20100413Revised Direct, Exhibits.pdf

Avista Corp.
1411 East Mission P.O. Box 3727
Spokane. Washington 99220-0500
Telephone [phone]
Toll Free 800-727-9170
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~~I'V'STA.
Corp.
ZOln APR' 3 At~ 10: 29
April 12,2010
Jean D. Jewell
Commssion Secretar
Idaho Public Utilities Commssion
472 W. Washington St.
Boise, il 83702
RE: TariffI.P.U.C. No. 28 (Electric) and TariffI.P.U.C. No. 27 (Natural Gas)
Docket Nos. A VU-E-10-01 and A VU-G-10-01
Avista hereby encloses for filing an original and nine copies of the REVISED Andrews Testimony (page 8),
Johnson Testimony (pages 3, 6, 7, and 12) and Johnson Exhibit 6, Schedules 1, 3, and 4. On March 23, 2010,
Avista filed with the Commssion the original Andrew's Testimony, Johnson Testimony and Johnson Exhibit 6,
Schedule 1,3, and 4. The revised Testimony and Schedules reflex corrected data to the pro-forma power supply
numbers originally fied, but do not otherwise change the requested level of overall revenue requirement. Each
changed page is labeled "REVISED APRI 12,2010" and is shown in legislative style with each change marked.
Computer-readable copies of the testimony and exhibits are also included on the attached compact disc. A paper
copy of all documents along with a CD containing the revised testimony and exhibits have been included for the
Cour Reporter.
Questions regarding this fiing should be directed to Paul Kimball at [phone].
Sincerely,7~~~
Kelly Norwood
VP, State & Federal Regulation
Enclosures
cc: See attached service list
REC:E
iOlU APR 13 Ali 10= 29
10 PJ¡ 0 ,'Li.i' it .i. .... . ......... .;
I HEREBY CERTIFY that I have this 25th day of March, ~81b':I~:;~àl":¡m~:;~::U;\
foregoing application, and Avista's Direct Testimony and Exhibits in Docket No.
AVU-E-10-01 and AVU-G-10-01 upon the following parties, by mailng a copy
thereof, property addressed with postage prepaid to:
CERTIFICATE OF SERVICE
Jean D Jewell, Secretary
Idaho Public Utilities Commission
Statehouse
Boise, ID 83720-5983
Brad M. Purdy
Attorney at Law
2019 N 1 ih Street
Boise,ID 83720
Donald L. Howell,1I
Kristine A. Sasser
Deputy Attorney
Idaho Public Utilities Commission
472 W. Washington
Boise,ID 83702-0659
Peter J. Richardson
Richardson & O'Leary PLLC
515 N. 2ih Street
Boise, ID 83702
Howard Ray
Clearwater Paper
803 Mil Road
P.O. Box 1126
Lewiston, ID 83501-1126
Dean J. Miler
McDevitt & Miler, LLP
420 W. Bannock St.
Boise, ID 83701-2564
Scott Atkison
Idaho Forest Products
171 Highway 95 N.
Grangevile, ID 83530
Larry Crowley
Energy Strategies Institute
5549 South Cliffs Edge Avenue
Boise, ID 83716
paç:~s~
Rates Coordinator
CASE NO. AVU-E-10-Ol
CASE NO. AVU-G-10-Ol
CORRECTED PAGE (8)
TO ELIZABETH M. ANREWS DIRECT TESTIMONY
(Marked)
REVISED APRIL 12, 2010
1
2
categories,such as distribution expenses,customer
service,and administrati ve and general,,totals
3 approximately 8% of the overall request.
4 Q.Could you please provide additional details
5 related to the changes in production and Transmission
6 expense?
7 A.Yes.As discussed in Company witness Mr.
8 Johnson's testimony, the level of Idaho's share of power
9 supply expense has increased by approximately $17.Q million
10 ($50.2 million on a system basis) from the level currently
11 in base rates.
12 The primary expense increases are the addition of the
13 Lancaster plant, from which the Company began receiving
14 power on January 1, 2010, and the expiration of four low-
15 cost power supply contracts. The increase in pro forma net
16 expense related to the inclusion of the Lancaster plant is
17 approximately $21.3 million (system) or $7.5 million (Idaho
18 share). With regard to the power contracts, there are four
19 low-cost 25 aMW power purchases that end December 31, 2010.
