20150601Johnson Exhibit 6.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-15-05
OF AVISTA CORPORATION FOR THE )
AUTHORITY TO INCREASE ITS RATES )
AND CHARGES FOR ELECTRIC AND )
NATURAL GAS SERVICE TO ELECTRIC ) EXHIBIT NO. 6
AND NATURAL GAS CUSTOMERS IN THE )
STATE OF IDAHO ) WILLIAM G. JOHNSON
)

FOR AVISTA CORPORATION

(ELECTRIC ONLY)

Avista Corp.
Power Supply Pro forma - Idaho Jurisdiction
System Numbers - Jan 2014 - Dec 2014 Actual and Jan 2016 - Dec 2016 Pro Form
Line Jan 14 - Dec 14 Jan 16 - Dec 16
No.Actual Adjustment Pro Forma
555 PURCHASED POWER
1 Modeled ST Market Purchases $0 $10,975 $10,975
2 Actual ST Market Purchases 98,836 -98,836 0
3 Rocky Reach/Rock Island Purchase 12,320 93 12,413
4 Wells - Avista Share 1,678 168 1,846
5 Wells - Colville Tribe's Share 4,887 -4,887 0
6 Priest Rapids Project 6,818 1,114 7,932
7 Douglas Settlement 1,081 -91 990
8 Lancaster Capacity Payment 22,333 697 23,030
9 Lancaster Variable O&M Payments 2,398 780 3,178
10 WNP-3 14,986 2,589 17,575
11 Deer Lake-IP&L 4 3 7
12 Small Power 1,425 51 1,476
13 Stimson 1,654 474 2,128
14 Spokane-Upriver 2,158 605 2,763
15 Spokane Waste-to-Energy 6,389 61 6,450
16 Non-Monetary 145 -145 0
17 Ancillary Services 927 -927 0
18 Palouse Wind 18,786 1,611 20,397
19 Stateline Wind Purchase 866 -866 0
20 Total Account 555 197,691 -86,532 111,159
557 OTHER EXPENSES
21 Broker Commission Fees 614 0 614
22 WA EIA REC Purchase - 100% WA Allocation 735 -735 0
23 Optional Renewable Power Expense Offset -33 33 0
24 Natural Gas Fuel Purchases 85,747 -85,747 0
25 Total Account 557 87,063 -86,449 614
501 THERMAL FUEL EXPENSE
26 Kettle Falls - Wood Fuel 6,035 -464 5,571
27 Kettle Falls - Start-up Gas 15 0 15
28 Colstrip - Coal 20,896 3,515 24,411
29 Colstrip - Oil 333 0 333
30 Total Account 501 27,279 3,050 30,329
547 OTHER FUEL EXPENSE
31 Coyote Springs Gas 41,343 -7,410 33,933
32 Coyote Springs 2 Gas Transportation 6,503 633 7,136
33 Lancaster Gas 34,176 -1,297 32,879
34 Lancaster Gas Transportation 5,622 173 5,795
35 Gas Transport Optimization 0 -8,936 -8,936
36 Gas Transportation for BP, NE and KFCT 40 0 40
37 Imbalance and Tax Adjustment -61 61 0
38 Rathdrum Gas 583 441 1,024
39 Northeast CT Gas 102 -72 30
40 Boulder Park Gas 578 19 597
41 Kettle Falls CT Gas 207 -29 178
42 Total Account 547 89,093 -16,417 72,676
565 TRANSMISSION OF ELECTRICITY BY OTHERS
43 WNP-3 943 -31 912
44 Short-term Transmission Purchases 31 30 61
45 BPA PTP for Colstrip, Coyote & Lancaster 13,834 -2,001 11,833
Exhibit No. 6
Case No. AVU-E-15-05 W. Johnson, Avista
Schedule 1, p. 1 of 4
Avista Corp.
Power Supply Pro forma - Idaho Jurisdiction
System Numbers - Jan 2014 - Dec 2014 Actual and Jan 2016 - Dec 2016 Pro Form
Line Jan 14 - Dec 14 Jan 16 - Dec 16
No.Actual Adjustment Pro Forma
46 BPA Townsend-Garrison Wheeling 1,499 9 1,508
47 Avista on BPA - Borderline 1,325 0 1,325
48 Kootenai for Worley 45 0 45
49 Sagle-Northern Lights 140 0 140
50 Northwestern for Colstrip 436 0 436
51 PGE Firm Wheeling 643 0 643
52 Total Account 565 18,896 -1,993 16,903
536 WATER FOR POWER
53 Headwater Benefits Payments 983 18 1,001
54 TOTAL EXPENS 421,005 -188,323 232,682
447 SALES FOR RESALE
55 Modeled Short-Term Market Sales 0 36,191 36,191
56 Actual ST Market Sales 126,022 -126,022 0
57 Peaker (PGE) Capacity Sale 1,749 17,529 19,278
58 Nichols Pumping Sale 1,641 -251 1,390
59 Sovereign/Kaiser DES 98 58 156
60 Pend Oreille DES & Spinning 451 119 570
61 SMUD Sale/Energy America 20,000 -10,806 9,194
62 Intracompany Generation 927 -927 0
63 Total Account 447 150,888 -84,108 66,780
456 OTHER ELECTRIC REVENUE
64 Non WA EIA REC Sales 4,006 -1,217 2,789
65 WA EIA REC Sales 163 -163 0
66 Gas Not Consumed Sales Revenue 87,122 -87,122 0
67 Total Account 456 91,291 -88,502 2,789
453 SALES OF WATER AND WATER POWER
68 Upstream Storage Revenue 475 -9 466
