20230201Kalich Exhibit 7 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]
[e-mail]
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF AVISTA CORPORATION FOR THE ) AUTHORITY TO INCREASE ITS RATES ) AND CHARGES FOR ELECTRIC AND ) NATURAL GAS SERVICE TO ELECTRIC )
AND NATURAL GAS CUSTOMERS IN THE )
STATE OF IDAHO )
CASE NO. AVU-E-23-01
CASE NO. AVU-G-23-01
EXHIBIT NO. 7
CLINT G. KALICH )
FOR AVISTA CORPORATION
(ELECTRIC ONLY)
Exhibit No. 7
Case No. AVU-E-23-01 & AVU-G-23-01
C. Kalich, Avista
Schedule 1, Page 1 of 1
CONFIDENTIAL subject to Attorney’s Certificate of Confidentiality
Dispatch Model Results
Pages 1 of 8
Line 12 Mo-Ending 9/1/23 - 8/31/24
No.Jun-22 Adjustment Pro Forma
1 555 PURCHASED POWER
2 Short-Term Market 32,694 -27,913 4,781
3 Chelan PUD 14,586 15,339 29,925
4 Douglas PUD 5,174 -1,110 4,064
5 Grant PUD 14,263 9,111 23,374
6 Columbia Basin Hydro 0 909 909
7 Lancaster PPA 28,803 524 29,327
8 Small Power 1,044 240 1,285
9 Stimson 1,480 178 1,658
10 Spokane-Upriver 1,880 1,535 3,415
11 Spokane Waste-to-Energy 5,470 314 5,784
12 Palouse Wind 23,361 -23,361 0
13 Adams-Neilson Solar 0 0 0
14 Rattlesnake Flats Wind 12,907 -12,907 0
15 Clearwater (Idaho only)11 -11 0
16 WPM Ancillary Services (reconciling item)1,141 -1,141 0
17 Non-Mon. Accruals (reconciling item)113 -113 0
18 Total Account 555 142,926 -38,405 104,521
19
20 557 OTHER EXPENSES
21 Miscellaneous Transaction Fees 754 -145 609
22 Other Resource Costs 1 -1 0
23 REC Expense 84 0 84
24 WA CCA Law Emission Allowance Costs 0 70,535 70,535
25 Natural Gas Fuel Purchases 75,748 -75,296 452
26 Total Account 557 76,587 -4,907 71,680
27
28 501 THERMAL FUEL EXPENSE
29 Kettle Falls - Wood Fuel 7,734 1,030 8,764
30 Colstrip - Fuel Cost 29,388 2,617 32,005
31 Total Account 501 37,122 3,648 40,769
32
33 547 OTHER FUEL EXPENSE
34 Coyote Springs 2 Combined Cycle Combustion Turbine 55,127 943 56,070
35 Lancaster Combined Cycle Combustion Turbine 47,645 8,026 55,671
36 TC Energy Pipeline 10,087 708 10,795
37 Williams Northwest Pipeline 0 275 275
38 Rathdrum Combustion Turbine 6,459 32,333 38,792
39 Northeast Combustion Turbine 81 -81 0
40 Boulder Park Engines 2,371 1,843 4,214
41 Kettle Falls Combustion Turbine 153 1,314 1,467
42 Total Account 547 121,923 45,361 167,285
43
44 565 TRANSMISSION OF ELECTRICITY BY OTHERS
45 Short-term Purchases 1,327 -1,327 0
46 BPA Point-to-Point for Colstrip, Coyote Springs 2 & Lancaster 13,192 1,427 14,619
47 BPA Townsend to Garrison 1,508 0 1,508
48 Columbia Basin Hydro 0 236 236
49 Avista on BPA Borderline/Network 1,540 34 1,574
50 Kootenai for Worley 48 -2 45
51 Sagle for Northern Lights 143 -10 134
52 Northwestern for Colstrip 1,007 -181 826
53 Portland General Electric John Day to COB 1,077 -434 643
54 Total Account 565 19,842 -257 19,585
55
56 407 Regulatory Debits
57 407.434 Incremental EIM O&M (reconciling item)286 -286 0
58
59 537 MT Invasive Species
60 Total Montana Invasive Species 777 3 780
61
62 TOTAL EXPENSE 399,463 5,157 404,620
Avista Corp.
Power Supply Pro Forma - Idaho Jurisdiction
System Numbers - 12ME June 2022 Actual vs. 09/23 - 08/24 Pro Forma
Test Year Load
($000)
Page 1 of 4
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 2, Page 1 of 4
Line 12 Mo-Ending 9/1/23 - 8/31/24
No.Jun-22 Adjustment Pro Forma
Avista Corp.
