20210129Kalich Exhibit 9 Schedule 1-5.pdf

DAVID J. MEYER
VICE PRESIDENT AND CHIEF COUNSEL FOR
REGULATORY & GOVERNMENTAL AFFAIRS
AVISTA CORPORATION
P.O. BOX 3727
1411 EAST MISSION AVENUE
SPOKANE, WASHINGTON 99220-3727
TELEPHONE: [phone]
FACSIMILE: [phone]
[e-mail]

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION

IN THE MATTER OF THE APPLICATION ) CASE NO. AVU-E-21-01
OF AVISTA CORPORATION FOR THE )
AUTHORITY TO INCREASE ITS RATES )
AND CHARGES FOR ELECTRIC AND )
NATURAL GAS SERVICE TO ELECTRIC ) EXHIBIT NO. 9
AND NATURAL GAS CUSTOMERS IN THE ) OF
STATE OF IDAHO ) CLINT G. KALICH

FOR AVISTA CORPORATION

(ELECTRIC)

Entire Document is CONFIDENTIAL
Dispatch Model Results
Pages 1 through 4
Exhibit No. 9 Case Nos. AVU-E-21-01 C. Kalich, Avista
Schedule 1(R), Page 1 of 1
Line 9/1/21-8/31/22No.2019 Adjustment Pro Forma1 555 PURCHASED POWER2 Short-Term Market 40,814 -37,613 3,2013 Chelan PUD 15,277 -597 14,6804 Douglas PUD 2,629 986 3,6155 Grant PUD 9,438 1,835 11,2736 Lancaster PPA 28,141 327 28,4677 WNP-3 7,911 -7,911 08 Small Powe 1,387 15 1,4029 Stimson 1,941 -510 1,43110 Spokane-Uprive 2,142 429 2,57111 Spokane Waste-to-Energy 5,575 93 5,66812 Palouse Wind 18,596 1,826 20,42213 Adams-Neilson Solar (Solar Select) 1,647 -1,647 014 Rattlesnake Flats Wind 0 14,115 14,11515Total Account 555 - PC 135,497 -28,652 106,84516 Clearwater Paper - reconciling items (not in ERM/PCA) 8,728 -8,728 017 WA WNP3 - reconciling items (not in ERM/PCA) 88 -88 018Total Account 555 144,313 -37,468 106,8451920 557 OTHER EXPENSES21 Miscellaneous Transaction Fees 570 62 63222 WA EIA REC Sales - 557.171 (REC Journal) 48 -48 023 Other Resource Costs 1,455 -1,455 024 Natural Gas Fuel Purchases 47,651 -47,651 025Total Account 557 49,723 -49,092 6322627 501 THERMAL FUEL EXPENSE28 Kettle Falls - Wood Fuel 6,232 210 6,44229 Colstrip - Fuel Cost 22,648 2,965 25,61430Total Account 501 28,881 3,175 32,0563132 547 OTHER FUEL EXPENSE33 Coyote Springs 2 Combined Cycle Combustion Turbine 27,374 10,094 37,46834 Lancaster Combined Cycle Combustion Turbine 27,247 2,007 29,25435 TC Energy Pipeline 10,433 -972 9,46136 Williams Northwest Pipeline 174 29 20337 Rathdrum Combustion Turbine 4,410 2,883 7,29238 Northeast Combustion Turbine 71 -71 039 Boulder Park Engines 1,342 865 2,20740 Kettle Falls Combustion Turbine 451 -228 22341Total Account 547 71,501 14,608 86,1094243 565 TRANSMISSION OF ELECTRICITY BY OTHERS 44 WNP-3 472 -472 045 Short-term Purchases 347 -347 046 BPA Point-to-Point for Colstrip, Coyote Springs 2 & Lancaste 12,322 2,028 14,35047 BPA Townsend to Garrison 1,500 8 1,50848 Avista on BPA Borderline 1,466 -76 1,39049 Kootenai for Worley 48 0 4850 Sagle for Northern Lights 139 -6 13451 Northwestern for Colstrip 317 0 31752 Portland General Electric John Day to COB 643 0 64353Total Account 565 17,253 1,136 18,3895455 537 MT Invasive Species56Total Montana Invasive Species 1,582 28 1,6105758TOTAL EXPENSE 304,437 -58,797 245,640
Avista Corp.