69 TOTAL REVENU 242,654 -172,620 70,034
70 TOTAL NET EXPENS 178,351 -15,703 162,648
-8.80%
Exhibit No. 6
Case No. AVU-E-15-05 W. Johnson, Avista
Schedule 1, p. 2 of 4
Avista Corp.
Power Supply Pro forma - Idaho Jurisdiction
System Numbers - Jan 2014 - Dec 2014 Actual and Jan 2017 - Dec 2017 Pro Form
Line Jan 14 - Dec 14 Jan 16 - Dec 16
No.Actual Adjustment Pro Forma
555 PURCHASED POWER
1 Modeled ST Market Purchases $0 $8,979 $8,979
2 Actual ST Market Purchases 98,836 -98,836 0
3 Rocky Reach/Rock Island Purchase 12,320 1,553 13,873
4 Wells - Avista Share 1,678 168 1,846
5 Wells - Colville Tribe's Share 4,887 -4,887 0
6 Priest Rapids Project 6,818 1,543 8,361
7 Douglas Settlement 1,081 -92 989
8 Lancaster Capacity Payment 22,333 989 23,322
9 Lancaster Variable O&M Payments 2,398 924 3,322
10 WNP-3 14,986 3,054 18,040
11 Deer Lake-IP&L 4 3 7
12 Small Power 1,425 47 1,472
13 Stimson 1,654 255 1,909
14 Spokane-Upriver 2,158 703 2,861
15 Spokane Waste-to-Energy 6,389 138 6,527
16 Non-Monetary 145 -145 0
17 Ancillary Services 927 -927 0
18 Palouse Wind 18,786 1,936 20,722
19 Stateline Wind Purchase 866 -866 0
20 Total Account 555 197,691 -85,461 112,230
557 OTHER EXPENSES
21 Broker Commission Fees 614 0 614
22 WA EIA REC Purchase - 100% WA Allocation 735 -735 0
23 Optional Renewable Power Expense Offset -33 33 0
24 Natural Gas Fuel Purchases 85,747 -85,747 0
25 Total Account 557 87,063 -86,449 614
501 THERMAL FUEL EXPENSE
26 Kettle Falls - Wood Fuel 6,035 74 6,109
27 Kettle Falls - Start-up Gas 15 0 15
28 Colstrip - Coal 20,896 1,743 22,639
29 Colstrip - Oil 333 0 333
30 Total Account 501 27,279 1,817 29,096
547 OTHER FUEL EXPENSE
31 Coyote Springs Gas 41,343 -3,152 38,191
32 Coyote Springs 2 Gas Transportation 6,503 633 7,136
33 Lancaster Gas 34,176 2,712 36,888
34 Lancaster Gas Transportation 5,622 173 5,795
35 Gas Transport Optimization 0 -9,877 -9,877
36 Gas Transportation for BP, NE and KFCT 40 0 40
37 Imbalance and Tax Adjustment -61 61 0
38 Rathdrum Gas 583 736 1,319
39 Northeast CT Gas 102 -51 51
40 Boulder Park Gas 578 203 781
41 Kettle Falls CT Gas 207 29 236
42 Total Account 547 89,093 -8,533 80,560
565 TRANSMISSION OF ELECTRICITY BY OTHERS
43 WNP-3 943 -31 912
44 Short-term Transmission Purchases 31 30 61
45 BPA PTP for Colstrip, Coyote & Lancaster 13,834 -2,001 11,833
Exhibit No. 6
Case No. AVU-E-15-05 W. Johnson, Avista
Schedule 1, p. 3 of 4
Avista Corp.
Power Supply Pro forma - Idaho Jurisdiction
System Numbers - Jan 2014 - Dec 2014 Actual and Jan 2017 - Dec 2017 Pro Form
Line Jan 14 - Dec 14 Jan 16 - Dec 16
No.Actual Adjustment Pro Forma
46 BPA Townsend-Garrison Wheeling 1,499 9 1,508
47 Avista on BPA - Borderline 1,325 0 1,325
48 Kootenai for Worley 45 0 45
49 Sagle-Northern Lights 140 0 140
50 Northwestern for Colstrip 436 0 436
51 PGE Firm Wheeling 643 0 643
52 Total Account 565 18,896 -1,993 16,903
536 WATER FOR POWER
53 Headwater Benefits Payments 983 18 1,001
54 TOTAL EXPENS 421,005 -180,601 240,404
447 SALES FOR RESALE
55 Modeled Short-Term Market Sales 0 38,936 38,936
56 Actual ST Market Sales 126,022 -126,022 0
57 Peaker (PGE) Capacity Sale 1,749 -1,749 0
58 Nichols Pumping Sale 1,641 -91 1,550
59 Sovereign/Kaiser DES 98 58 156
60 Pend Oreille DES & Spinning 451 119 570
61 SMUD Sale/Energy America 20,000 -9,987 10,013
62 Intracompany Generation 927 -927 0
63 Total Account 447 150,888 -99,663 51,225
456 OTHER ELECTRIC REVENUE
64 Non-WA EIA REC Sales 4,006 -1,217 2,789
65 WA EIA REC Sales 163 -163 0
66 Gas Not Consumed Sales Revenue 87,122 -87,122 0
67 Total Account 456 91,291 -88,502 2,789
453 SALES OF WATER AND WATER POWER
68 Upstream Storage Revenue 475 -9 466
69 TOTAL REVENU 242,654 -188,174 54,480
70 TOTAL NET EXPENS 178,351 7,573 185,924
4.25%
Exhibit No. 6
Case No. AVU-E-15-05 W. Johnson, Avista
Schedule 1, p. 4 of 4

