 1 A VU-G-08-01
IPUC
Production Request
Staff-205
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
07/25/08
Wiliam Johnson
Wiliam Johnson
Power Supply
[phone]
REQUEST:
In reference to the adjustment shown on line 5 of Exhibit No.6, Schedule 2, p. 1 of 2, (W.
Johnson), please provide a narative explanation, along with contract excerts, workpapers,
spreadsheets or any other documentation supporting the increase in purchased power costs for the
Priest River Project from 2007 actual to 2009 pro forma costs.
RESPONSE:
The Priest Rapids Project expense contains many components in 2009. Beginnng November
2009, the Priest Rapids Project includes both the Priest Rapids Development and the Wanapum
Development. Prior to the expiration of the Wanapum contract on October 31, 2009, the Priest
Rapids Project includes only the Priest Rapids Development.
For the first ten months of 2009, the Company receives power from 3.28% of the Priest Rapids
Development. This is split into two pars: 1) Surlus Conversion of .41 % at project cost
($18.03/M) and 2) Meaningful Priority of2.87% at market rate (use AURORA model price).
Because Grant PUD's load requirement exceeds their power (under critical water) from Priest
Rapids (70%) and Wanapum (36.5%), the Reasonable Portion Revenue that would offset a portion
of the Meaningful Priority expense is zero for the first ten months. These calculations are shown
on page P8 of Wiliam Johnson's workpapers.
For the last two months of 2009, the Company receives power from 3.79% of the Priest Rapids
Project (this includes both the Priest Rapids Development and the Wanapum Development). This
is split into two pars: 1) Surplus Conversion of .49% at project cost ($19.05/MW) and 2)
Meaningful Priority of 3.30% at market rate (use AURORA model price). Because Grant PUD's
load requirement does not exceed their power (under critical water) from Priest Rapids (70%) and
Wanapum (70%), the Company expects to receive 50% ofthe Reasonable Portion Revenue that
offsets a portion of the Meaningful Priority expense in November and December. These
calculations are shown on page P8 of Wiliam Johnson's workpapers.
There are several reasons that the Priest Rapids Project costs are increasing. First, the project is
becoming more expensive with relicensing, trbal settlements and equipment upgrades and
replacement. Whle this adds to expense, the project is stil a very low cost resource under
$20/M.
The second, and most important, factor increasing the Priest Rapids Project cost is Grant PUD's
load growth. As described above, Avista receives the majority of the project output though its
Meaningful Priority slice. The price of the Meaningfl Priority slice is set by an auction. The pro
forma assumes that the auction price is the market price from the AURORA modeL. Under the
contract, if Grant PUD's load requirement was met, under critical water, by their share of
the Priest
Page 1 of2
.
.
.
Rapids Project then the Reasonable Portion Revenue (the difference between the auction price and
project cost) would offset the Meaningful Priority cost (auction price) and the net effective price of
the Meaningful Priority slice would be close to project cost. However, as Grant's load has been
increasing at a very rapid rate, due to large server fars and other energy intensive industres
locating or expanding in their service area, Grant each year is taking a larger share of the
Reasonable Portion Revenue so that the net effect is to be able to sere their load at project cost.
Effectively, even though Grant does not physically receive all of the Priest Rapids Project, they
financially receive the benefits of the low project cost for all but the small Surplus Conversion
slice of the project (some small Idaho Coops also receive some of the financial value of the
project).
Grant has gone from taking only around 50 percent of the Reasonable Portion Revenue in the 2007
test year to 100 percent of the Reasonable Portion Revenue in the 2009 pro forma period. This is
the primary driver of the large increase in the Priest Rapids Project cost. The overall Priest Rapids
Project cost is stil less than the market, but much closer to market cost, and less close to project
cost, than it was in 2007.
Attached are the 2008 final pro formas for the Priest Rapids ("S tafC PR _ 212 _Attachment-A. pdf')
and Wanapum Developments ("StafCPR_212_Attachment-A.pdf'), which shows how the
calculations are derived (for 2008) and support the cost estimates of project cost in the 2009 pro
forma period.
Page 2 of2
l.
.
2008 Priest Rapids Development
FINAL PROFORMA
November 30, 2007
.
.
StafCPR_205 _Attachment-A. pdf Page 1 of 31
;
.
.
.
2ppa.PRQFORNI~
CALQULATIONOF NET DISTRicT SIiARE
SECTION 5(b)(11
ESTIMATED DISTRICT LOADS PLUS LOSSES
SECTION 5(b)(2)
ESTIMATED FIRM PRP ENERGY
PRIEST RAPIDS
PNCA TOTAL HYDRO
CEAEA
NET PRIEST RAPIDS TOTAL HYDRO
WANAPUM
PNCA TOTAL HYDRO
CEAEA
NET WANAPUM TOTAL HYDRO
SECTION 5(b)(3)
DISTRIt;TRESER\iEI).SHARE
DISTRICT LOADS PLUS LOSSES
36.5% NET WANAPUM TOTAL HYDRO
SUBTOTAL
AS A PERCENT OF NET PRIEST
RAPIDS TOTAL HYDRO
=OR"'70%
SECTION 500
ESTIMATED UNMEr DISTRICT LOAD (EUDl) (aMW)
DISTRICT LOADS PLUS LOSSES
36.5% NET WANAPUM TOTAL HYDRO
NET PRIEST RAPIDS TOTAL HYDRO
NET EUDL
ADJUSTMENTS TO DISTRICT RESERVED SHARE
DISTRICT RESERVED SHARE
CONVERSION ADJUSTMENT
(DRS%-36.5%)/8
ADJUSTED DISTRICT RESERVED SHARE
EXCHANGE ADJUSTMENT
NET DISTRICT SHARE
DISPLACEMENT POWER (aMW)
DISPLACEMENT STEP UP (aMW) (Per 1956 Contrct)
DISPLACEMENT POWER wI STEP UP (aMW)
2008 Final Pries! Rapids Proforma 1 of 30
StafCPR_ 205 -fttachment-A.pdf
2008 FINAL
PROFORMA
438.5
122.5
316.0
70.00%
438.5
122.5
222.8
93.2
70.00%
4.21%
65.79%
3.93%
61.86%
10.1
198.1
1112812007
Page 2 of 31
.1 FINAL 2008PROFqRI\A VS., fINAL 2()07PROFORMA
CALCULATION OF NET DISTRICT SHARE COMPARISON
. . .438.5.