Power Supply Pro forma - Idaho Jurisdiction
System Numbers - 2019 Actual and Sep 2021 - Aug 2022 Pro Forma
Test Year Load
($000)
Exhibit No. 9
Case No. AVU-E-20-01
C. Kalich, Avista
Schedule 2, Page 1 of 2
Line 9/1/21-8/31/22No.2019 Adjustment Pro Forma
Avista Corp.
Power Supply Pro forma - Idaho Jurisdiction
System Numbers - 2019 Actual and Sep 2021 - Aug 2022 Pro Forma
Test Year Load
($000)
5960 447 SALES FOR RESALE61 Short-Term Market 61,301 18,954 80,25562 Nichols Pumping 1,724 -584 1,14063 Sovereign/Kaiser Services 149 0 14964 Direct Energy CEC-1 Index (formerly Energy Amercia) 7,077 -7,077 065 Morgan Stanley index sale 9,305 -9,305 066 Douglas PUD 0 0 067 Pend Oreille PUD 665 -660 568 CAISO Market Sales 0 2,265 2,26569 Solar Select 1,176 -1,176 070Total Account 447 81,398 2,417 83,8157172 456 OTHER ELECTRIC REVENUE 73 456.030 Clearwater Transmission - Idaho only -103 103 074456.380 Clearwater REC - Idaho only 247 -247 075 Non-WA EIA REC 1,749 -1,749 076 Natural Gas Liquids 357 66 42377 Surplus AECO to Malin Transportation 53,356 -48,339 5,01778Total Account 456 55,607 -50,167 5,4407980TOTAL REVENUE 137,005 -47,750 89,2558182TOTAL NET EXPENSE 167,432 -11,047 156,385
Exhibit No. 9
Case No. AVU-E-20-01
C. Kalich, Avista
Schedule 2, Page 2 of 2
Brief Description of CGK-2 Power Supply Adjustment Workpaper
1 N/
2
Short-Term Market. Term financial and physical contracts, plus hour
spot transactions. Spot market in proforma are results of Aurora
model. Term deals 08282020.xlsx
3 Chelan PUD. Rocky Reach and Rock Island contract expense.
Expires 12/31/2040. Aurora-generated - see CGK-1/CGK-2
4 Douglas PUD. Wells Purchase contract expense. Expires
12/31/2040. Aurora-generated - see CGK-1/CGK-2
5 Grant PUD. Priest Rapids and Wanapum contract expense. Expires
12/31/2040. Aurora-generated - see CGK-1/CGK-2
6 Lancaster PPA. Includes Contract costs of capital and operations and maintenance (O&M) and heat rate tracker. Variable O&M based
on the generation level determined by Aurora model.
Lancaster PPA - workpaper.xlsx (for
PPA energy, capacity & O&M) 2019 Lancaster Invoice Breakdown.xlsx (for
heat rate tracker)
7 WNP-3. BPA contract expired 4/30/2019. Not included in rate period proforma
8
Small Power - Summation of small PURPA power contracts; Pro forma costs are based on 5-year average generation levels and
actual proforma period contract rates. Small Power 2020.xlsx
9
Stimson. PURPA purchase from cogeneration plant at Plummer,
Idaho; based on 5-year average generation levels and priced using actual contract rates. Stimson Lumber 2020.xlsx
10
Spokane Upriver. PURPA purchase from City of Spokane; based on 5-year average of local pumping and generation levels and priced
using actual contract rates. Upriver Gen and Load 2020.xlsx
11
Spokane Waste to Energy. PURPA purchase from City of Spokane;
based on 5-year average of generation levels and priced using actual contract rates. Spokane_Waste_to_Energy 2020.xlsx
12
Palouse Wind. PPA price in proforma year multiplied by generation.
Monthly generation equals the 5-yr average adjusted for curtailment.
The hourly shaping methodology uses the 5-yr median energy profile.