20 The cost to replace these power purchase agreements
21 increases Idaho expense by $3.6 million.Mr. Johnson
22 discusses each of the increased expenses in detail in his
23 testimony.
Andrews, Di 8
Avista Corporation
CASE NO. AVU-E-10-Ol p,i:rç/'i/\""Vi¡ú..1î -¡¡
lOiD APR f 3 AM 10: 30
CORRECTED PAGES (3, 6, 7, and
TO WILLIAM G. JOHNSON DIRECT TESTIMONY
(Marked)
REVISED APRI 12, 2010
1 the 2009 calendar-year test period and the pro forma period
2 October 2010 to September 2011.The table below shows
3 total net power supply expense during the test period and
4 the pro forma period.For information purposes only, the
5 power supply expensel currently in rates, which is based on
6 a July 2009 through June 2010 pro forma period, is also
7 shown.
Idaho
System Allocation
Power Supply Expense in Current Base Rates $169,037,000
Actual Jan 09 - De 09 Power Supply Expense $189,811,000
Adjustment to Test Period $29,376,000 $10,319,789
Proposed Pro forma Power Supply Expense $219,187,000
Increase frm Expense in Current Rates $50,150,000 $17,617,6958
9 The net effect of my adjustments to the test year
10 power supply expense is an increase of $29,376,000
11 ($219,187,000 - $189,811,000) on a system basis. The Idaho
12 allocation of this adjustment of $10,319,789 is
13 incorporated into the revenue requirement calculation for
14 the Idaho jurisdiction by Company witness Ms. Andrews.
15 The increase in power supply expense compared to the
16 authorized level in current base rates is $50,150,000
17 (system) and $17, 617,695 (Idaho allocation) .
1 For the remainder of
my testiony, for puroses of the power supply adjustment, I will refer to the net of
power supply revenues and expenses as power supply expense for ease of reference.
Johnson, Di 3
Avista Corporation
REVISED APRI 12, 2010
1 expiration of a load following contract with NorthWestern
2 Energy along with other contract volume and price changes.
3 Higher fuel prices increases power supply expense by
4 $5.3 million (Idaho allocation). This impact is the sum of
5 higher natural gas fuel prices ($4.1 million) and higher
6 net costs at Colstrip and Kettle Falls ($1. 2 million).
7 Natural gas prices in this pro forma are $6. 26/dth
8 (Stanfield) compared to $4. 79/dth in the current base
9 rates.
10 A reduction in retail loads reduces power supply
11 expense by $2.1 million (Idaho allocation). Pro forma
12 system loads are 13.5 aMW lower than loads that current
13 rates are based on. Most of this increase is mitigated by
14 the production property adjustment so the net impact of
15 lower retail loads is small.
16 The table below shows the primary factors driving the
17 increase in power supply expense compared to the level in
18 current base rates.
Johnson, Di 6
Avista Corporation
REVISED APRI 12,2010
Power Supply Expense Change
Oct 10-Sep-11 Pro forma vs. Current Authorized
Lancaster $21.3 $7.5
Decreased System Load -$6.0 -$2.1
Low Cost 100 MW Purchase Ends $10.3 $3.6
Reduced Hydro Generation $7.1 $2.5
Colstnp and Kettle Falls Fuel $3.5 $1.2
Purchase Contracts $2.1 $0.7
Higher Natural Gas Pnces $11.8 $4.1
Total Power Supply Increase $50.1 $17.61
2
3 III. PRO FORM POWER SUPPLY EXPENSE ADSTMS
4 Overview
5 Q.Please identify the specific power supply cost
6 i tams that are covered by your testimony and the total
7 adjustment being proposed.
8 A.Exhibit No.6, Schedule 1 identifies the power
9 supply expense and revenue items that fall wi thin the scope
10 of my testimony.These revenue and expense i ters are
11 related to power purchases and sales, fuel expenses,
12 transmission expense, and other miscellaneous power supply
13 expenses and revenues.