Avista Corp. Brief Description of Power Supply Adjustments

Line No.
1 Modeled Short-term Market Purchases - Short-term purchases from the
AURORA Dispatch Simulation Model.
2 Actual ST Market Purchases – Expense of the actual term physical and
financial power transactions in test-year. Actual transactions not included in
the pro forma.

3 Rocky Reach/Rock Island Purchase – The pro forma expense is based on a purchase of a portion of Rocky Reach and Rock Island generation. The
current contract ends 12-31-2020.

4 Wells – Avista Share - Wells’ costs are based on the Company's 3.34% share
of total project costs.
5 Wells – Colville Tribe’s Share - The test-year expense is based on a purchase
of the Colville Indian Tribe’s portion of the Wells’ dam generation. The
current contract ended 3-31-15.
6 Priest Rapids Project - Priest Rapids Project expense includes the expense
related to the purchased power from the Priest Rapids development and power
from the Wanapum development.

7 Douglas Settlement – Douglas Settlement is for power Avista purchases from Douglas PUD per the 1989 Settlement Agreement.

8 Lancaster Capacity Payment – The Lancaster capacity payment includes a
capital payment and a fixed O&M payment.
9 Lancaster Variable O&M Payments – the Lancaster variable O&M payment
is based on the variable O&M rate in the Lancaster Power Purchase
Agreement multiplied time the MWh of Lancaster generation in the pro forma.

10 WNP-3 - The pro forma uses the actual midpoint of the ceiling and floor prices identified in the contract for contract year 2014-2015 escalated at
inflation to the pro forma period.

11 Deer Lake-IP&L - Pro forma expense is for power purchased from Inland
Power to serve Avista customers.
Exhibit No. 6
Case No. AVU-E-15-05
W. Johnson, Avista
Schedule 2, Page 1 of 6

12 Small Power – Pro forma costs are based on 5-year average generation and an
average contract rate.

13 Stimson – This purchase is from the cogeneration plant at Plummer, Idaho. Pro forma costs are based on 5-year average generation and pro forma period
contract rates.

14 Spokane-Upriver – Pro forma expense is based on a purchase of the
generation, net of pumping (at the plant) at the pro forma contract rate.
15 Spokane Waste-to-Energy - Pro forma expense is based on average
generation and the pro forma period contract rate.

16 Non-Monetary - Expense is normalized to $0 in the pro forma.
17 Ancillary Services – Pro forma expense is $0 because this is an intra-utility
expense (matching revenue in Account 447).

18 Palouse Wind – Pro forma expense is based on the expected generation and the contract rate in the pro forma year, including the apprenticeship credit.

19 Stateline Wind Purchase – Pro forma expense is $0 because the contract
ended 3-31-14.

20 Total Account 555
21 Broker Commission Fees – Pro forma expense is associated with purchases
and sales of electricity and natural gas fuel.
22 WA EIA REC Purchases – Pro forma expense is $0 because the contract for
REC purchases ended 12-31-15 and is 100% allocated to Washington.

23 Optional Renewable Power Expense Offset – This test year credit was to
remove the REC cost of the Stateline Wind purchase that was assigned to the Buck-a-Block program. The pro forma credit is $0 because the Stateline Wind
purchase ended 3-31-14.
24 Natural Gas Fuel Purchases – This is the expense for natural gas purchased for but not consumed for generation. Pro forma expense is $0 because all gas
purchased is assumed to be used for generation, and included in Account 547.

25 Total Account 557
26 Kettle Falls Wood Fuel Cost – Pro forma fuel expense is based on the
generation of the Kettle Falls plant in the AURORA Model and the unit cost
of available fuel.
Exhibit No. 6
Case No. AVU-E-15-05
W. Johnson, Avista
Schedule 2, Page 2 of 6

27 Kettle Falls-Start-up Gas – Pro forma expense is for start-up gas at Kettle
Falls and is based on the test-year expense.
28 Colstrip Coal Cost – Pro forma fuel expense is based on the generation of the
Colstrip plant in the AURORA Model and the unit cost of fuel under the
contract.