Power Supply Pro Forma - Idaho Jurisdiction
System Numbers - 12ME June 2022 Actual vs. 09/23 - 08/24 Pro Forma
Test Year Load
($000)
63
64 447 SALES FOR RESALE
65 Short-Term Market 100,229 106,456 206,685
66 Nichols Pumping 2,247 723 2,969
67 Sovereign/Kaiser Services 141 5 147
68 Direct Energy CEC-1 Index (formerly Energy Amercia)0 0 0
69 Morgan Stanley index sale 0 0 0
70 Douglas PUD 0 0 0
71 Pend Oreille PUD 344 -25 319
72 Energy Imbalance Market 0 0 0
73 CAISO Market Sales 2,781 0 2,781
74 Merchant Ancillary Services (reconciling item)22,489 -22,489 0
75 Total Account 447 128,231 84,669 212,900
76
77 456 OTHER ELECTRIC REVENUE
78 REC Revenue (Idaho only)5,858 -1,889 3,969
79 Clearwater REC Revenue 361 -361 0
80 Natural Gas Liquids 654 -182 472
81 Surplus AECO to Malin Transportation 83,299 -75,051 8,248
82 Total Account 456 90,172 -77,483 12,689
83
84 TOTAL REVENUE 218,403 7,187 225,590
85
86 TOTAL NET EXPENSE 181,060 -2,030 179,030
Page 2 of 4
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 2, Page 2 of 4
Line 9/1/23 - 8/31/24 9/1/24 - 8/31/25
No.Pro Forma Adjustment Pro Forma
1 555 PURCHASED POWER
2 Short-Term Market 4,781 -2,465 2,315
3 Chelan PUD 29,925 7,938 37,863
4 Douglas PUD 4,064 46 4,110
5 Grant PUD 23,374 -3,932 19,442
6 Columbia Basin Hydro 909 13,011 13,920
7 Lancaster PPA 29,327 344 29,671
8 Small Power 1,285 10 1,294
9 Stimson 1,658 -5 1,653
10 Spokane-Upriver 3,415 54 3,469
11 Spokane Waste-to-Energy 5,784 176 5,961
12 Palouse Wind 0 0 0
13 Adams-Neilson Solar 0 0 0
14 Rattlesnake Flats Wind 0 0 0
15 Clearwater (Idaho only)0 0 0
16 WPM Ancillary Services (reconciling item)0 0 0
17 Non-Mon. Accruals (reconciling item)0 0 0
18 Total Account 555 104,521 15,177 119,698
19
20 557 OTHER EXPENSES
21 Miscellaneous Transaction Fees 609 0 609
22 Other Resource Costs 0 0 0
23 REC Expense 84 0 84
24 WA CCA Law Emission Allowance Costs 70,535 13,570 84,105
25 Natural Gas Fuel Purchases 452 0 452
26 Total Account 557 71,680 13,570 85,250
27
28 501 THERMAL FUEL EXPENSE
29 Kettle Falls - Wood Fuel 8,764 -308 8,456
30 Colstrip - Fuel Cost 32,005 965 32,971
31 Total Account 501 40,769 657 41,427
32
33 547 OTHER FUEL EXPENSE
34 Coyote Springs 2 Combined Cycle Combustion Turbine 56,070 -4,316 51,755
35 Lancaster Combined Cycle Combustion Turbine 55,671 -5,084 50,586
36 TC Energy Pipeline 10,795 0 10,795
37 Williams Northwest Pipeline 275 -2 273
38 Rathdrum Combustion Turbine 38,792 -16 38,776
39 Northeast Combustion Turbine 0 0 0
40 Boulder Park Engines 4,214 -283 3,931
41 Kettle Falls Combustion Turbine 1,467 -52 1,415
42 Total Account 547 167,285 -9,753 157,532
43
44 565 TRANSMISSION OF ELECTRICITY BY OTHERS
45 Short-term Purchases 0 0 0
46 BPA Point-to-Point for Colstrip, Coyote Springs 2 & Lancaster 14,619 0 14,619
47 BPA Townsend to Garrison 1,508 0 1,508
48 Columbia Basin Hydro 236 1,543 1,779
49 Avista on BPA Borderline/Network 1,574 0 1,574
50 Kootenai for Worley 45 0 45
51 Sagle for Northern Lights 134 0 134
52 Northwestern for Colstrip 826 0 826
53 Portland General Electric John Day to COB 643 0 643
54 Total Account 565 19,585 1,543 21,128
55
56 407 Regulatory Debits
57 407.434 Incremental EIM O&M (reconciling item)0 0 0
58
59 537 MT Invasive Species
60 Total Montana Invasive Species 780 0 780
61
62 TOTAL EXPENSE 404,620 21,195 425,815
Avista Corp.
Power Supply Pro Forma - Idaho Jurisdiction
System Numbers - 12ME August 2024 Actual vs. 09/24 - 08/25 Pro Forma
Test Year Load
($000)
Page 3 of 4
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 2, Page 3 of 4
Line 9/1/23 - 8/31/24 9/1/24 - 8/31/25
No.Pro Forma Adjustment Pro Forma
Avista Corp.