14 Q.What is the basis for the adjustments to the test
15 period power supply revenues and expenses?
Johnson, Di 7
Avista Corporation
REVISED APRI 12,2010
1 New Authorized Power Supply and Transmission Expense
2 Q.What is the authorized power supply expense and
3 revenue proposed by the Company for the PCA?
4
5
A.The proposed authorized level of annual system
power supply expense is $200,570,792.This is the sum of
6 Accounts 555 (Purchased power), 501 (Thermal Fuel), 547
7 (Fuel), less Account 447 (Sale for Resale). The proposed
8 level of Transmission Expense is $17, 64~, 340 . The proposed
9 level of Transmission Revenue is $12,388,460.
10 The level of retail sales and the retail revenue
11 credit will also be updated. The proposed authorized level
12 of retail sales to be used in the PCA is the October 2009
13 through September 2011 pro forma retail sales.The
14 proposed retail revenue credit is $50. 26/MW, which is the
15 average cost of production/transmission in this filing.
16 The proposed authorized monthly PCA expense and
17 revenue is shown in Exhibit 6, Schedule 4.
18 Q.Does that conclude your pre-filed direct
19 testimony?
20 A. Yes.
Johnson, Di 12
Avista Corporation
REVISED APRIL 6, 2010
~¡ l,. L
555 PURCHASED POWER
1 Modeled Short-Term Market Purchases $0 $31,363 $31,363
2 Actual ST Market Purchases - Physical 198,063 -198,063 0
3 Rocky Reach 1,658 439 2,097
4 Wanapum 4,989 -4,989 0
5 Wells - Avista Share 1,412 140 1,552
6 Wells - Colvile Tribe's Share 11,202 -11,202 0
7 Priest Rapids Project 4,999 692 5,691
8 Grant Displacement 5,333 326 5,659
9 Douglas Settlement 365 219 584
10 Lancaster Capacity Payment 0 20,999 20,999
11 Lancaster Variable O&M Payments 0 2,555 2,555
12 Lancaster BPA Reserves 0 744 744
13 WNP-3 14,078 -1,825 12,253
14 Deer Lake-IP&L 7 0 7
15 Small Power 904 115 1,019
16 Stimson 1,865 300 2,165
17 Spokane-Upriver 1,792 211 2,003
18 Douglas Exchange Capacity 1,511 -1,511 0
19 Seattle Exchange Capacity 1,535 -1,535 0
20 Black Creek Index Purchase 139 -5 134
21 Non-Monetary -142 142 0
22 Contract A 6,789 -5,077 1,712
23 Contract B 6,745 -5,044 1,701
24 Contract C 6,657 -4,978 1,679
25 Contract D 7,556 -5,651 1,905
26 Northwestern Deviation Energy 1,661 -1,661 0
27 BPA NT Deviation Energy 1,101 -1,101 0
28 Clearwater Paper Co-Gen Purchase 19,413 -19,413 0
29 Spinning Reserve Purchase 622 0 622
30 Ancillary Services 686 -686 0
31 Stateline Wind Purchase 2,846 685 3,531
32 Total Account 555 303,786 -203,811 99,975
557 OTHER EXPENSES
33 Broker Commission Fees 124 0 124
34 REC Purchases 350 0 350
35 Natural Gas Fuel Purchases 32,480 -32,480 0
36 Total Account 557 32,954 -32,480 474
501 THERMAL FUEL EXPENSE
37 Kettle Falls - Wood Fuel 7,450 2,830 10,280
38 Kettle Falls - Start-up Gas 47 0 47
39 Colstrip - Coal 13,336 7,012 20,348
40 Colstip - Oil 113 85 198
41 Total Account 501 20,946 9,927 30,873
547 OTHER FUEL EXPENSE
42 Coyote Springs Gas 57,429 -2,651 54,778
43 CS2 Gas Transportation Charge 6,832 1,052 7,884
44 Lancaster Gas 0 57,669 57,669
45 Lancaster Gas Transportation Charge 0 6,014 6,014
46 Lancaster Gas Transportation Optimization 0 -392 -392
47 Rathdrum Gas 2,628 -2,285 343
48 Northeast CT Gas 3 73 76
49 Boulder Park Gas 1,461 -1,276 185
50 Kettle Falls CT Gas 303 -101 202
51 Total Account 547 68,656 58,102 126,758 Exhibit NO.6
Case No. AVU-E-10-01
W. Johnson, Avista
Schedule 1, p. 1 of 2
Avista Corp.