See workpaper Palouse Wind 2020.xlsx. Palouse Wind 2020.xlsx
13
Adams-Neilson Solar (Solar Select). Contract purchase based on
output estimated by facility, as project has been in existence only since 2018; priced using actual contract rates. Represents the net purchase/sale deal
14
Rattlesnake Wind. Contract purchase based on output estimated by facility, as project entered commercial service in late 2020; priced
using actual contract rates. Rattlesnake Flats 2020.xlsx
15 Total Account 555 Summarization of lines 2-14.
16 Clearwater Paper - reconciling items (not in ERM/PCA)
17 WA WNP3 - reconciling items (not in ERM/PCA)
18 Total Account 555 - with reconciling items
19 N/
20 N/
21
Miscellaneous Transaction Fees . Expense is the 5-year average of
transaction fees for CAISO, broker fees and Canadian Merchandise Processing Fees assessed by the U.S. Government on imported
Canadian gas. Transactions Fees.xlsx
22 WA EIA REC Sales - 557.171 (REC journal)
23
Other Resource Cost. Actual one-time load curtailment payment to avoid shedding market purchases and/or load shedding during a
2019 sysetm reliability event; set to zero in proforma.
Not included in rate period proforma.
Not a recurring expense.
24
Natural . -
part of risk management/hedging policy, but then later re-sold (see line 67, Surplus AECO to Malin Transportation) due to changing
market conditions (i.e., plant later becomes uneconomic relative to purchasing electricity from the market). Proforma expense is zero
because we do not emulate our hedging program in proforma modeling.Reclassification - please see acccounts 501/547
25 Total Account 557 Summarization of lines 18-22.
26 N/
27 N/
28
Kettle Falls Generation Station. Combined wood fuel and natural gas
expense. Wood fuel expense is based on Aurora model generation
multiplied by the latest budget fuel price. Natural gas used for starting the plant is based on 5-year average.
Fuel Costs' sheet of this exhibit, Kettle
and Colstrip Fuel 2015 through 2019.xlsx
29
Colstrip. Combined coal and fuel oil expense. Coal expense is based on fixed and variable costs under a long-term contract. The
variable portion of coal fuel costs is based on generation levels from the Aurora model. Fuel oil used for starting the plant is based on 5-
year average.
Fuel Costs' sheet of this exhibit, Kettle and Colstrip Fuel 2015 through
2019.xlsx
Line
No.
Avista Corp.
Exhibit No. 9
Case No. AVU-E-20-01
C. Kalich, AvistaSchedule 3, Page 1 of 3
Brief Description of CGK-2 Power Supply Adjustment Workpaper
Line
No.
Avista Corp.
30 Total Account 501. Summarization of lines 24-25.
31 N/
32 N/
33
Coyote Springs 2 Combined Cycle Combustion Turbine. Natural gas cost based on Aurora model dispatch priced first at its location, but
then reduced to AECO basin prices where long-term contract transportation rights exist. See testimony and workpapers for more
detail on this calculation. 'Fuel Costs' sheet of this exhibit
34
Lancaster Combined Cycle Combustion Turbine. Natural gas cost
based on Aurora model dispatch priced first at its location, but then reduced to AECO basin prices where long-term contract
transportation rights exist. See testimony and workpapers for more detail on this calculation. 'Fuel Costs' sheet of this exhibit
35
TC Energy Pipleline. Costs related to firm natural gas pipeline
capacity on TC Energy pipeline between AECO and Kingsgate.
Used for our Lancaster and Coyote Springs 2 plants. Variable
charges are billed at tariffed rates based on the generation level
determined by Aurora model.
Natural Gas Transporation
Contracts.xlsx
36
Williams Northwest Pipeline. Costs related to use of the Williams
Northwest pipeline. Used for our Boulder Park, Northeast, and Kettle Falls CT plants. Charges are billed at tariffed rates based on the
generation level determined by Aurora model.
Natural Gas Transporation Contracts.xlsx
37
Ra rum om us on ur ne. a ura gas cos ase on urora
model dispatch priced first at its location, but then reduced to AECO
basin prices where long-term contract transportation rights exist.
See testimony and workpapers for more detail on this calculation. 'Fuel Costs' sheet of this exhibit
38
Northeast Combustion Turbine. Natural gas cost based on Aurora
model dispatch priced first at its location, but then reduced to AECO basin prices where long-term contract transportation rights exist.