29 Colstrip Oil – Pro forma expense is for start-up oil expense. Pro forma is based on the test-year expense.

30 Total Account 501

31 Coyote Springs Gas – Pro forma expense is an output of the AURORA Model based on the pro forma unit cost of fuel and the dispatch of the plant,
which determines the volume of fuel consumed.

32 CS2 Gas Transportation – This expense is for natural gas transportation for
the Coyote Springs 2 plant.
33 Lancaster Gas - Pro forma expense is an output of the AURORA Model
based on the pro forma unit cost of fuel and the dispatch of the plant, which
determines the volume of fuel consumed.
34 Lancaster Gas Transportation – This expense is for natural gas
transportation for the Lancaster plant.

35 Gas Transportation Optimization - This credit to expense is based on
optimizing the gas transportation contracts for Coyote Springs 2 and Lancaster. In general, this involves trading the gas price spread between
AECO (Canada) and Malin.

36 Gas Transportation for BP, NE and KFCT – This expense is for
transportation of natural gas to serve Boulder Park, Northeast and Kettle Falls Combustion Turbine gas-fired plants.

37 Imbalance and Tax Adjustment – This is a test-year only expense to adjust
gas-fuel expense.
38 Rathdrum Gas – Pro forma expense is an output of the AURORA Model
based on the pro forma unit cost of fuel and the dispatch of the plant, which
determines the volume of fuel consumed.

39 Northeast CT Gas – Pro forma expense is an output of the AURORA Model based on the pro forma unit cost of fuel and the dispatch of the plant which
determines the volume of fuel consumed.
Exhibit No. 6
Case No. AVU-E-15-05
W. Johnson, Avista
Schedule 2, Page 3 of 6

40 Boulder Park Gas – Pro forma expense is an output of the AURORA Model
based on the pro forma unit cost of fuel and the dispatch of the plant which
determines the volume of fuel consumed.
41 Kettle Falls CT Gas – Pro forma expense is an output of the AURORA
Model based on the pro forma unit cost of fuel and the dispatch of the plant,
which determines the volume of fuel consumed.

42 Total Account 547
43 WNP-3 Transmission – Pro forma WNP-3 wheeling is based on 32.22 MW
at a rate of $2.36/kW/mo.
44 Wheeling for System Sales and Purchases – Pro forma expense is for short-
term transmission purchases.

45 PTP for Colstrip and Coyotes Springs 2 and Lancaster– This wheeling is
for the transmission of 196 MW from Colstrip, 272 MW from Coyote Springs 2 and 100 MW from Lancaster. Pro forma expense is based on 568 MW of
capacity at a rate of $1.736/kW/mo.

46 BPA Townsend-Garrison Wheeling – This expense is for the transmission of Colstrip power from the Townsend substation to the Garrison substation.

47 Avista on BPA Borderline – This expense is to serve Avista load off of BPA
transmission. Expense is based on Avista’s borderline loads priced at BPA’s
NT transmission rates plus ancillary services cost and use of facilities charges. 48 Kootenai for Worley – This expense is for Avista load served using
Kootenai’s facilities.

49 Sagle-Northern Lights – Expense is for transmission purchased from Northern Lights Utility to serve Avista customers.
50 Northwestern for Colstrip – Northwestern for Colstrip wheeling is an
expense for the transmission of Colstrip energy above 196 MW from the
Garrison substation over Northwestern Energy’s transmission system to the interconnection of Northwestern Energy and Avista. 51 PGE Firm Wheeling – PGE Firm wheeling reflects the cost of transmission
from the John Day substation to COB (Intertie South) purchased from Portland
General Electric. 52 Total Account 565
Exhibit No. 6
Case No. AVU-E-15-05
W. Johnson, Avista
Schedule 2, Page 4 of 6

53 Headwater Benefits Expense - Pro forma expense is based on the expense for
contract year September 2014 through August 2015.

54 Total Expenses – Sum of Accounts 555, 557, 501, 547, 565, 536, and 549.
55 Modeled Short-Term Market Sales - Short-term market sales from the
AURORA Model simulation.

56 Actual ST Market Sales - Physical – Revenue from the actual short-term sales in the test-year. Actual sales are not included in the pro forma.

57 Peaker (PGE) Capacity Sale – This pro forma revenue is based on 150 MW
of capacity at the full contract rate.
58 Nichols Pumping Sale – This is a sale of energy to other Colstrip Units 3 and
4 owners at the Mid-Columbia index price less $2.16/MWh. Pro forma
revenue is based on approximately 7 aMW at the market price (less
$2.16/MWh) as determined by the AURORA model.
59 Sovereign/Kaiser DES – This contract provides load control services to
Kaiser’s Trentwood plant. A new contract began 10-1-2015.

60 Pend Oreille DES & Spinning Reserves – This contract provides load
regulation and reserves for Pend Oreille PUD. A new contract began 10-1-2015.