2007 FINAL
PROFORMA
aMW
~. ~6..9
VARIANCE
~31.6.
SECTION 5(b)(11
ESTIMATED DISTRICT LOADS PLUS LOSSES
SECTION S(b)(21
ESTIMATED FIRM PRP ENERGY
PRIEST RAPIDS
PNCA TOTAL HYDROCEA
NET PRIEST RAPIDS TOTAL HYDRO
WANAPUM
PNCA TOTAL HYDROCEA
NET WANAPUM TOTAL HYDRC
SECTION 5(bU3l
DISJRIC'lRESERVlQ.SIiARE
DISTRCT LOADS PLUS LOSSES
36.5% NET WANAPUM TOTAL HYDRC
SUBTOTAL
AS A PERCENT OF NET PRIESl
RAPIDS TOTAL HYDRO
= ORC:70"k
2008 FINAL
PROFORMA
aMW
.
SECTION S(f
ESTIMATED UNMET DISTRICT lOAD (EUDL) (aMW)
DISTRICT lOADS PLUS lOSSES
36.50/ NET WANAPUM TOTAL HYDRC
NET PRIEST RAPIDS TOTAL HYDRO
NET EUDl
ADJUSTMENTS TO DISTRICT RESERVED SHARE
DISTRICT RESERVED SHARE
CONVERSION ADJUSTMENT
(DRS%-36.5%)18
ADJUSTED DISTRICT RESERVED SHARE
EXCHANGE ADJUSTMENT
NET DISTRICT SHARE
DISPLACEMENT POWER (aMW)
DISPLACEMENT STEP UP (aMW) (Per 1956 Contract)
DISPLACEMENT POWER wi STEP UP (aMW)
438.5 406.31.6
122.5 122.4 0.1
316.0 284.5 31.5
70.00/70.00%0.00%
438.5 406.9 31.6
122.5 122.4 0:1
22.8 223.4 (0.6)
93.2 61.1 32.1
70.00%70.00%0.0%
4.21%4.21%0.00%
65.79%65.79%0.00%
3.93%3.93%0.00%
61.86%61.86.1.0.00%
.
2008 Final Priest Rapids Proforma StafCPR_205~ÅdBchment-A.pdf
1iYQgÇf 31
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PRIEST RAPIDS PROFORMA BUDGETED COST BY PROGRAM.FINAL 2008 PROFORMA vs. FINAL 2007 PROFORMA
2008 2007 FINAL
PROGRAM PROGRAM DESCRIPTION PROFORMA PROFORMA VARIANCE
Generation Operations
P5020 Upstream Migrants $464,447 $269,731 $194,716
P5031 Bldgs&Grounds..&M-Hydro 215,975 180,147 35,828
P5050 Business System Development 1,068 3,112 (2,045)
P5120 Ferc Hatchery Comp Requirements 581,618 429,400 152,218
P5130 Ferc Os Migrant Requirements 4,724,624 3,768,202 956,422
P5140 Ferc Minimum Flow Requirements 423,524 244.268 179,256
P5170 General Administration 26,195 25.530 665
P5320 Hydro Engineering Operations 331,553 161,403 170.150
P5350 Property/Liabilty Claims Admi 5,000 5,000
P5390 Recreation & Tourist Facilties 294.279 263.301 30,978
P5450 Telecommunications 48.880 10.178 38,702
P5480 Training & Education 221.920 46,921 175,000
P7220 Pr Electrical Maintenance 221,028 219,858 1.169
P7221 Pr Mechanical Maintenance 587,681 615,451 (27.770)
P7241 Pr Generation Operations 2.637,921 2,735.826 (97.905)
P9115 Ferc License-Pr Project 49,564 41,425 8.139
Generation Operations Total 10,835.276 9.019.753 1,815,523
Generation Maintenance
P1610 Wildlife Issues 196,898 141,099 55,799
P3620 Pr Powerhouse Improvements 20,230 20,230
P5030 Bldgs&Properties 152.062 268,418 (116.356).P5031 Bldgs&Grounds-O&M-Hydro 309,001 345,381 (36,381)
P5120 Ferc Hatchery Comp Requirements 3.790.910 740,185 3,050.725
P5130 Ferc Os Migrant Requirements 89,771 62,831 26.940
P5250 Load & Resource Planning 81.858 129,642 (47.785)
P5271 Tools & Test Equipment-Hydro 45,518 31,826 13.692
P5320 Hydro Engineering Operations 1,506,215 970.263 535,952
P5390 Recreation & Tourist Facilties 681.857 639,952 41.905
P5420 Security & Fire Protection 133,992 133,992
P5450 Telecommunications 21,355 36,472 (15,117)
P7220 Pr Electrical Maintenance 948,460 1,049.533 (101,073)
P7221 Pr Mechanical Maintenance 2,342,057 1,774,499 567,558
P7224 M/C Electrical Maintenance 59,263 45,331 13,932
P7225 M/C Mechanical Maintenance 181,652 160.111 21,541
P9115 Ferc License-Pr Project 65,673 (65,673)
Generation Maintenance Total 10,561,098 6,461,216 4,099,882
Transmission Operation
P5320 Hydro Engineering Operations 4,083 3.690 393
P5340 Control & Accounting 309.172 231,944 77,228
P5530 Transmission Operations 752,705 524,374 228,331
P591 0 Electonics System Maintenance 37,791 49,696 (11,905)
P7240 Wanapum Generation Operations 179.794 (179,794)
P7241 Pr Generation Operations 179,794 (179,794)
P8170 Work To Be Reimbursed (371,217)(353.041)(18.176)
Transmission Operation Total 732,535 816,251 (83,716)
Transmission Maintenance
P5521 Project Switchyard O&M 12,366 5,202 7.164
P5530 Transmission Operations 3,755 3,711 44.Transmission Maintenance Total 16,122 8,913 7,209
2008 Final Pnest Rapids Proforma StafCPR_2êl~Wáchment-A.pdf 1Øl?~bf 31
.