Power Supply Pro Forma - Idaho Jurisdiction
System Numbers - 12ME August 2024 Actual vs. 09/24 - 08/25 Pro Forma
Test Year Load
($000)
63
64 447 SALES FOR RESALE
65 Short-Term Market 206,685 8,184 214,869
66 Nichols Pumping 2,969 -302 2,667
67 Sovereign/Kaiser Services 147 0 147
68 Direct Energy CEC-1 Index (formerly Energy Amercia)0 0 0
69 Morgan Stanley index sale 0 0 0
70 Douglas PUD 0 0 0
71 Pend Oreille PUD 319 0 319
72 Energy Imbalance Market 0 0 0
73 CAISO Market Sales 2,781 0 2,781
74 Merchant Ancillary Services (reconciling item)0 0 0
75 Total Account 447 212,900 7,882 220,783
76
77 456 OTHER ELECTRIC REVENUE
78 Non-WA EIA REC (Idaho only)3,969 0 3,969
79 Clearwater Trans and REC Revenue 0 0 0
80 Natural Gas Liquids 472 0 472
81 Surplus AECO to Malin Transportation 8,248 105 8,353
82 Total Account 456 12,689 105 12,794
83
84 TOTAL REVENUE 225,590 7,987 233,576
85
86 TOTAL NET EXPENSE 179,030 13,208 192,238
Page 4 of 4
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 2, Page 4 of 4
Brief Description of Kalich Exhibit No.7, Schedule 3 - Power
Supply Adjustment
Workpaper
1 N/A
2 Short-Term Market. Term financial and physical contracts, plus hour
spot transactions. Spot market in proforma are results of Aurora
model.
Term deals.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 Columbia Basin Hydro. Contracts expense on multiple CBH
projects. Expires 12/31/2045.
Aurora-generated - see CGK-1/CGK-2
7 Lancaster PPA. Includes contract costs of capital, operations and
maintenance (O&M). Variable O&M based on the generation level
determined by Aurora model.
Lancaster PPA - workpaper.xlsx (for
PPA energy, capacity & O&M)
8 Small Power - Summation of small PURPA power contracts; pro
forma costs are based on 5-year average generation levels and
actual pro forma period contract rates.
Small Power.xlsx and IPC Deer
Lake.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.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.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.xlsx
12 'Palouse Wind. Not included - flows through PCA.
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. Not included - flows through PCA.
15 Clearwater - Idaho only.
16 WPN Ancillary Services - reconciling item .
17 Non-Monetary Accruals - reconciling item .
18 Total Account 555 - with reconciling items.Summarization of lines 2-14.
19 N/A
20 N/A
21 Miscellaneous Transaction Fees. Expense is 5-year average of
transaction fees for CAISO, brokerage fees for electricity and
natural gas market transactions, and Canadian Merchandise
Processing Fees assessed by the U.S. Government on imported
Canadian gas.
Transactions Fees.xlsx
22 Other Resource Cost. Optional renewable power offset ; set to zero
in pro forma.
Not included in rate period proforma.
Not a recurring expense.
23 REC expense. Renewable energy credit broker fees.
24 WA CCA Law Emission Allowance Costs. Allowance costs for In-
WA CO2 emissions (Boulder Park, NE is zero since cannot operate
except in system emergencies and testing, and Kettle Falls facility is
exempt due to being under the 25,000 tonne annual threshold), and
in-WA wholesale market sales at Mid-C, for the benefit of Idaho.
See Idaho CCA Costs sheet.
25 Natural Gas Fuel. Purchases to fuel gas-fired generation fleet as
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). Pro forma expense is zero
because we do not emulate our hedging program in pro forma
modeling.
Reclassification - please see
acccounts 501/547
26 Total Account 557 Summarization of lines 18-22.
27 N/A
28 N/A
29 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 2017-2021.xlsx
30 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 2017-2021.xlsx
Line
No.
Avista Corp.
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 3, Page 1 of 3
Brief Description of Kalich Exhibit No.7, Schedule 3 - Power
Supply Adjustment
Workpaper
Line
No.
Avista Corp.
31 Total Account 501.Summarization of lines 24-25.
32 N/A
33 N/A
34 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
35 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
36 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 5-year average
generation.
Natural Gas Transporation
Contracts.xlsx
37 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 5-year average generation.
'Fuel Costs' sheet of this exhibit
38 Rathdrum 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 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
40 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
41 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
42 Total Account 547 Summarization of lines 29-36.
43 N/A
44 N/A
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 pro forma
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.
565 Transmission Expense.xlsx
47 BPA Townsend to Garrison. Fixed fee contract with BPA for
transmission of Colstrip power from Townsend to Garrison.
565 Transmission Expense.xlsx
48 Avista on BPA Borderlines. Purchase for serving Avista load in 3rd-
party service area. 5-year average of actual expense priced at
proforma year tariffed rate.
565 Transmission Expense.xlsx
49 Columbia Basin Hydro transmission 565 Transmission Expense.xlsx
50 Kootenai for Worley. Purchase for serving Avista load in 3rd-party
service area. Pro forma expense is based on contracted capacity at
tariffed rate.