Power Supply Pro forma -Idaho Jurisdiction
System Numbers. Jan 2009 - Dec 2009 Actual and Oct 2010 - Sep 2011 Pro Forma
Jan 09 - Dec 09 Oct 10.-. S.!R ~Q /\....r../.,....O '.'. '.'.::.'~. 'ii;; \;~ (;
Actuals Adjustment Pro fg~ii\T\!:' (') \"t)f;",.i ¡'V'"
'lorn ~PR \ 3 I\M l\: 43
Line
No.
REVISED APRIL 6, 2010
CE.,
Line
No.
Avista Corp.
Power Supply Pro forma - Idaho Jurisdiction
System Numbers - Jan 2009 . Dec 2009 Actual and Oct 2010 - Sep 2011 Pro Forma .' . ' r.
\f\,L'J'.¡U.".#.. .''' ..,0,,Oct 10 - Sep nT\UTI\:':~J
Adjustment Pro forma ,.
in\o APR \ 3 AM \\: 43
Jan 09 - Dec 09
Actuals
565 TRANSMISSION OF ELECTRICITY BY OTHERS
52 WNP-3 789 0 789
53 Sand Dunes-Warden 13 0 13
54 Black Creek Wheeling 25 -4 21
55 Wheeling for System Sales & Purchases 332 0 332
56 PTP Transmission for Colstrip & Coyote 8,432 -2 8,430
57 PTP Transmission for Lancaster 0 4,503 4,503
58 Redirected Lancaster Transmission 0 -241 -241
59 BPA Townsend-Garrison Wheeling 1,173 0 1,173
60 Avista on BPA - Borderline 1,530 0 1,530
61 Kootenai for Worley 45 0 45
62 Sagle-Northern Lights 140 0 140
63 Garrison-Burke 226 44 270
64 PGE Firm Wheeling 647 -4 643
65 Total Account 565 13,352 4,296 17,648
536 WATER FOR POWER
66 Headwater Benefits Payments 716 7 723
549.MISC OTHER GENERATION EXPENSE
67 Rathdrum Municipal Payment 160 0 160
68 ITOTAL EXPENSE 440,570 -163,960 276,6101
447 SALES FOR RESALE
69 Modeled Short-Term Market Sales 0 45,214 45,214
70 Actual ST Market Sales - Physical 158,707 -158,707 0
71 Peaker (PGE) Capacity Sale 1,748 0 1,748
72 Nichols Pumping Sale 1,642 1,511 3,153
73 Sovereign/Kaiser DES 511 -432 79
74 Pend Oreile DES & Spinning 613 -154 459
75 Northwestern Load Following 4,554 -3,556 998
76 NaturEner 313 -313 0
77 SMUD Sale 27,648 -22,265 5,383
78 Ancillary Services 686 -686 0
79 BPA NT Deviation Energy 1,233 -1,233 0
80 Total Account 447 197,655 -140,621 57,034
456 OTHER ELECTRIC REVENUE
81 Renewable Energy Credit Sales 144 -144 0
82 Gas Not Consumed Sales Revenue 33,137 -33,137 0
83 Total Account 456 33,281 -33,281 0
453 SALES OF WATER AND WATER POWER
84 Upstream Storage Revenue 381 -20 361
454 MISC RENTS
85 Colstrip Rents 29 0 29
86 ITOTAL REVENUE 231,346 -173,922 57,4241
87 ITOTAL NET EXPENSE 209,224 9,963 219,1871
88 Clearwater Paper Purchase Assigned to Idaho 19,413
89 Total Adjustment Including Clearwater Paper 29,376
Exhibit NO.6
Case No. AVU-E-10-01
W. Johnson, Avista
Schedule 1, p. 2 of 2
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