.
.
PRIEST RAPIDS PROFORMA BUDGETED COST BY PROGRAM
FINAL 2008 PROFORMA V5. FINAL 2007 PROFORMA
PROGRAM PROGRAM DESCRIPTION
Administrative & General
P5030 Bldgs&Propertes
P5050 Business System Development
P5060 Computer O&M (License Fees)
P5120 Ferc Hatchery Comp Requirements
P5130 Ferc Os Migrant Requirements
P5152 Environmental Compliance
P5160 General Accounting & Reporting
P5170 General Administration
P5190 Strategic Planning
P5200 Safety And Medical
P5275 Office Furniture & Equipment
P5310 Power Mgmt Contract Admin
P5320 Hydro Engineering Operatons
P5340 Control & Accounting
P5350 Property/Liabilty Claims Admi
P5370 Purchasing/Contract Admin
P541 0 Regional Planning
P5450 Telecommunications
P5480 Training & Education
P5490 Treasury & Debt Administration
P591 0 Electronics System Maintenance
P6116 Business Network
P6120 Fiber Backbone
P8170 Work To Be Reimbursed
P9115 Fere License-Pr Project
P9999 General Ledger
Administrative & General Total
Taxes
P5160 General Accounting & Reportng
Taxes Total
Debt Service
P5490 Treasury & Debt Administration
Debt Service Total
Total Cost Per Detail
2008 2007 FINAL
PROFORMA PROFORMA VARIANCE
179,319 13,373 165,946
197,587 115,941 81,647
950,020 831,777 118,243
1,213,574 1,206,784 6,790
341,503 360,043 (18,541)
213,106 101,348 111,758
286,933 268,306 18,627
6,409,615 2,451,109 3,958,506
121,598 84,054 37,544
236,873 171,297 65,575
26,815 26,260 555
25.168 18,530 6,638
1,469,174 1,666,481 (197,307)
2,529 6,079 (3,550)
800,248 763,222 37,027
244,708 237,463 7,245
279,208 340.973 (61.765)
399,331 282,654 116,671
899,283 642,944 256,339
194,543 179.537 15,006
218.274 188,818 29,456
169,281 195,099 (25,818)
42,767 6,603 36,164
665 660 5
1,087,236 1,034,945 52,291
(796,681)(476,454)(320,227)
15,212,617 10,717,846 4,494,831
1,245,000 1,239,738 5.262
1,245,000 1,239,738 5,262
22,131,859 26,882,074 (4.750,215)
22,131,859 26,882,074 7,552,004
$60,734.567 $55,145,791 $7,552,004
2008 Final Pries! Rapids Proforma StafCPR_2b% ~Ä~ichment-A.pdf
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"UNOFFICIAL" PRIEST RAPIDS POWER COST FORECAST
($000)
2008 2009 2010 2011
o & M EXPENSES $37,358 $40,913 $40,711 $35,836
DEBT:
ISSUED DEBT-INTEREST 12,262 12,982 12,482 9,509
ISSUED DEBT-PRINCIPAL 9,870 11,041 11,512 11,088
FUTURE LEVEUZED DEBT 3,399 3,399 14,915
15% OF DS TO SUPP R&R 3.320 4,113 4,109 5,327
EXCESS FROM SUPP R&R (3.330)(3,320)(4,113)(4,109)
TOTAL PROPOSED DEBT 22,122 28,216 27,388 36,730
TOTAL TAXES 1,245 1,245 1,245 1,245
INTEREST INCOME 635 902 744 1,137
NET POWER COSTS $60,090 $69,471 $68,600 $72,674
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WANAPUM PROFORMA BUDGETED COST BY PROGRAM
FINAL 2008 PROFORMA vs. FINAL 2007 PROFORMA.2008 FINAL 2007 FINAL
PROGRAM PROGRAM DESCRIPTION PROFORMA PROFORMA VARIANCE
Generation Operations
P5020 Upsteam Migrants $457,533 $269,731 $187,802
P5031 Bldgs&Grounds-O&M-Hydro 215,598 180,147 35,452
P5050 Business System Development 1,539 4,279 (2,740)P5120 Ferc Hatchery Comp Requirements 580,635 429,400 151,234
P5130 Ferc Os Migrant Requirements 4,697,223 3,768,202 929,021
P5140 Ferc Minimum Flow Requirements 419,889 244,268 175,621
P5170 General Administrtion 37,761 35,104 2,657
P5320 Hydro Engineering Operations 334,062 162,918 171,144
P5350 Propert/Liability Claims Admi 5,000 5,000
P5390 Recreation & Tourist Facilities 288,778 263,301 25,477
P5450 Telecomunications 69,341 13,994 55,346
P5480 Training & Education 216,317 46,921 169,396
P7222 Wanapum Elecrical Maintenance 211,208 208,340 2,868
P7223 Wan Mechanical Maintenance 700,282 550,460 149,822
P7240 Wanapum Generation Operations 2,849,780 2,704,533 145,247
P9115 Fere Ucense-Pr Project 49,480 41,425 8,056
Generation Operations Total 11,134,425 8.928,023 2,206,402
Generaion Maintenance
P1610 Wildlife Issues 195,774 141,099 54,675
P5030 Bldgs&Properties 209,119 373,451 (164,332)
P5031 Bldgs&Grounds-O&M-Hydro 304,090 345,381 (41,291)
P5120 Ferc Hatchery Camp Requirements 3,783,311 740,185 3,043,126.P5130 Ferc Os Migrant Requirements 89,158 62,831 26,327
P5250 Load & Resource Planning 20,080 32,411 (12,331 )
P5271 Tools & Test Equipment-Hydro 45,441 31,826 13,615
P5320 Hydro Engineering Operations 1,569,743 974,717 595,026
P5390 Recreation & Tourist Facilities 668,456 639,952 28,505
P5420 Security & Fire Protecton 130,754
P5450 Telecommunications 30,784 50,149 (19,365)
P7221 Pr Mechanical Maintenance 17,285 16,059 1,226
P722 Wanapum Electrical Maintenance 881,076 862,756 18,320
P7223 Wan Mechanical Maintenance 2,150,858 1,743,546 407,311
P7224 MlC Electrcal Maintenance 58,122 45,331 12,791
P7225 MIC Mechanical Maintenance 179,914 160,111 19,803
P9115 Ferc License-Pr Project 65,673 (65,673)
Generation Maintenance Total 10,333,964 6,285,478 4,04,486
Transmission Operation
P5320 Hydro Engineenng Operations 1,477 1,314 163
P5340 Control & Accunting 313,348 241,144 72,205
P5530 Transmission Operations 733,520 524,374 209,146
P5910 Electronics System Maintenance 53.150 68,332 (15,181 )
P7240 Wanapum Generation Operations 179.794 (179,794)
P7241 Pr Generaion Operations 179,794 (179,794)
P8170 Work To Be Reimbursed (370,589)(353.041)(17,549)
Transmission Operation Total 730.907 841,711 (110,804)
Transmission Maintenance
P5521 Project Switchyard O&M 110.931 115,633 (4,702)
P5530 Transmission Operations 3,135 3,121 14
Transmission Maintenance Total 114,066 118,754 (4,688).