565 Transmission Expense.xlsx
51 Sagle for Northern Lights. Purchase for serving Avista load in 3rd-
party service area. Pro forma expense is based on contracted
capacity at tariffed rate.
565 Transmission Expense.xlsx
52 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.
565 Transmission Expense.xlsx
53 Portland General Electric John Day to COB. Purchase of Southern
Interntie rights from John Day substation to California-Oregon
border. Proforma expense priced at pro forma year tariffed rate.
565 Transmission Expense.xlsx
54 Total Account 565.Summarization of lines 41-48.
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 3, Page 2 of 3
Brief Description of Kalich Exhibit No.7, Schedule 3 - Power
Supply Adjustment
Workpaper
Line
No.
Avista Corp.
55 N/A
56 N/A
57 407.434 Incremental EIM O&M (reconciling item)
58 N/A
59 N/A
60 Montana Invasive Species.
61 N/A
62 Total Expense - Sum of Accounts 555, 557, 501, 547, 565.
63 N/A
64 N/A
65 Short-Term Market. Term financial and physical contracts, plus
hourly spot transactions. Spot market in pro forma are results of
Aurora model.
Aurora-generated - see CGK-1/CGK-2
66 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
67 Sovereign/Kaiser Services. Sale of balancing area services to
Kaiser’s Trentwood plant. Based on 5-year average.
447 Sovereign and POPUD.xlsx
68 Energy America. Contract expired 12/31/2019. Not included in rate period proforma
69 Morgan Stanley. Index contract with no net power supply expense.
Refer to testimony for additional detail.
Not included in rate period proforma
70 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
71 Pend Oreille PUD. Sale of balancing area services to Pend Oreille
PUD. Based on TY since 5-year average overstates due to loss of
large industrial customers. Contract expires 9/30/2026.
447 Sovereign and POPUD.xlsx
72 Energy Imbalance Market benefits. Effective March 1, 2022.
Annualized amount is $5.8 million in future years.
73 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 Market Sales.xlsx
74 Merchant Ancillary Services - reconciling item.
75 Total Account 447 - with reconciling items.Summarization of lines 54-61.
76 N/A
77 N/A
78 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 in WA and goes through the base for ID.
Not included in rate period proforma.
Included in annual REC filing.
79 Clearwater REC revenue. Revenue associated with the use of
Clearwater Paper's generation.
80 Natural Gas Liquids. Liquids rebates from natural gas purchased at
AECO; 5-year average.
Natural Gas Liquids.xlsx
81 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). Pro forma 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
82 Total Account 456.Summarization of lines 65-67.
83 N/A
84 Total Revenue - Sum of Accounts 447, 456.
85 N/A
86 Total Net Expense - Total expense minus total revenue.
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 3, Page 3 of 3
Avista Corp.
Market Purchases and Sales, Plant Generation and Fuel Cost Summary
Idaho Normalized September 2023 - August 2024
720 744 720 744 744 696 744 720 744 720 744 744
Total Sep-23 Oct-23 Nov-23 Dec-23 Jan-24 Feb-24 Mar-24 Apr-24 May-24 Jun-24 Jul-24 Aug-24
Market Sales - Dollars $206,684,747 $25,095,862 $11,370,462 $14,669,505 $17,182,395 $15,398,558 $12,938,472 $12,450,946 $11,998,565 $16,517,461 $13,362,588 $30,833,859 $24,866,074Market Sales - MWh (2,503,004)-193,666 -142,561 -168,411 -160,893 -162,658 -144,566 -184,634 -236,801 -382,479 -262,128 -258,168 -206,039
Average Market Sales Price -$/ MWh -$82.57 -$129.58 -$79.76 -$87.11 -$106.79 -$94.67 -$89.50 -$67.44 -$50.67 -$43.19 -$50.98 -$119.43 -$120.69
Market Purchases - Dollars $4,780,581 $337,853 $252,951 $116,046 $1,377,216 $81,826 $442,450 $82,730 $119,043 -$261 $194,751 $958,904 $817,072