61 SMUD Sale (Energy America) – The SMUD contract ended 12-31-2014.
Pro forma revenue includes 35 aMW of an energy sale at the Mid C index plus
$3/MWh, plus 15 aMW of the Mid C to COB margin of $3/MWh.
62 Intercompany Generation – Pro forma revenue is $0 because it is intra-
utility revenue (matching expense in Account 555).

63 Total Account 447
64 Non WA EIA REC Sales – REC revenue in the pro forma year.

65 WA EIA REC Sales – Pro forma revenue is $0 because WA EIA compliant
RECs are not being sold in the pro forma period and would be 100% allocated to Washington.
66 Gas Not Consumed Sales Revenue - This is the revenue for natural gas
purchased, but not consumed for generation. Pro forma revenue is $0 because
all gas purchased is assumed to be used for generation, and included in Account 547.
Exhibit No. 6
Case No. AVU-E-15-05
W. Johnson, Avista
Schedule 2, Page 5 of 6

67 Total Account 456
68 Upstream Storage Revenue – Pro forma revenue is based on the revenue for
contract year September 2014 through August 2015.
69 Total Revenue – Sum of Accounts 447, 456, 453 and 454.

70 Total Net Expense – Total expense minus total revenue.

Exhibit No. 6
Case No. AVU-E-15-05
W. Johnson, Avista
Schedule 2, Page 6 of 6
Avista Corp.
Market Purchases and Sales, Plant Generation and Fuel Cost Summary
Idaho Pro Forma January 2016 - December 2016
744 696 743 720 744 720 744 744 720 744 721 744
Total Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16
Market Sales - Dollars -$36,191,247 -$3,268,102 -$2,300,929 -$2,629,925 -$4,186,063 -$4,187,893 -$2,687,482 -$3,513,152 -$1,453,008 -$2,351,977 -$2,176,556 -$3,496,646 -$3,939,513
Market Sales - MWh (1,585,379) -115,528 -85,088 -105,855 -206,207 -250,552 -197,846 -148,967 -52,656 -86,638 -83,387 -124,839 -127,817Average Market Sales Price -$/ MWh $22.83 $28.29 $27.04 $24.84 $20.30 $16.71 $13.58 $23.58 $27.59 $27.15 $26.10 $28.01 $30.82
Market Purchases - Dollars $10,974,600 $684,498 $1,029,987 $798,135 $181,939 $66,814 $364,880 $1,091,496 $2,328,879 $1,090,925 $1,314,496 $1,037,210 $985,340
Market Purchases - MWh 376,752 26,351 40,261 33,886 9,153 3,801 15,315 31,710 74,828 36,132 42,027 32,732 30,554Average Market Purchase Price - $/MWh $29.13 $25.98 $25.58 $23.55 $19.88 $17.58 $34.42 $31.12 $30.19 $31.28 $31.69 $32.25
Net Market Purchases (Sales) MWh -1,208,627 -89,176 -44,826 -71,969 -197,054 -246,750 -182,530 -117,257 22,173 -50,506 -41,360 -92,107 -97,263Net Market Purchases (Sales) aMW -138.0 -120 -64 -97 -274 -332 -254 -158 30 -70 -56 -128 -131
Average Sale and Purchase Price - $/MWh $24.04 $27.86 $26.57 $24.53 $20.28 $16.73 $14.32 $25.49 $29.67 $28.04 $27.84 $28.77 $31.10
Colstrip MWh 1,567,995 143,992 134,547 139,988 114,327 97,295 89,264 133,416 141,985 140,608 145,761 141,248 145,563
Colstrip Fuel Cost $/MWh $15.57 $15.06 $15.39 $15.21 $16.33 $17.46 $18.16 $15.51 $15.14 $15.16 $14.99 $15.13 $15.00Colstrip Fuel Cost $24,410,569 $2,167,951 $2,070,527 $2,129,526 $1,866,457 $1,698,803 $1,621,334 $2,068,793 $2,150,227 $2,131,845 $2,184,357 $2,137,718 $2,183,031
Kettle Falls MWh 259,491 27,192 24,001 21,322 16,477 13,628 2,460 19,587 24,988 25,014 27,619 27,551 29,652Kettle Falls Fuel Cost $/MWh $21.47 $21.27 $21.39 $21.61 $22.47 $22.42 $21.57 $21.45 $21.37 $21.24 $21.14 $21.10
Kettle Falls Fuel Cost $5,570,606 $578,378 $513,410 $460,833 $370,279 $305,464 $54,431 $422,440 $535,944 $534,681 $586,600 $582,398 $625,749
Coyote Springs MWh 1,598,018 172,949 151,376 145,472 103,785 61,752 43,842 110,146 146,668 154,359 158,949 169,251 179,468