2008 Final Wanapum Proforma 5of9 11/28/2007
StafCPR_205 ~Attachment-B.pdf Page 6 of 10
.
.
.
WANAPUM PROFORMA BUDGETED COST BY PROGRAM
FINAL 2008 PROFORMA VS. FINAL 2007 PROFORMA
2008 FINAL 2007 FINAL
PROGRAM PROGRAM DESCRIPTION PROFORMA PROFORMA VARIACE
Administrative & General
P5030 Bldgs&Properties 249,363 18,388 230,976
P5050 Business System Development 281,811 159,418 122,392
P5060 Computer O&M (License Fees)1,351,106 1,143,693 207,413
P5120 Ferc Hatchery Comp Requirements 1,211.522 1.206,784 4,738
P5130 Farc Ds Migrant Requirements 334,466 360,043 (25,577)
P5152 Environmental Compliance 209,620 101,348 108,272
P5160 General Accounting & Reporting 385,632 352,197 33,434
P5170 General Administration 7,329,440 3,167,667 4,161,773
P5190 Strategic Planning 171,713 115,574 56,138
P5200 Safety And Medical 310,568 235,534 75,035
P5275 Offce Furniture & Equipment 38,655 36,107 2,54
P5310 Power Mgmt Contract Admin 24,513 18,530 5,983
P5320 Hydro Engineering Operations 1,455,566 1,666,481 (210,915)
P5340 Control & Accounting 2,524 6,079 (3,554)
P5350 Propert/Liability Claims Admi 899,868 856,801 43,066
P5370 Purchasing/Contrct. Admin 243,211 241,384 1,827
P5410 Regional Planning 277,432 340,973 (63,541)
P5450 Telecommunicaions 568,579 387,410 181,169
P5480 Training & Education 967,512 718.806 248,707
P5490 Treasury & Debt Administration 246,940 221.877 25,063
P591 0 Elecnics System Maintenance 232,162 199,514 32,647
P6116 Business Network 242,203 268,261 (26,057)
P6120 Fiber Backbone 61,176 9,079 52.097
P8170 Work To Be Reimbursed 935 907 28
P9115 Fere License-Pr Project 1,069,734 1,034,945 34,789
P9999 General Ledger (2,442,158)(1,996.974)(445,184)
Administrative & General Total 15,724,094 10,870,827 4,853,267
Taxes
P5160 General Accunting & Reporting 1,166,000 1,089,287 76,713
Taxes Total 1,166,000 1,089,287 76,713
Debt Service
P5490 Treasury & Debt Administration 32,418,655 35.963,189 (3,54,534)
Debt Service Total 32,418,655 35,963,189 7,552,004
Total Cost Per Detail $71,622,112 $64,097,269 $7,524,843
2008 Final Wanapum Proforma 60f9
Staff _PR_205 _Attchment-B. pdf
111281007
Page 7 of 10
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."UNOFFICIAL" WANAPUM POWER COST FORECAST
($000)
2008 2009 2010 2011
o & M EXPENSES $38,037 $42,311 $43,241 $40,933
DEBT:
ISSUED DEBT-INTEREST 21,099 20.587 20,046 19,472
ISSUED DEBT-PRINCIPAL 11,320 11,885 12,375 12,930
FUTURE LEVEUZED DEBT 14.158 14,158 29,751
15% OF DS TOSUPP R&C 4,863 6,995 6,987 9,323
EXCESS FROM SUPP R&C (4,875)(4,863)(6,995)(6,987)
TOTAL PROPOSED DEBT 32,406 48,762 46,572 64,489
TOTAL TAXES 1,166 1.166 1.166 1.166
INTEREST INCOME 4,686 9,289 3.783 7,921
NET POWER COSTS $66,924 $82,951 $87,196 $98,667
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2008 Final Wanapm Profmi 8of9
StafCPR _205 _Attachment-B.pdf
111281007
Page 90f10
,
.WANAPUM
CONSTRUCTION FUND
($000)
2008 2009 2010 2011
BEGINNING BALANCE $93,529 $37,496 $98,057 $(12)
RECEIPTS:
FINANCING PROCEEDS 150,700 166,000
INTEREST INCOME 3,832 8.373 2,868 6,937
TOTAL RECEIPTS 3.832 159,073 2.868 172.937
EXPENDITURES:
GENERATOR RESTORATION 2.756 31,893 27,149 27,603
TURBINES 26,868 27,255 23,614 29,449
POWERHOUSEISWITCHYARD 15,183 18,306 19,177 17,064
FISH AND WILDLIFE 4,368 5,271 9.357 12,185
FERC-L1CENSE 1,663
BUILDINGS/PROPERTIES 4,230 9,939 15,037 5,764
OTHER 964 3,475 3.734 2,736.TOTAL PER DETAIL 56,033 96.139 98.069 94,801
TRANSFER FROM R&C FUND (6,000)
PAID FROM THE CONST FUND 56.033 90,139 98.069 94,801
TRNSFER INT TO REV FUND (3,832)(8.373)(2,868)(6,937)
ENDING BALANCE $37,496 $98.057 $(12)$71,187
.