Market Purchases - MWh 99,294 3,975 7,413 3,265 29,659 1,678 11,638 1,785 7,280 53 4,163 24,047 4,340
Average Market Purchase Price - $/MWh $48.15 $85.00 $34.12 $35.54 $46.44 $48.77 $38.02 $46.35 $16.35 -$4.94 $46.79 $39.88 $188.26
Net Market Purchases (Sales) MWh -2,403,710 -189,692 -135,148 -165,146 -131,234 -160,980 -132,928 -182,849 -229,521 -382,426 -257,965 -234,121 -201,699
Net Market Purchases (Sales) aMW -274.4 -263 -182 -229 -176 -216 -191 -246 -319 -514 -358 -315 -271Average Sale and Purchase Price - $/MWh -$77.59 -$125.27 -$74.13 -$84.77 -$82.94 -$93.20 -$80.00 -$66.35 -$48.67 -$43.18 -$49.45 -$105.86 -$114.31
Colstrip MWh 1,615,307 142,105 140,213 139,397 152,179 152,896 143,032 151,979 133,054 99,239 73,362 139,269 148,584
Colstrip Fuel Cost $/MWh $19.81 $16.47 $16.42 $16.42 $16.41 $21.40 $21.41 $21.41 $21.64 $21.85 $23.09 $21.79 $21.60Colstrip Fuel Cost $32,005,291 $2,340,682 $2,302,891 $2,288,376 $2,497,996 $3,272,646 $3,062,621 $3,253,115 $2,879,392 $2,168,728 $1,694,217 $3,035,245 $3,209,381
Kettle Falls MWh 315,296 31,289 33,206 32,504 32,790 33,621 31,289 32,921 18,515 769 9,231 25,474 33,688
Kettle Falls Fuel Cost $/MWh $27.80 $27.87 $27.88 $27.86 $27.91 $27.58 $27.59 $27.59 $28.09 $29.83 $29.15 $27.72 $27.57
Kettle Falls Fuel Cost $8,764,127 $871,969 $925,833 $905,476 $915,182 $927,184 $863,310 $908,248 $520,002 $22,950 $269,093 $706,003 $928,877
Coyote Springs MWh 1,872,326 185,951 138,476 209,627 210,598 220,092 190,826 160,037 125,283 32,235 41,288 153,969 203,945Coyote Springs Fuel Cost $/MWh $29.95 $28.20 $28.14 $32.36 $35.34 $36.83 $34.89 $29.14 $22.04 $20.23 $20.71 $25.13 $25.19
Coyote Springs Fuel Cost $56,070,483 $5,244,426 $3,897,003 $6,784,001 $7,443,577 $8,105,708 $6,657,455 $4,662,967 $2,761,843 $652,159 $855,203 $3,869,618 $5,136,523
Lancaster MWh 1,808,935 165,347 175,027 188,425 181,043 196,868 179,616 181,650 80,161 125,499 29,504 129,431 176,363
Lancaster Fuel Cost $/MWh $30.78 $29.80 $29.09 $33.50 $36.87 $38.06 $36.26 $30.32 $23.20 $21.18 $22.19 $25.72 $26.36
Lancaster Fuel Cost $55,670,517 $4,927,285 $5,090,973 $6,312,381 $6,675,239 $7,492,007 $6,513,327 $5,508,295 $1,859,650 $2,658,137 $654,610 $3,329,119 $4,649,492
Boulder Park MWh 107,823 12,750 10,735 10,877 12,226 12,460 7,491 6,426 3,732 3,668 3,181 9,783 14,494
Boulder Park Fuel Cost $/MWh $39.09 $37.81 $36.63 $42.52 $46.64 $48.98 $45.90 $38.72 $31.01 $26.38 $27.12 $33.20 $33.10
Boulder Park Fuel Cost $4,214,389 $482,040 $393,224 $462,529 $570,246 $610,321 $343,858 $248,823 $115,743 $96,746 $86,261 $324,844 $479,754
Kettle Falls CT MWh 31,255 3,766 3,154 3,272 3,199 3,237 2,138 2,068 1,128 1,162 884 2,959 4,288
Kettle Falls CT Fuel Cost $/MWh $46.93 $46.44 $44.39 $50.96 $55.21 $58.24 $54.66 $46.57 $37.96 $32.27 $33.92 $41.36 $40.63
Kettle Falls CT Fuel Cost $1,466,833 $174,894 $140,020 $166,738 $176,599 $188,522 $116,872 $96,293 $42,810 $37,503 $29,990 $122,374 $174,219
Rathdrum MWh 753,110 84,902 91,725 87,786 84,088 90,032 60,797 70,613 23,935 21,690 10,723 31,502 95,318
Rathdrum Fuel Cost $/MWh $51.51 $49.82 $47.81 $55.24 $59.45 $62.41 $58.47 $50.56 $40.76 $34.83 $36.26 $43.96 $42.79
Rathdrum Fuel Cost $38,791,961 $4,229,839 $4,385,783 $4,848,895 $4,999,331 $5,619,287 $3,554,966 $3,570,203 $975,641 $755,505 $388,854 $1,384,691 $4,078,964
Northeast MWh 0 0 0 0 0 0 0 0 0 0 0 0 0
Northeast Fuel Cost $/MWh #DIV/0!
Northeast Fuel Cost $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0
Total Fuel Expense $196,983,601 $18,271,135 $17,135,727 $21,768,397 $23,278,171 $26,215,676 $21,112,410 $18,247,944 $9,155,080 $6,391,728 $3,978,228 $12,771,894 $18,657,210
Net Fuel and Purchase Expense -$4,920,565
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 4, Page 1 of 2
Avista Corp.