See testimony and workpapers for more detail on this calculation. 'Fuel Costs' sheet of this exhibit
39
Boulder Park Engines. Natural gas cost based on Aurora model dispatch priced first at its location, but then reduced to AECO basin
prices where long-term contract transportation rights exist. See testimony and workpapers for more detail on this calculation. 'Fuel Costs' sheet of this exhibit
40
Kettle Falls Combustion Turbine. Natural gas cost based on Aurora
model dispatch priced first at its location, but then reduced to AECO basin prices where long-term contract transportation rights exist.
See testimony and workpapers for more detail on this calculation. 'Fuel Costs' sheet of this exhibit
41 Total Account 547 Summarization of lines 29-36.
42 N/
43 N/
44 WNP-3. Contract expired June 30, 2019. Not included in rate period proforma.
45
Short-Term Purchases. Set to zero in proforma reflecting additional
50 MW long-term Point-to-Point contract purchase from BPA for Coyote Springs 2 accounted for in line 48. Not included in rate period proforma
46
BPA Point-to-Point for Colstrip, Coyote Springs 2, and Lancaster. Proforma expense is based on contracted capacity at tariffed rate.
Includes additional 50 MW contract for Coyote Springs 2.
Transmission Expense - Account
565.xlsx
47 BPA Townsend to Garrison. Fixed fee contract with BPA for
transmission of Colstrip power from Townsend to Garrison.
Transmission Expense - Account
565.xlsx
48 Avista on BPA Borderlines. Purchase for serving Avista load in 3rd-
party service area. 5-year average of actual expense. BPA Borderline.xlsx
49
Kootenai for Worley. Purchase for serving Avista load in 3rd-party
service area. Proforma expense is based on contracted capacity at tariffed rate. Transmission Expense - Account 565.xlsx
50
Sagle for Northern Lights. Purchase for serving Avista load in 3rd-party service area. Proforma expense is based on contracted
capacity at tariffed rate.
Transmission Expense - Account
565.xlsx
51
Northwestern for Colstrip. Purchase on Northwestern for Colstrip
generation above 196-MW BPA Townsend to Garrison contract. 2019 test year expense used instead of 5-year average due to lower
cost of serving Nichols Pumping contract after closure of Colstrip Units 1/2. Transmission Expense - Account 565.xlsx
52
Portland General Electric John Day to COB. Purchase of Southern Interntie rights from John Day substation to California-Oregon border.
Proforma expense priced at proforma year tariffed rate.
Transmission Expense - Account
565.xlsx
53 Total Account 565. Summarization of lines 41-48.
54 N/
55 N/
56 Total Account 537 - Montana Invasive Species.Exhibit No. 9
Case No. AVU-E-20-01
C. Kalich, AvistaSchedule 3, Page 2 of 3
Brief Description of CGK-2 Power Supply Adjustment Workpaper
Line
No.
Avista Corp.
57 N/
58 Total Expense - Sum of Accounts 555, 557, 501, 547, 565 and 537.
59 N/
60 N/
61
Short-Term Market. Term financial and physical contracts, plus hourly spot transactions. Spot market in proforma are results of
Aurora model. Aurora-generated - see CGK-1/CGK-2
62 Nichols Pumping. Sale of energy for water pumping loads of Colstrip Units 3 and 4; contract price is Mid-C index less $0.50/MWh. Lower
revenue due to reduction in pumping load with closure of Units 1&2. Aurora-generated - see CGK-1/CGK-2
63 Sovereign/Kaiser Services. Sale of balancing area services to
Kaiser’s Trentwood plant. Based on test year actuals. N/A
64 Energy America. Contract expired 12/31/2019. Not included in rate period proforma
65 Morgan Stanley. Index contract with no net power supply expense.
Refer to testimony for additional detail. Not included in rate period proforma
66
Douglas PUD. Contract has no direct power supply impact.
Reflected in beneficial impact on shape of portfolio hydro operations in Aurora model. Not included in rate period proforma
67 Pend Oreille PUD. Sale of balancing area services to Pend Oreille PUD. Contract expires 9/30/2021. Not included in rate period proforma
68
CAISO Market Sales. Revenues from power sales to CAISO. New market opportunity since previous case. 3-year average since
inception of opportunity with phase out and ultimate expiration of Energy America contract. CAISO Mkt Sales.xlsx
69 Solar Select.
70 Total Account 447. Summarization of lines 54-61.
71 N/
72 N/
73 456.030 Clearwater Transmission - Idaho only.