Coyote Springs Fuel Cost $/MWh $21.23 $21.92 $21.82 $21.51 $19.45 $19.52 $19.80 $20.57 $20.69 $20.56 $20.59 $21.81 $23.30Coyote Springs Fuel Cost $33,932,586 $3,790,617 $3,302,559 $3,129,559 $2,018,361 $1,205,498 $868,235 $2,266,149 $3,034,247 $3,173,140 $3,272,174 $3,690,732 $4,181,315
Lancaster MWh 1,534,293 166,416 145,710 141,001 101,571 60,058 44,625 101,896 135,459 145,977 159,960 160,983 170,637
Lancaster Fuel Cost $/MWh $21.43 $22.13 $22.09 $21.76 $19.73 $19.72 $20.03 $20.78 $20.89 $20.73 $20.72 $21.94 $23.47
Lancaster Fuel Cost $32,879,217 $3,683,264 $3,218,085 $3,068,820 $2,004,365 $1,184,315 $894,068 $2,117,229 $2,830,358 $3,026,513 $3,314,865 $3,532,651 $4,004,683
Boulder Park MWh 21,363 2,430 1,803 711 397 395 790 2,706 3,538 2,698 1,988 1,969 1,937Boulder Park Fuel Cost $/MWh $27.96 $29.15 $28.98 $28.70 $25.76 $25.74 $25.93 $26.96 $27.14 $26.94 $27.32 $28.84 $31.10
Boulder Park Fuel Cost $597,397 $70,832 $52,253 $20,392 $10,236 $10,164 $20,480 $72,962 $96,014 $72,696 $54,321 $56,798 $60,250
Kettle Falls CT MWh 6,641 527 426 77 8 112 366 999 1,639 1,032 535 416 503
Kettle Falls CT Fuel Cost $/MWh $26.83 $28.20 $27.91 $28.14 $24.92 $24.98 $25.11 $26.09 $26.30 $26.09 $26.47 $27.93 $30.12Kettle Falls CT Fuel Cost $178,156 $14,873 $11,878 $2,180 $206 $2,796 $9,203 $26,081 $43,111 $26,926 $14,153 $11,608 $15,143
Rathdrum MWh 28,024 4,021 2,828 109 0 259 1,994 3,718 7,416 3,392 1,428 1,229 1,630Rathdrum Fuel Cost $/MWh $36.54 $36.80 $36.59 $38.75 $34.12 $33.72 $35.74 $35.95 $36.21 $37.75 $39.88 $41.19
Rathdrum Fuel Cost $1,024,134 $147,987 $103,497 $4,234 $0 $8,834 $67,225 $132,875 $266,632 $122,812 $53,904 $49,001 $67,133
Northeast MWh 747 179 81 0 0 5 156 66 91 62 62 14 31
Northeast Fuel Cost $/MWh $39.74 $41.56 $41.17 $37.47 $37.28 $38.72 $38.88 $38.66 $39.08 $41.37 $45.68Northeast Fuel Cost $29,678 $7,424 $3,342 $0 $0 $198 $5,810 $2,569 $3,555 $2,378 $2,407 $594 $1,403
Total Fuel Expense $98,622,342 $10,461,326 $9,275,550 $8,815,544 $6,269,903 $4,416,071 $3,540,786 $7,109,098 $8,960,087 $9,090,990 $9,482,780 $10,061,500 $11,138,708
Net Fuel and Purchase Expense $73,405,694
Exhibit No. 6
Case No. AVU-E-15-05 W. Johnson, Avista
Schedule 3, p. 1 of 2
Avista Corp.
Market Purchases and Sales, Plant Generation and Fuel Cost Summary
Idaho Pro Forma January 2017 - December 2017
744 672 743 720 744 720 744 744 720 744 721 744
Total Jan-17 Feb-17 Mar-17 Apr-17 May-17 Jun-17 Jul-17 Aug-17 Sep-17 Oct-17 Nov-17 Dec-17
Market Sales - Dollars -$38,935,954 -$3,379,723 -$2,582,210 -$3,088,498 -$4,295,436 -$5,730,247 -$3,565,064 -$3,290,679 -$1,045,609 -$2,274,533 -$1,944,964 -$3,873,854 -$3,865,137
Market Sales - MWh (1,416,284)-99,876 -82,111 -106,670 -178,249 -267,765 -188,260 -113,143 -30,312 -67,455 -59,662 -116,646 -106,136Average Market Sales Price -$/ MWh $27.49 $33.84 $31.45 $28.95 $24.10 $21.40 $18.94 $29.08 $34.50 $33.72 $32.60 $33.21 $36.42
Market Purchases - Dollars $8,979,094 $499,604 $719,402 $591,310 $112,657 $7,087 $38,934 $1,027,920 $2,452,710 $1,024,042 $1,025,859 $569,587 $909,982
Market Purchases - MWh 308,002 21,204 28,824 25,379 5,939 358 1,706 32,893 83,075 34,009 31,145 16,527 26,943Average Market Purchase Price - $/MWh $29.15 $23.56 $24.96 $23.30 $18.97 $19.78 $31.25 $29.52 $30.11 $32.94 $34.46 $33.77
Net Market Purchases (Sales) MWh -1,108,282 -78,672 -53,288 -81,291 -172,309 -267,407 -186,554 -80,250 52,763 -33,445 -28,516 -100,119 -79,193Net Market Purchases (Sales) aMW -126.5 -106 -79 -109 -239 -359 -259 -108 71 -46 -38 -139 -106