Market Purchases and Sales, Plant Generation and Fuel Cost Summary
Idaho Normalized September 2024 - August 2025
720 744 720 744 744 696 744 720 744 720 744 744
Total Sep-24 Oct-24 Nov-24 Dec-24 Jan-25 Feb-25 Mar-25 Apr-25 May-25 Jun-25 Jul-25 Aug-25
Market Sales - Dollars $214,869,156 $25,804,510 $11,091,019 $13,655,285 $15,127,659 $16,352,523 $13,318,694 $12,888,558 $12,277,083 $16,977,965 $12,768,046 $35,484,039 $29,123,775Market Sales - MWh (2,869,001)-252,463 -170,391 -194,214 -166,831 -186,502 -149,113 -196,487 -247,932 -441,439 -293,007 -306,558 -264,065
Average Market Sales Price -$/ MWh -$74.89 -$102.21 -$65.09 -$70.31 -$90.68 -$87.68 -$89.32 -$65.59 -$49.52 -$38.46 -$43.58 -$115.75 -$110.29
Market Purchases - Dollars $2,315,278 $0 $54,396 $48,617 $684,182 $25,287 $645,787 $66,628 $43,869 $0 $61,843 $373,142 $311,526
Market Purchases - MWh 55,117 0 1,222 1,928 17,744 593 15,666 1,557 3,000 0 2,870 8,664 1,873
Average Market Purchase Price - $/MWh $42.01 $0.00 $44.52 $25.22 $38.56 $42.66 $41.22 $42.78 $14.62 $0.00 $21.55 $43.07 $166.31
Net Market Purchases (Sales) MWh -2,813,885 -252,463 -169,169 -192,286 -149,087 -185,909 -133,447 -194,930 -244,932 -441,439 -290,138 -297,894 -262,192
Net Market Purchases (Sales) aMW -321.2 -351 -227 -267 -200 -250 -192 -262 -340 -593 -403 -400 -352Average Sale and Purchase Price - $/MWh -$72.69 -$102.21 -$64.31 -$69.37 -$78.25 -$87.27 -$76.91 -$64.74 -$48.75 -$38.46 -$42.94 -$111.38 -$108.34
Colstrip MWh 1,606,138 142,105 140,213 139,397 152,029 152,896 137,533 151,979 129,331 99,534 72,696 139,842 148,584
Colstrip Fuel Cost $/MWh $19.93 $16.47 $16.42 $16.42 $16.43 $21.40 $22.27 $21.41 $22.26 $21.79 $23.31 $21.70 $21.60Colstrip Fuel Cost $32,005,291 $2,340,682 $2,302,891 $2,288,376 $2,497,996 $3,272,646 $3,062,621 $3,253,115 $2,879,392 $2,168,728 $1,694,217 $3,035,245 $3,209,381
Kettle Falls MWh 312,455 32,601 32,779 32,283 32,617 33,688 30,048 33,146 17,147 730 8,980 24,747 33,688
Kettle Falls Fuel Cost $/MWh $28.05 $26.75 $28.24 $28.05 $28.06 $27.52 $28.73 $27.40 $30.33 $31.42 $29.97 $28.53 $27.57
Kettle Falls Fuel Cost $8,764,127 $871,969 $925,833 $905,476 $915,182 $927,184 $863,310 $908,248 $520,002 $22,950 $269,093 $706,003 $928,877
Coyote Springs MWh 1,845,516 188,953 138,196 203,766 200,719 223,020 194,463 162,685 118,584 31,575 30,185 149,360 204,011Coyote Springs Fuel Cost $/MWh $30.38 $27.76 $28.20 $33.29 $37.08 $36.35 $34.24 $28.66 $23.29 $20.65 $28.33 $25.91 $25.18
Coyote Springs Fuel Cost $56,070,483 $5,244,426 $3,897,003 $6,784,001 $7,443,577 $8,105,708 $6,657,455 $4,662,967 $2,761,843 $652,159 $855,203 $3,869,618 $5,136,523
Lancaster MWh 1,757,338 167,558 164,154 174,786 176,260 197,492 174,557 182,460 71,443 121,401 18,649 133,513 175,065
Lancaster Fuel Cost $/MWh $31.68 $29.41 $31.01 $36.11 $37.87 $37.94 $37.31 $30.19 $26.03 $21.90 $35.10 $24.93 $26.56
Lancaster Fuel Cost $55,670,517 $4,927,285 $5,090,973 $6,312,381 $6,675,239 $7,492,007 $6,513,327 $5,508,295 $1,859,650 $2,658,137 $654,610 $3,329,119 $4,649,492
Boulder Park MWh 106,416 14,450 10,134 9,883 10,595 14,352 8,244 6,630 2,680 2,803 2,243 9,572 14,828
Boulder Park Fuel Cost $/MWh $39.60 $33.36 $38.80 $46.80 $53.82 $42.52 $41.71 $37.53 $43.19 $34.51 $38.47 $33.94 $32.35
Boulder Park Fuel Cost $4,214,389 $482,040 $393,224 $462,529 $570,246 $610,321 $343,858 $248,823 $115,743 $96,746 $86,261 $324,844 $479,754
Kettle Falls CT MWh 31,594 4,240 3,079 2,959 2,921 3,815 2,499 2,304 870 936 592 2,903 4,476
Kettle Falls CT Fuel Cost $/MWh $46.43 $41.25 $45.47 $56.36 $60.47 $49.42 $46.76 $41.79 $49.20 $40.05 $50.68 $42.16 $38.92
Kettle Falls CT Fuel Cost $1,466,833 $174,894 $140,020 $166,738 $176,599 $188,522 $116,872 $96,293 $42,810 $37,503 $29,990 $122,374 $174,219
Rathdrum MWh 800,526 98,773 96,604 95,280 76,488 108,684 80,046 72,734 16,747 17,840 7,898 31,222 98,210
Rathdrum Fuel Cost $/MWh $48.46 $42.82 $45.40 $50.89 $65.36 $51.70 $44.41 $49.09 $58.26 $42.35 $49.24 $44.35 $41.53
Rathdrum Fuel Cost $38,791,961 $4,229,839 $4,385,783 $4,848,895 $4,999,331 $5,619,287 $3,554,966 $3,570,203 $975,641 $755,505 $388,854 $1,384,691 $4,078,964
Northeast MWh 0 0 0 0 0 0 0 0 0 0 0 0 0
Northeast Fuel Cost $/MWh #DIV/0!