74 456.380 Clearwater REC - Idaho only.
75
Non-WA EIA REC Sales. Idaho share of REC sales. These are not included in base power supply expenses and are tracked and
rebated annually.
Not included in rate period proforma.
Included in annual REC filing.
76 Natural Gas Liquids. Liquids rebates from natural gas purchased at
AECO; 5-year average. Natural Gas Liquids.xlsx
77
Surplus AECO to Malin Transportation. Test year value includes
resale of purchases made to fuel gas-fired generation fleet as part of
risk management/hedging policy (see line 20, Natural Gas Fuel
Purchases) due to changing market conditions (i.e., plant later
becomes uneconomic relative to purchasing electricity from the market). Proforma value reflects only revenue received from buying
AECO gas and selling it at Malin using firm transportation rights surplus to Avista gas plant use.'Fuel Costs' and 'Gas Contracts MTM' sheets of this exhibit
78 Total Account 456. Summarization of lines 65-67.
79 N/
80 Total Revenue - Sum of Accounts 447, 456.
81 N/
82 Total Net Expense - Total expense minus total revenue.
Exhibit No. 9
Case No. AVU-E-20-01
C. Kalich, AvistaSchedule 3, Page 3 of 3
Avista Corp.
Market Purchases and Sales, Plant Generation and Fuel Cost Summar
Idaho Normalized September 2021 - August 202
720 744 720 744 744 672 744 720 744 720 744 744
Total Sep-21 Oct-21 Nov-21 Dec-22 Jan-22 Feb-22 Mar-22 Apr-22 May-22 Jun-22 Jul-22 Aug-22
Market Sales - Dollars $80,255,168 $6,825,852 $5,391,012 $5,861,698 $9,003,540 $5,598,081 $4,049,338 $5,218,558 $5,880,976 $7,773,059 $7,109,589 $12,243,175 $5,300,291Market Sales - MWh (2,627,796) -182,845 -174,616 -162,430 -192,472 -134,906 -94,966 -174,512 -276,962 -391,205 -371,934 -330,942 -140,004Average Market Sales Price -$/ MWh -$30.54 -$37.33 -$30.87 -$36.09 -$46.78 -$41.50 -$42.64 -$29.90 -$21.23 -$19.87 -$19.12 -$36.99 -$37.86Market Purchases - Dollars $3,200,659 $338,506 $358,670 $393,797 $557,076 $561,426 $350,345 $588,364 $19,899 $1,256 $0 $1,204 $30,115Market Purchases - MWh 113,825 10,436 11,598 13,135 22,413 17,040 18,719 16,895 2,356 187 0 187 860Average Market Purchase Price - $/MWh $28.12 $32.44 $30.93 $29.98 $24.86 $32.95 $18.72 $34.82 $8.45 $6.71 #DIV/0! $6.45 $35.04Net Market Purchases (Sales) MWh -2,513,970 -172,409 -163,018 -149,296 -170,059 -117,866 -76,247 -157,617 -274,606 -391,018 -371,934 -330,755 -139,145Net Market Purchases (Sales) aMW -287.0 -239 -219 -207 -229 -158 -113 -212 -381 -526 -517 -445 -187Average Sale and Purchase Price - $/MWh -$28.11 -$33.56 -$27.02 -$31.14 -$39.31 -$33.15 -$32.54 -$24.19 -$20.98 -$19.86 -$19.12 -$36.97 -$37.41
Colstrip MWh 1,575,237 143,297 146,369 143,297 146,760 148,073 132,769 147,286 107,254 90,968 80,655 141,121 147,389Colstrip Fuel Cost $/MWh $16.26 $16.48 $15.25 $12.73 $16.51 $16.50 $16.53 $16.51 $17.20 $17.78 $18.09 $16.62 $16.53Colstrip Fuel Cost $25,613,517 $2,362,000 $2,232,838 $1,823,597 $2,422,665 $2,443,141 $2,194,220 $2,431,756 $1,844,484 $1,617,850 $1,459,376 $2,345,391 $2,436,199