Average Sale and Purchase Price - $/MWh $27.79 $32.04 $29.76 $27.87 $23.93 $21.40 $18.97 $29.57 $30.85 $32.51 $32.72 $33.37 $35.88
Colstrip MWh 1,571,225 144,334 129,966 141,000 114,252 100,058 91,862 133,715 142,154 140,969 145,858 141,385 145,672
Colstrip Fuel Cost $/MWh $14.41 $13.97 $14.42 $14.08 $15.07 $15.84 $16.43 $14.36 $14.06 $14.06 $13.92 $14.04 $13.93Colstrip Fuel Cost $22,639,048 $2,016,998 $1,873,613 $1,985,575 $1,722,091 $1,585,408 $1,509,185 $1,920,661 $1,998,094 $1,982,059 $2,030,398 $1,985,743 $2,029,224
Kettle Falls MWh 274,435 28,313 24,390 23,233 17,438 14,888 2,625 21,222 26,996 26,306 29,723 29,020 30,282Kettle Falls Fuel Cost $/MWh $22.26 $22.10 $22.20 $22.34 $23.25 $23.10 $22.31 $22.20 $22.19 $22.01 $21.95 $21.97
Kettle Falls Fuel Cost $6,108,534 $625,773 $541,461 $519,026 $405,520 $343,910 $60,087 $473,442 $599,326 $583,618 $654,098 $636,951 $665,321
Coyote Springs MWh 1,644,176 176,557 150,297 156,064 104,315 68,986 45,684 118,198 149,668 156,752 162,723 174,441 180,490
Coyote Springs Fuel Cost $/MWh $23.23 $23.73 $23.70 $23.33 $21.43 $21.58 $21.88 $22.59 $22.74 $22.64 $22.59 $24.02 $25.39Coyote Springs Fuel Cost $38,190,504 $4,189,095 $3,562,155 $3,641,591 $2,235,825 $1,488,937 $999,757 $2,670,687 $3,404,006 $3,548,988 $3,676,573 $4,189,966 $4,582,925
Lancaster MWh 1,573,037 167,153 143,808 149,712 102,760 67,166 47,205 108,188 138,742 148,751 162,964 163,788 172,801
Lancaster Fuel Cost $/MWh $23.45 $23.99 $23.98 $23.64 $21.70 $21.76 $22.12 $22.80 $22.96 $22.85 $22.78 $24.22 $25.59
Lancaster Fuel Cost $36,888,173 $4,010,476 $3,449,221 $3,539,166 $2,229,986 $1,461,597 $1,044,042 $2,466,366 $3,186,043 $3,399,111 $3,711,870 $3,967,600 $4,422,694
Boulder Park MWh 25,523 2,764 1,812 1,209 587 659 982 3,262 3,900 3,070 2,630 2,416 2,232Boulder Park Fuel Cost $/MWh $30.60 $31.62 $31.45 $31.02 $28.33 $28.41 $28.63 $29.58 $29.84 $29.74 $29.95 $31.85 $33.89
Boulder Park Fuel Cost $780,893 $87,411 $57,002 $37,500 $16,636 $18,714 $28,113 $96,468 $116,381 $91,280 $78,782 $76,964 $75,643
Kettle Falls CT MWh 8,010 601 423 119 19 203 432 1,264 1,819 1,193 734 563 640
Kettle Falls CT Fuel Cost $/MWh $29.46 $30.61 $30.47 $30.15 $27.40 $27.57 $27.76 $28.65 $28.94 $28.84 $29.03 $30.85 $32.85Kettle Falls CT Fuel Cost $235,946 $18,407 $12,884 $3,590 $520 $5,602 $11,989 $36,218 $52,635 $34,395 $21,315 $17,358 $21,034
Rathdrum MWh 32,856 4,245 2,427 320 7 534 2,070 4,991 8,172 3,978 2,242 1,572 2,297Rathdrum Fuel Cost $/MWh $40.16 $39.99 $40.02 $40.91 $38.66 $37.32 $37.37 $39.14 $39.59 $40.15 $41.20 $43.77 $44.40
Rathdrum Fuel Cost $1,319,378 $169,785 $97,117 $13,103 $285 $19,943 $77,369 $195,315 $323,572 $159,724 $92,356 $68,821 $101,988
Northeast MWh 1,183 222 75 0 0 29 231 160 178 128 77 22 60
Northeast Fuel Cost $/MWh $43.41 $45.38 $44.45 $41.33 $41.28 $42.44 $42.95 $42.73 $42.83 $45.81 $49.28Northeast Fuel Cost $51,362 $10,088 $3,350 $0 $0 $1,204 $9,545 $6,796 $7,660 $5,460 $3,314 $989 $2,956
Total Fuel Expense $106,213,839 $11,128,033 $9,596,803 $9,739,551 $6,610,862 $4,925,316 $3,740,087 $7,865,952 $9,687,716 $9,804,636 $10,268,706 $10,944,391 $11,901,785
Net Fuel and Purchase Expense $76,256,979
Exhibit No. 6
Case No. AVU-E-15-05 W. Johnson, Avista
Schedule 3, p. 2 of 2
Avista Corp
Pro forma January 2016 - December 2016
PCA Authorized Expense and Retail Sales
January 2014 - December 2014 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 $111,159,298 $12,161,272 $11,404,620 $9,963,402 $8,809,523 $6,740,586 $6,706,571 $7,374,163 $8,360,370 $7,222,858 $8,051,573 $11,904,606 $12,459,755