2008 Final Wanapum Proforma 90f9
StafCPR_205 _Attachment-B. pdf
111281007
Page 10 of 10
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
A VU-E-08-01 1 A VU-G-08-01
IPUC
Production Request
Staff-206
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
07/25/08
Wiliam Johnson
Wiliam Johnson
Power Supply
[phone]
The workpaper provided in support of the adjustment on line 10 of Exhibit No, 6, Schedule 2, p. 1
of 2, Small Power, (W. Johnson) (workpapers p. 17 of Wiliam Johnson), shows monthly
generation totals and estimated expenses for 2008-2010 for six PURA projects. Please provide
additional workpapers showing how the expenses for 2008-2010 were computed or estimated for
the Sheep Creek, Jim White, and Hydro Tech projects.
RESPONSE:
Electronic copies of worksheets showing how the expenses for 2008-2010 were computed or
estimated for the Sheep Creek ("StafCPR _ 206-Attachment A.xls"), Jim White
("StafCPR_206-Attachment B.xls"), and Hydro Tech ("Staff_PR_206-Attachment C.xls")
projects are being provided electronically as requested.
AVISTACORPORATION
RESPONSE TO REQUEST FOR INFORMTION
07/25/08
Wiliam Johnson
Wiliam Johnson
Power Supply
[phone]
.DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
IDAHO
AVU-E-08-01 1 AVU-G-08-01
IPUC
Production Request
Staff-207
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
In reference to the adjustment shown on line 12 of Exhibit No.6, Schedule 2, p. 1 of 2, (W.
Johnson), Spokane-Upriver Power Purchase, please explain why 2009 pro forma expenses are
greater than 2007 actual expenses, given that the power purchase payment rates shown on p. 21 of
Wiliam Johnson's workpapers are the same between July 1, 2004 through December 31, 2011. Is
the difference due to below normal flows in 200n
RESPONSE:
The reason for the difference in expense between the 2009 pro forma and 2007 is due to the
difference in the amount of power purchased. The proforma uses a five-year average power
purchase amount of 52,205 MWh, where as the power purchased in 2007 was 49,278 MW. The
average purchase rate was $38.82/M in 2007 and is $38.64/M in the pro forma. The
average rate wil var from year to year because the power purchase rate is seasonally adjusted so
. the monthly shape of the power purchase changes the average rate.
The Company purchases the net generation from Upriver, which is plant generation less the City of
Spokane's water pumping load at the Upriver plant. Therefore the change in net generation
purchased between years is a combination of change in generation and/or a change in pumping
load.
.
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
IDAHO
A VU-E-08-01 1 A VU-G-08-01
IPUC
Production Request
Staff-208
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
07/25/08
Wiliam Johnson
Wiliam Johnson
Power Supply
[phone]
Please provide an update on the status of the Thompson River cogen project. Did the project come
online as assumed on p. 36 of the workpapers of Wiliam Johnson? If not, please explain the
reasons for the delay and provide a revised estimate of when the project is expected to become
operationaL. Include any support for a revised estimate of an operation date. Please explain the
basis for the monthly generation estimates included on the aforementioned workpaper.
RESPONSE:
Thompson River Cogen has given no formal notifications to A vista of its intent to star its
cogeneration facility. Based upon informal discussions and news reports, Avista anticipates that
the facility could star deliveries durng the fourh quarer of2008. Therefore, the generation was
included in the 2009 pro forma.
The basis for the monthly generation estimates included in the pro forma is based on informal
information provided by Thompson River.
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
A VU-E-08-01 1 A VU-G..08-01
IPUC
Production Request
Staff-210
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
07/25/08
Wiliam Johnson
Willam Johnson
Power Supply
[phone]
Please provide documentation and support for the adjustment shown on line 50 of Exhibit No.6,
Schedule 2, p. 2 of2, (W. Johnson), Sand Dunes - Warden. Exhibit No.6, Schedule 2, p. 50f8,
(W. Johnson), states that the contract ended Oct. 2007, yet the amount of the 2007 actual expense
has been included as a 2009 pro forma expense. Please reconcile ths inconsistency.
RESPONSE:
Line 50 of Exhibit No.6, Schedule 2, p. 2 of2, (W. Johnson), Sand Dunes - Warden, which states
that the contract ended Oct. 2007, is in error.
The Sand Dunes - Warden transmission expense is a continuing anual expense. The Grant
transmission expense did end October 2007. The pro forma amount is correct. The expense
description on Line 50 of Exhibit No.6, Schedule 2, p. 2 of 2, is wrong.
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
IDAHO
A VU-E-08-01 1 A VU-G-08-01
IPUC
Production Request
Staff-211
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
07/25/08
Wiliam Johnson
Wiliam Johnson
Power Supply
[phone]
Please provide documentation and support for the adjustment shown on line 51 of Exhibit No.6,
Schedule 2, p. 2 of 2, (W. Johnson), Black Creek Wheeling. Workpapers show actual 2007
revenue and 2009 normalized revenue, but do not explain the adjustment in sufficient detail or
provide support for it.
RESPONSE:
The Black Creek transmission and ancilary servces rate is $6.001M. In 2007, the wheeling
expense was based on 2,959 MW for a wheeling charge of $17,754. The pro forma uses a
five-year average for Black Creek of 3,720 MW, for a pro forma wheeling expense of $22,320.
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
IDAHO
A VU-E-08-01 1 A VU-G-08-01
IPUC
Production Request
Staff-212
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
07/25/08
Wiliam Johnson
Wiliam Johnson
Power Supply
[phone]
Please provide an update on the status of the transmission agreement between A vista and Kootenai
Electrc for service to Worley. The adjustment is shown on line 56 of Exhibit No.6, Schedule 2, p.
2 of 2, (W. Johnson). If a new transmission agreement has been signed, please provide
documentation of the cost to A vista. If no new agreement has yet been signed, please provide an
updated estimate of the cost and cite the source of the estimate.