Kettle Falls MWh 299,074 28,963 28,751 29,325 32,449 33,396 27,271 25,306 11,679 10,982 11,502 27,785 31,665Kettle Falls Fuel Cost $/MWh $21.54 $21.29 $21.44 $21.33 $21.20 $21.15 $21.34 $21.71 $22.95 $22.52 $23.61 $21.51 $21.25Kettle Falls Fuel Cost $6,442,015 $616,739 $616,291 $625,610 $688,069 $706,451 $582,077 $549,436 $267,998 $247,359 $271,583 $597,544 $672,857
Coyote Springs MWh 2,120,469 189,124 196,427 197,646 211,039 203,958 174,378 182,959 156,224 106,080 119,137 188,900 194,596Coyote Springs Fuel Cost $/MWh $17.67 $17.47 $17.45 $18.93 $22.31 $22.50 $20.79 $16.77 $14.25 $14.37 $13.20 $14.72 $14.90Coyote Springs Fuel Cost $37,467,669 $3,304,443 $3,428,014 $3,741,246 $4,707,733 $4,588,687 $3,626,152 $3,067,762 $2,225,950 $1,523,886 $1,573,137 $2,780,823 $2,899,836
Lancaster MWh 1,586,368 159,867 168,208 162,418 169,954 150,835 129,935 126,404 80,235 65,206 60,226 152,390 160,691Lancaster Fuel Cost $/MWh $18.44 $18.28 $18.21 $19.69 $23.47 $22.49 $21.24 $15.77 $15.62 $15.14 $14.32 $15.40 $15.49Lancaster Fuel Cost $29,254,365 $2,922,810 $3,062,654 $3,197,227 $3,988,503 $3,392,808 $2,759,440 $1,993,241 $1,252,928 $987,141 $862,190 $2,346,946 $2,488,476
Boulder Park MWh 96,640 9,628 7,489 8,543 14,082 10,845 6,975 5,921 2,429 3,406 2,201 11,617 13,502Boulder Park Fuel Cost $/MWh $22.84 $23.47 $22.91 $25.53 $27.82 $25.29 $26.61 $17.82 $17.02 $19.43 $18.86 $19.17 $19.47Boulder Park Fuel Cost $2,207,320 $225,950 $171,536 $218,101 $391,724 $274,274 $185,616 $105,536 $41,338 $66,197 $41,524 $222,674 $262,848
Kettle Falls CT MWh 11,135 1,383 957 1,332 0 0 0 1,097 319 607 313 2,185 2,941Kettle Falls CT Fuel Cost $/MWh $20.01 $22.84 $22.80 $25.59 $16.07 $17.19 $19.44 $19.31 $18.00 $18.71Kettle Falls CT Fuel Cost $222,816 $31,601 $21,828 $34,081 $0 $0 $0 $17,626 $5,485 $11,789 $6,053 $39,329 $55,024
Rathdrum MWh 245,377 23,796 13,785 20,430 38,896 27,320 17,191 14,131 5,982 8,196 4,899 31,658 39,094Rathdrum Fuel Cost $/MWh $29.72 $31.10 $29.39 $33.82 $35.80 $32.56 $34.69 $20.95 $22.14 $25.79 $25.96 $25.14 $25.96Rathdrum Fuel Cost $7,292,374 $740,051 $405,127 $690,942 $1,392,570 $889,652 $596,281 $296,080 $132,419 $211,399 $127,180 $795,964 $1,014,709
Northeast MWh 0 0 0 0 0 0 0 0 0 0 0 0 0Northeast Fuel Cost $/MWh #DIV/0!Northeast Fuel Cost $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0
Total Fuel Expense $108,500,075 $10,203,593 $9,938,289 $10,330,805 $13,591,265 $12,295,013 $9,943,787 $8,461,436 $5,770,603 $4,665,622 $4,341,043 $9,128,671 $9,829,949
Net Fuel and Purchase Expense $31,445,566
Exhibit No. 9
Case No. AVU-E-20-01
C. Kalich, Avista
Schedule 4, Page 1 of 1
Avista Corp
PCA Authorized Expense and Retail Sales (Annual)
Based on Pro forma September 2021 - August 2022
January 2019 - December 2019 Historic Normalized Loads