Northeast Fuel Cost $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0
Total Fuel Expense $196,983,601 $18,271,135 $17,135,727 $21,768,397 $23,278,171 $26,215,676 $21,112,410 $18,247,944 $9,155,080 $6,391,728 $3,978,228 $12,771,894 $18,657,210
Net Fuel and Purchase Expense -$15,570,278
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 4, Page 2 of 2
Avista Corp
PCA Authorized Expense and Retail Sales (Annual)
Based on Pro forma 9/1/2023 - 8/31/2024
7/1/2021 - 6/30/2022 Historic Normalized Loads
PCA Authorized Power Supply Expense - System Numbers (1)
Total Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug
Account 555 - Purchased Power $104,521,277 $7,508,215 $6,908,554 $7,209,626 $9,346,250 $9,740,856 $9,151,262 $8,468,581 $8,126,508 $8,364,764 $8,253,615 $11,079,214 $10,363,832
Account 501 - Thermal Fuel $40,769,418 $3,212,651 $3,228,724 $3,193,852 $3,413,178 $4,199,830 $3,925,931 $4,161,363 $3,399,394 $2,191,678 $1,963,310 $3,741,248 $4,138,258
Account 537 - MT Invasive Species $780,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000
Account 547 - Natural Gas Fuel $167,284,818 $15,990,884 $14,834,086 $19,502,102 $20,794,907 $22,946,287 $18,105,067 $15,003,022 $6,664,922 $5,109,266 $2,922,593 $9,955,681 $15,456,001
Account 557 - Other Expenses $71,679,967 $5,973,331 $5,973,331 $5,973,331 $5,973,331 $5,973,331 $5,973,331 $5,973,331 $5,973,331 $5,973,331 $5,973,331 $5,973,331 $5,973,331
Account 565 - Transmission Expense $19,584,527 $1,630,441 $1,630,441 $1,630,441 $1,630,441 $1,632,845 $1,632,845 $1,632,845 $1,632,845 $1,632,845 $1,632,845 $1,632,845 $1,632,845
Account 456 - Other Revenue -$12,689,056 -$623,677 -$833,353 -$898,267 -$892,243 -$1,106,886 -$1,020,981 -$1,182,164 -$1,000,628 -$1,144,209 -$1,545,834 -$1,430,762 -$1,010,051
Account 447 - Sale for Resale -$212,900,464 -$25,749,986 -$11,876,355 -$15,190,036 -$17,748,350 -$15,949,645 -$13,438,229 -$12,918,947 -$12,398,731 -$16,911,017 -$13,749,735 -$31,442,366 -$25,527,065
Power Supply Expense $179,030,486 $8,006,859 $19,930,428 $21,486,049 $22,582,515 $27,501,618 $24,394,225 $21,203,030 $12,462,640 $5,281,658 $5,515,125 -$425,809 $11,092,150
Account 456 - Transmission Revenue (2)-$32,125,556 -$3,106,214 -$2,806,579 -$2,348,726 -$2,429,524 -$2,075,534 -$2,301,316 -$2,141,035 -$2,363,836 -$2,645,810 -$3,281,367 -$3,289,061 -$3,336,554
Total Authorized Expense $146,904,930 $4,900,645 $17,123,849 $19,137,323 $20,152,991 $25,426,084 $22,092,909 $19,061,995 $10,098,804 $2,635,848 $2,233,758 -$3,714,870 $7,755,596
Idaho Only (no adjustment for Directly assigned)$50,638,129 $1,689,252 $5,902,591 $6,596,635 $6,946,736 $8,764,371 $7,615,426 $6,570,670 $3,481,058 $908,577 $769,976 -$1,280,516 $2,673,354
PCA Authorized Idaho Retail Sales (3)
Total Idaho Retail Sales, MWh 3,082,930 304,450 275,917 276,088 250,222 227,023 225,845 256,211 254,893 218,497 235,421 260,464 297,899
2023 Load Change Adjustment Rate (4)$25.23 /MWh
2024 Load Change Adjustment Rate (4)$26.54 /MWh
(1) Multiply number by ROO current production/transmission allocation ratio of 34.47%
(2) Transmission Revenue as discussed by Company witness Mr. Dillon.