RESPONSE:
Avista and Kootenai have a new transmission agreement effective April 1, 2008. The anual
wheeling cost is $45,222.
An electronic copy of the new agreement is provided as "StafCPR_212_Attachment-Apdf'.
.
.
.
USE OF FACILITIES AGREEMENT
BETWEEN
KOOTENAI ELECTRlC COOPERATIVE, INC.
AND
THE A VISTA CORP 0 R.A nON
This Use of Facilities Agreement (Agreement), dated as of the latest execution by both
parties, is by and benveen Kootenai Electric Cooperative, Inc. (Kootenai): a nonprofit
corporation orgai"lzed under the laws of the state of Idaho, and Avista Corporation
(A vista), a corporation organized under the la\',15 of the State of Washigton,
RECITALS
WHEREAS, Avista Ow11S and operates facilities within the City of Worley, Idaho,
(Worley), and
\Vh'EREAS, Kootenai ovins and operates facilities in the vicinity of
Worley, and;
Vv1-EREAS, the electric faciliies of Kootenai and Avista are interconnected at
Kootenai's Setters 115kV Transmission Tap (Setters Tap) as provided in the
Interconnection and Operating Agreement (Avista Contract No. AV-TR05-0205) as may
be amended, and;
WHEREAS, the electrc facilities of Kootenai and A vista are interconnected at
Kootenai's 12.47kV distribution pole locatIon 12468 (Worley point of intercofiiiection),
and;
NOW, THEREFORE, Kootenai and Avista agree as follows:
1. Definitions: \Vhen used in ths Agreement, the follov1lÌng terms have the
meaning sho\ovii below:
a. Bonnevile means the Bop.nevile Power Administration.
b. Setters TaQ means Kootenai's 3 pole 1 15kV steel sL.-ucture located
adj acent to A vista's Rockrord dIstribution substation,
c. Worley point of interconnection means the Kootenai distribution
pole number 12468 where Kootenai and Avista interconnect at
12.47kV.
StafCPR_212_Attachment-A.pdf Page 1 of 8
d.\\1iolesale Po\ver Bill meaiîS the monthly power bil received from
the Bori..evile Power Administration..
e. Losses meai-is the energy lost during the transfer of energy from
Setters Tap to the Worley point of interconnection.
f Energv loss factors means the values agreed upon betvJeen
Kootenai, Avista and Bonneville Power Administration that adjust
the \v1iolesale Power Bil to reflect losses incurred during the
delivery of energy under this Agreement. The energy Joss factors
are sho'.vn on the W1101esale Power BilL.
g. Prudent Utility Practice means the practices, methods and acts
engaged in or approved by a significant portion of the electric
utility industry during the relevant time period, or the practices,
methods and acts which, in the exercise of reasonable judgment in
light of the tàcts kno"\\'TI at the time the decision was made, could
have been expected to accomplish the desired result at a reasonable
cost consistent with good business practice, reliability, safety and
expedition. Prudent Utility Practice is not intended to be limited to
the optimum practice,. method or act to the exdusion of all others,
but rather to be a range of acceptable practices, methods or acts..2.Term of Agreement. This Agreement \\riU be effective commencing at
0000 hours on April 1, 2008, and shall remain in effect until the earlier of:
a. 2400 hours on December 31, 2018; or
b. Termination of this Agreement as provided in Section 9.
3. Sentices to be Prov'ided. Kootenai agrees to rece.iv~e fro-m A vista at Setters
Tap capacity and energy which Avista wishes to have delivered to its
Worley electric distribution system. Kootenai wil exchange capacity and
energy received from Avista at Setters Tap for like amounts of capacity
and energy at the W orIe)' point of interconnection.
4. Losses. Avista shall replace energy losses which result from delivery by
Kootenai of energy to the Worley point of interconnection. Bonnevile
Power Administration shall adjust the \\'bolesale Power Bil to account for
the losses. These loss factors may be changed at any time upon receipt of
three (3) months' notice from Kootenai to Avista and BOll'1evile.
5.Metering Facilities & Meter Reading. Avista will be responsible for
providing and maintaining, at its 0\VI expense, metering facilities at the
Worley point of interconnection. Such metering facilities shall read
directly the power and energy aiîd reactive kilovolt-amperes delivered to.
:.
StafCPR_212_Attachment-A.pdf Page 2 of8
.
.
.
A vista at L1ie Worley point of interconnection. All meters shaH be subject
to inspection and testing in accordance vvith A vista's meter testing
program. AvIsta shall supply Bonnevile \Vi'li all load data necessary to
reduce Kootenai's \Vholesale Power BiI1 for power deliveries plus losses
to the Worley point of interconnection.
rO.Liabilitv. Kootenai shall not be liable to A vista for failure to deliver
electrcity as called for herein if such failure is due to fire, earhquake,
flood, strikers, labor disputes, war, civil commotion or other causes
beyond the control of Kootenai, Kootenai agrees to employ prudent utilty
practices to protect Avista from faults or failures in Kootenai's electrical
facilities. Avista agrees that it \vil make no claI.í1agaist Kootenai for
any loss or damage whatsoever resulting from faults on or failures in
Kootenai's electrical facilities. Avista fù.rtber agrees to save and hold
Kootenai haimless a.nd to defend Kootenai from and .against any damage
claims made by Avista's customers resulting from faults or failures in
Kootenai's or Avista's facilities which are related to providing service to
Worley. In the event of the failure of Kootenai's electrical facilties,
Kootenai shan restore such facilties as soon as is reasonably possible.
7.Payment. Avista shall pay Kootenai, on a monthly basis, one t\velfth of
L1ie amount shovl'. in Exhibit A for providing \vheelìl1g services under the
Agreement. Payment by A vista shall be due within twenty (20) days
follO\ving receipt of an invoice from Kootenai. A vista shall pay Kootenai
interest at the rate of 1,5% monthly on any late payment.