PCA Authorized Power Supply Expense - System Numbers (1)
Total January February March April May June July August September October November December
Account 555 - Purchased Power $106,845,279 $9,606,334 $9,698,053 $9,366,237 $9,872,022 $8,886,045 $8,285,804 $8,164,246 $8,144,382 $8,017,698 $8,211,843 $9,102,301 $9,490,316
Account 501 - Thermal Fuel $32,055,532 $3,110,734 $3,149,592 $2,776,297 $2,981,191 $2,112,483 $1,865,209 $1,730,959 $2,942,935 $3,109,056 $2,978,738 $2,849,129 $2,449,208
Account 537- MT Invasive Species $1,610,000 $134,167 $134,167 $134,167 $134,167 $134,167 $134,167 $134,167 $134,167 $134,167 $134,167 $134,167 $134,167
Account 547 - Natural Gas Fuel $86,108,743 $11,295,559 $9,954,341 $7,969,107 $6,281,879 $4,451,743 $3,596,406 $3,403,267 $7,000,112 $7,540,209 $8,034,011 $7,893,498 $8,688,611
Account 557 - Other Expenses $631,627 $52,636 $52,636 $52,636 $52,636 $52,636 $52,636 $52,636 $52,636 $52,636 $52,636 $52,636 $52,636
Account 565 - Transmission Expense $18,388,767 $1,532,397 $1,532,397 $1,532,397 $1,532,397 $1,532,397 $1,532,397 $1,532,397 $1,532,397 $1,532,397 $1,532,397 $1,532,397 $1,532,397
Account 456 - Other Revenue -$5,440,184 -$189,208 -$490,610 -$563,735 -$639,676 -$357,547 -$533,284 -$519,401 -$450,199 -$452,801 -$357,164 -$420,937 -$465,622
Account 447 - Sale for Resale -$83,814,599 -$9,345,121 -$5,924,158 -$4,348,472 -$5,511,862 -$6,134,003 -$8,021,316 -$7,355,600 -$12,554,225 -$5,626,357 -$7,145,585 -$5,683,315 -$6,164,584
Power Supply Expense $156,385,167 $16,197,497 $18,106,417 $16,918,634 $14,702,753 $10,677,921 $6,912,018 $7,142,671 $6,802,205 $14,307,004 $13,441,043 $15,459,875 $15,717,128
$156,385Account 456 - Transmission Revenue (2)-$16,222,003 -$1,098,227 -$1,274,169 -$1,354,060 -$1,178,427 -$1,385,805 -$1,569,197 -$1,530,360 -$1,471,969 -$1,177,009 -$1,173,629 -$1,400,030 -$1,609,121
Total Authorized Expense $140,163,164 $15,099,270 $16,832,248 $15,564,574 $13,524,327 $9,292,116 $5,342,821 $5,612,310 $5,330,236 $13,129,996 $12,267,414 $14,059,845 $14,108,007
Idaho Only (no adjustment for Directly assigned)$48,160,063 $5,188,109 $5,783,561 $5,347,988 $4,646,959 $3,192,771 $1,835,793 $1,928,390 $1,831,469 $4,511,466 $4,215,084 $4,830,963 $4,847,511
PCA Authorized Idaho Retail Sales (3)
Total ID Retail Sales, MWh 2,966,810 290,239 259,340 251,938 233,373 224,656 219,310 245,017 250,933 210,200 227,542 262,248 292,013
2022 Load Change Adjustment Rate (4)$25.72 /MWh
2023 Load Change Adjustment Rate (4)$26.52 /MWh
(1) Multiply number by ROO current production/transmission allocation ratio of 34.36%(2) Transmission Revenue as discussed by Company Witness Schlect(3) Test Year Weather Normalized Idaho Retail Sales monthly data from Company witness Ms. Knox Revenue Normalization workpapers(4) Rate Year 1 and Rate Year 2 Load Change Adjustment Rate discussed by Ms. Knox.
Exhibit No. 9
Case No. AVU-E-20-01
C. Kalich, Avista
Schedule 5, Page 1 of 1