Account 501 - Thermal Fuel $30,329,175 $2,775,328 $2,612,937 $2,619,359 $2,265,736 $2,033,267 $1,704,765 $2,520,233 $2,715,171 $2,695,525 $2,799,957 $2,749,116 $2,837,780
Account 547 - Natural Gas Fuel $72,676,167 $8,051,247 $7,027,863 $6,561,435 $4,369,417 $2,748,054 $2,201,271 $4,954,115 $6,610,166 $6,760,714 $7,048,073 $7,677,634 $8,666,178
Account 447 - Sale for Resale $66,779,554 $5,920,050 $4,854,311 $5,165,161 $6,554,606 $6,515,727 $4,972,680 $6,095,109 $4,125,900 $4,959,989 $4,807,644 $6,125,690 $6,682,687
Power Supply Expense $147,385,086 $17,067,798 $16,191,109 $13,979,034 $8,890,069 $5,006,180 $5,639,927 $8,753,401 $13,559,807 $11,719,109 $13,091,960 $16,205,666 $17,281,025
Transmission Expense $16,903,007 $1,452,738 $1,372,806 $1,509,572 $1,336,193 $1,369,317 $1,346,174 $1,362,491 $1,404,564 $1,467,208 $1,430,341 $1,420,003 $1,431,599
Transmission Revenue $16,741,674 $1,405,733 $1,166,326 $1,222,888 $1,264,428 $1,579,616 $1,659,588 $1,679,720 $1,535,727 $1,376,848 $1,338,310 $1,287,627 $1,224,863
PCA Authorized Idaho Retail Sales (2)
Total January February March April May June July August September October November December
Total Retail Sales, MWh 3,072,989 299,392 263,761 268,236 243,401 234,981 228,959 249,355 246,161 197,872 249,356 287,858 303,659
Load Change Adjustment Rate $23.99 /MWh
1) Multiply system numbers by 35.29% to determine Idaho share.
2) 12 months ended December 2014 weather normalized Idaho retail sales.
Exhibit No. 6
Case No. AVU-E-15-05 W. Johnson, Avista
Schedule 4, p. 1 of 2
APPENDIX 1
Avista Corp
Pro forma January 2017 - December 2017
PCA Authorized Expense and Retail Sales
January 2014 - December 2014 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 $112,230,820 $12,130,228 $11,186,711 $10,062,611 $9,094,471 $7,127,475 $6,663,323 $7,534,677 $8,764,543 $7,318,010 $7,852,556 $11,761,192 $12,735,023
Account 501 - Thermal Fuel $29,095,582 $2,671,771 $2,444,074 $2,533,602 $2,156,611 $1,958,318 $1,598,272 $2,423,104 $2,626,420 $2,594,678 $2,713,495 $2,651,693 $2,723,545
Account 547 - Natural Gas Fuel $80,560,256 $8,743,096 $7,439,562 $7,492,783 $4,741,085 $3,253,831 $2,428,649 $5,729,682 $7,348,130 $7,496,792 $7,842,044 $8,579,531 $9,465,073
Account 447 - Sale for Resale $51,224,686 $4,511,738 $3,566,125 $4,103,494 $5,117,279 $6,537,573 $4,323,973 $4,335,371 $2,185,994 $3,360,608 $3,068,293 $4,998,689 $5,115,549
Power Supply Expense $170,661,973 $19,033,356 $17,504,222 $15,985,502 $10,874,887 $5,802,051 $6,366,271 $11,352,092 $16,553,099 $14,048,872 $15,339,803 $17,993,727 $19,808,092
Transmission Expense $16,902,539 $1,452,699 $1,372,767 $1,509,533 $1,336,154 $1,369,278 $1,346,135 $1,362,452 $1,404,525 $1,467,169 $1,430,302 $1,419,964 $1,431,560
Transmission Revenue $18,936,869 $1,405,733 $1,366,326 $1,422,888 $1,464,428 $1,779,616 $1,859,427 $1,879,559 $1,735,566 $1,575,687 $1,537,149 $1,486,627 $1,423,863
PCA Authorized Idaho Retail Sales (2)
Total January February March April May June July August September October November December
Total Retail Sales, MWh 3,072,989 299,392 263,761 268,236 243,401 234,981 228,959 249,355 246,161 197,872 249,356 287,858 303,659
Load Change Adjustment Rate $25.99 /MWh
1) Multiply system numbers by 35.29% to determine Idaho share.
2) 12 months ended December 2014 weather normalized Idaho retail sales.
Exhibit No. 6
Case No. AVU-E-15-05 W. Johnson, Avista
Schedule 4, p. 2 of 2