8. Reactive Power. The paries hereto shall jointly plan and operate their
system in accordance with prudent utilty practices so tht the voltage
level and flow of reactive power resulting from or accompanying
deliveries of electric power and energy hereunder wil not adversely affect
the system of either party,
9. Termination of Agreement & Charges.
(a) \\limout Cause. This Agreement may be terminated by either party
upon giving two (2) years' notice of such intent to the other pary. or as
oilenvise a.greed,
(b) \Vith Cause. Subject to Section 13 of this Agreement, in the event
a party is in material breach of the tenus of this Agreement~ the other pary
may tenuinate this Agreement provided that it first give wrtten notice to
the other party of such breach, and provided furher that Üie pary in
breach does not cure its default v-ithin ninety (90) days of the date of
receiving such notice. In the event this Agreement Is terminated for cause,
the party in defauìt shall be responsible for the damages sustained by the
other party.
3
StafCPR_212Y.ttachment-A.pdf Page 3 of 8
.10.Adiustment to CharlZes. Kootenai mayadjust the charges contained in
Exhibit A effective April 1 of each year, upon giving 90 days prior notice.
11. Installation of Additional Facilities. The parties shall exchange any
necessai-v data and confer from time to tL.'1e to determine the necessity for. -
removal of existing facilities and for the instaUation of additional facilities
to enable the paries to fulfill their obligations liereurider. Kootenai agrees
to provide addition a! facil.ities at Kootenai's expense which are required to
meet the combined load groVv1. of both paries hereto in the vicinity of
Worley, provided that Avista's load at Worley does not exceed 1500 kW.
To the extent Avista's load does exceed 1500 kW, then Avista shall pay to
Kootenai an amount ba.c:ed on the costs incurred by Kootenai to construct
such additional facilities. The amount of payment bv A vista to Kootenai. ., -
shall be as mutually agreed by the paries hereto. in the event the paries
Can.liot agree, the a.mount of payment shall be determned as provided in
Section 15,
12,
.
.
Limitation of Ri£hts. Except to the extent set fort hereinabove, this
i\greement shall not be construed 10 grant either pary any rights 10
coiistnict, improve, adjust, control or tamper \vith the facilities of the other
pary, unless such permission is expressly given in writing and executed
by an auth.orized agent of the pary giving such right. Neither pary shall
a.')sign their interest in this Agreement, nor any par hereof, nor any duty or
obligation created herein, without the expressedVltten consent of the
other pary.
13. Attorney's Fees on Breach. In the event either party commences litigation
alleging a breach of the provisions ofthIs Agreement, the prevailing pary
in such litigation shall be entitled to its costs of such suit, including a
reasonable attorney's fee.
14, No Third Pary Beneficiarv. This Agreement is solely betv.,ieen Kootenai
and A vista and such paries do not intend to benefit any third pares by
entering into ths Agreement. No person or entity not a pary to this
Agreement may claim any rights or benefits hereunder, and the parties to
this Agreement shall have no liabilty to such person or entity,
15. Agreement to Arbitrate, AIl disputes and controversies of every kind and
nature between the parties hereto shall be submitted to arbitration in
accorda.lce with the procedure contained in Exhibit B.
16,Execution in Counterpar. This Agreement may be executed in any
number of counterpars in which case all such counterpart shall be
deemed to constitute a single document with the same force and effect as
4
Staff_PR _212_ Attachment-A.pdf Page 4 of 8
.if all paries hereto having signed a counterpar had signed all other
counterparts. The Agreement shal1 become effective on the date of
execution by both paries.
i ..1 I .Modification. This Agreement may only be modified by a v.TIting signed
by both parties. Adjustments of energy loss factors described in Section 4
or charges contained in Section 7 and Exhibit A by Kootenai shall not
constitute a modification of the Agreement.
18.Choice of Law. Ths Agreement shall be interpreted and governed by the
Iaws of the state ofIdabo.
19.Menzer. l11cre are no terms, agreements, or representations benveen the
parties concerning the subject matter of this Agreement except those
contained herein. All prior negotiations, agreements, and representations
are i:riergcd into this Agreement.
.
IN \VITNESS w'HEREOF, the Darties hereto have executed this Aílreement.. . ~
Signed this ?/Æ day of k~~
ATTEST:
,20d3 THE A \jl TA CORPOßATION
I JJ¿ JflBy: " è'! .gJ£ .
Title: (/¿ b-t&'rf-t Re..ev((èSI
)V ~~. t.-f_r-ß¡¡:d 6z~~u4dø.zi / /
Signed thiSP~ of t1~2¿ KOOTENAI?v \ATTEST: B.'
Tit~ .: ¿g~" ...../.. ~*__ ~¿j;1\~~/U.h.
5
StafCPR_212_ Attachment-A.pdf Page 50f8
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EXHIBIT B - ARBITRATION PROCED1.JRE
A.All disputes fuJd controversies of every kind fu'ld nature between the pfu"ties hereto
shall be submitted to arbitration pursint to the following procedure:
i. Either party may demand such arbitration with thi (30) days after Ltie
controversy a.rises, which demaì1d shall include the name of the arbitrator
appointed by the pary demanding arbitration, together ìvith a statement of
the matter in controversy.
2. Within thirty (30) days after such demand, the other pll"ty shall nan1e its
arbitrator, or in default L.tiereof. such arbitrator shall be named by the pary
demanding arbitration and the two (2) arbitrators so selected shall name a
L.llrd (3rd) with.in thirty (30) days or, in lieu of such agreement on a third
(3rd) arbitrator by the wo (2) arbitrators so appointed, a third (3rd)
arbitrator shall be appoi.rited by the Arbitration Committee of the
Americfui Arbitration Association.
3, Each party shall bear its own arbitration costs and expenses and 1he costs
of the arbitrator appointed for said par. The cost of the third (3rd)
arbitrator shaH be shared equally between the paries.
4.The arbitration hearg shall be held in Coeur d' Alene. IdaJio. after at least.. ~ ,
sixty (60) days' notice to the parties. TIie arbitration rules and procedures
of the American Arbitration Association are incorporated by reference
herein and shan govern the hearing. The law of evidence of the State of
Idaho shall govern the presentation of evidence tlierein.