(3) Note totals may vary slightly from adjustment due to rounding.(4) Twelve months ended June 30, 2022 normalized monthly retail sales.
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 5, Page 1 of 2
Avista Corp
PCA Authorized Expense and Retail Sales (Annual)
Based on Pro forma 9/1/2024 - 8/31/2025
7/1/2021 - 6/30/2022 Historic Normalized Loads
PCA Authorized Power Supply Expense - System Numbers (1)
Total Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug
Account 555 - Purchased Power $119,698,083 $8,342,061 $8,027,256 $8,351,016 $9,868,026 $9,452,656 $9,184,588 $8,651,049 $10,036,182 $11,242,163 $10,880,167 $13,331,737 $12,331,181
Account 501 - Thermal Fuel $41,426,888 $3,858,553 $3,250,125 $3,220,420 $3,442,467 $4,079,664 $3,826,109 $4,221,935 $3,342,992 $2,235,276 $1,973,453 $3,783,614 $4,192,280
Account 537 - MT Invasive Species $780,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000 $65,000
Account 547 - Natural Gas Fuel $157,532,022 $14,975,940 $13,237,601 $17,070,538 $17,970,228 $21,769,323 $17,943,690 $14,879,623 $6,309,559 $5,070,446 $2,495,947 $10,134,412 $15,674,713
Account 557 - Other Expenses $85,249,910 $7,104,159 $7,104,159 $7,104,159 $7,104,159 $7,104,159 $7,104,159 $7,104,159 $7,104,159 $7,104,159 $7,104,159 $7,104,159 $7,104,159
Account 565 - Transmission Expense $21,127,837 $1,632,845 $1,632,845 $1,632,845 $1,632,845 $1,821,040 $1,821,040 $1,825,729 $1,825,729 $1,825,729 $1,825,729 $1,825,729 $1,825,729
Account 456 - Other Revenue -$12,793,860 -$1,019,613 -$1,081,470 -$1,012,993 -$1,217,461 -$1,114,416 -$919,335 -$1,204,339 -$818,677 -$957,852 -$1,416,513 -$1,174,753 -$856,439
Account 447 - Sale for Resale -$220,782,536 -$26,381,727 -$11,557,037 -$14,131,066 -$15,654,977 -$16,894,802 -$13,801,836 -$13,352,631 -$12,667,716 -$17,361,966 -$13,149,295 -$36,076,630 -$29,752,855
Power Supply Expense $192,238,345 $8,577,219 $20,678,481 $22,299,920 $23,210,288 $26,282,625 $25,223,416 $22,190,526 $15,197,229 $9,222,956 $9,778,647 -$1,006,731 $10,583,769
Account 456 - Transmission Revenue (2)-$31,245,955 -$2,932,581 -$2,633,014 -$2,161,321 -$2,242,072 -$2,050,372 -$2,276,154 -$2,114,499 -$2,347,424 -$2,629,398 -$3,264,955 -$3,272,649 -$3,321,516
Total Authorized Expense $160,992,390 $5,644,638 $18,045,467 $20,138,599 $20,968,216 $24,232,253 $22,947,262 $20,076,027 $12,849,805 $6,593,558 $6,513,692 -$4,279,380 $7,262,253
Idaho Only (no adjustment for Directly assigned)$55,494,077 $1,945,707 $6,220,272 $6,941,775 $7,227,744 $8,352,858 $7,909,921 $6,920,206 $4,429,328 $2,272,800 $2,245,270 -$1,475,102 $2,503,299
PCA Authorized Idaho Retail Sales (3)
Total Idaho Retail Sales, MWh 3,082,930 304,450 275,917 276,088 250,222 227,023 225,845 256,211 254,893 218,497 235,421 260,464 297,899
2023 Load Change Adjustment Rate (4)$25.23 /MWh
2024 Load Change Adjustment Rate (4)$26.54 /MWh
(1) Multiply number by ROO current production/transmission allocation ratio of 34.47%
(2) Transmission Revenue as discussed by Company witness Mr. Dillon.
(3) Note totals may vary slightly from adjustment due to rounding.(4) Twelve months ended June 30, 2022 normalized monthly retail sales.
Exhibit No. 7 Case No. AVU-E-23-01 & AVU-G-23-01 C. Kalich, Avista
Schedule 5, Page 2 of 2