5. The arbitration hearing shall be conduded within twenty (20) days of the
commencement, unless otheni¡'Ìse ordered by the arbitrators, and 1he award
thereon shall be made withn 1hirty (30) days afer the close of the
submission of evidence. An Award rendered by a majority of the
arbitrators appointed pursuant to 1his Agreement shall be final and binding
on a1l pai-ües to the proceeding durng 1he period of this Agreement âi'ld
judgment on such award may be entered by either pary in the highest
cour, state or federal, having jurisdiction.
B. The paries stipulate that the provisions hereof shall be a complete defense to any
suit, action or proceeding instituted in any federal, state or local court or before
any administrative tribunal \vith respect to any controversy or dispute arsing
during the period of this Agreement and which is arbitrable as hereÌn set forth in
this Exhibit B. The arbitration provisions hereof shall, with respect to such
controversy or dispute, survive the termination or expiratÍon of this Agreement.
8tafCPR _212_ Attachment-A.pdf Page 7 of 8
.
.
.
c,Nothing herein contained shall be deemed to give the arbitrators aii)' authority,
power or rü.dlt to alter, chairge, aDend. add to or subtract from any of the.. ..- -. - " ~ .,
provisions of this Agreement.
2
StafCPR _212.-ttachment-A.pdf Page 8 of 8
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
IDAHO
AVU-E-08-01 1 A VU-G-08-01
IPUC
Production Request
Staff-215
DATE PREPARD:
WITESS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
07/25/08
Wiliam Johnson
Wiliam Johnson
Power Supply
[phone]
Please provide documentation and support for the adjustment shown on line 67 of Exhibit No.6,
Schedule 2, p. 2 of2, (W. Johnson), Sovereignaiser. Workpapers show actual 2007 revenue and
2009 normalized revenue, but do not explain the adjustment in suffcient detail or provide support
for it. Explain whether any adjustment is due to deviation energy.
RESPONSE:
In 2007 Kaiser DES revenue was $535,544. Of that total, $75,542 was the capacity charge and
$460,002 was for the sale of deviation energy. The pro forma only includes the capacity charge
revenue since deviation energy amounts are unown and not included as an obligation in the
AURORA modeL. Also, deviation energy is sold at the market price (index price) so any revenue
from the sale of deviation energy is offset by the expense to provide the energy.
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
IDAHO
A VU-E-08-01 / A VU-G-08-01
IPUC
Production Request
Staff-216
DATE PREPARD:
WITNESS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
07/25/08
Wiliam Johnson
Wiliam Johnson
Power Supply
[phone]
Please provide documentation and support for the adjustment shown on line 68 of Exhibit No.6,
Schedule 2, p. 2 of2, (W. Johnson), Pend Oreile DES & Spinning Reserves. Workpapers show
actual 2007 revenue and 2009 normalized revenue, but do not explain the adjustment in sufficient
detail or provide support for it. Explain whether any adjustment is due to deviation energy.
RESPONSE:
In 2007 Pend Oreile DES & Spinning Reserves revenue was $708,674. Of that total, $363,779
was the capacity charge and $344,895 was for the sale of deviation energy.
The pro forma only includes the capacity charge revenue since deviation energy amounts are
unkown and not included as an obligation in the AURORA modeL. Also, deviation energy is sold
at the market price (index price) so any revenue from the sale of deviation energy is offset by the
expense to provide the energy.
.
.
.
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
DATE PREPARD:
WITESS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
07/25/08
Wiliam Johnson
Wiliam Johnson
Power Supply
[phone]
IDAHO
A VU-E-08-01 1 A VU-G-08-01
IPUC
Production Request
Staff-217
REQUEST:
Please provide documentation and support for the adjustment shown on line 69 of Exhibit No.6,
Schedule 2, p. 2 of2, (W. Johnson), Northwester Load Following. Workpapers show actual 2007
revenue and 2009 normalized revenue, but do not explain the adjustment in suffcient detail or
provide support for it. Explain whether any adjustment is due to deviation energy. Why is the
2009 pro forma revenue lower in the months of May, June, and July?
RESPONSE:
In 2007 Northwestern Load Following revenue was $3,138,271. Of that total $1,727,495 was the
capacity charge and $1,410,776 was for the sale of deviation energy.
The pro forma only includes the capacity charge revenue since deviation energy amounts are
unkown and not included as an obligation in the AURORA modeL. Also, deviation energy is sold
at the market price (index price) so any revenue from the sale of deviation energy is offset by the
expense to provide the energy.
The 2009 pro forma revenue is lower in the months of May, June, and July because the amount of
dynamic capacity sold to Nortwestern is lower from May 1 through July 15, durng the ruoff
period when A vista has less load following capability.
.
.
.
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
A VU-E-08-01 1 A VU-G-08-01
IPUC
Production Request
Staff-219
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
07/25/08
Wiliam Johnson
Wiliam Johnson
Power Supply
[phone]
REQUEST:
On page 5, lines 13-15 of the direct testimony of Wiliam Johnson, he discusses the increase in
transmission expenses and states "This is primarly due to the purchase of an additional 125 MW
ofBP A point-to-point transmission for Coyote Springs 2." On page 13 of his testimony, however,
he states "To meet the transmission requirements of CS2 the Company purchased an additional 50
MW of firm PTP transmission from BP A, for a total of 272 MW of firm transmission for CS2."
Please reconcile this apparent discrepancy.
RESPONSE:
The Company originally purchased 147 MW of BPA point-to-point transmission for Coyote
Springs 2. Effective July 1, 2006 the Company purchased an additional 75 MW of BPA
point-to-point transmission for Coyote Springs 2. Effective August 1, 2007 the Company
purchased an additional 50 MW ofBP A point-to-point transmission for Coyote Springs 2.
Curent base rates used a power supply pro forma period of September 2004 through August 2005.
Since that period, the Company has purchased 125 MW of additional BP A point-to-point
transmission for Coyote Springs 2 (75 MW July 1, 2006 and 50 MW August 1,2007).
Since the 2007 test year, the Company has purchased 50 MW of additional BPA point-to-point
transmission for Coyote Springs 2 for a full year versus five months in the test year.