20090415Wright Direct.pdf

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zmBflPR 15 PH 12: 04
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF IDAHO POWER COMPAN FOR )
AUTHORITY TO IMPLEMENT POWER )
COST ADJUSTMENT ("PCA") RATES FOR ) CASE NO. IPC-E-09-11
ELECTRIC SERVICE FROM JUNE 1, )
2009, THROUGH MAY 31, 2010. )
)
IDAHO POWER COMPAN
DIRECT TESTIMONY
OF
SCOTT WRIGHT
1 Q.Please state your name and business address.
2 A.My name is Scott Wright. My business
3 address is 1221 West Idaho Street, Boise, Idaho.
4 Q.By whom are you employed and in what
5 capacity?
6 A.I am employed by Idaho Power Company (the
7 "Company") as a Pricing Analyst.
8 Q.Please describe your educational background.
9 A.I received a Bachelor of Science degree in
10 Business Economics from Eastern Oregon University. I have
11 attended the Center for Public Utilities College of
12 Business Administration and Economics Practical Skills for
13 a Changing Electric course in Albuquerque, New Mexico.
14 Q.Please describe your work experience.
15 A.In May 1998, I accepted a position as
16 Research Assistant with Idaho Power Company in the Pricing
17 and Regulatory Services Department. In March 2007, I was
18 promoted to a Pricing Analyst. As a Pricing Analyst, I am
19 responsible for running the AURORAmp model to calculate
20 the Net Power Supply Expense ("NPSE") for ratemaking
21 purposes, the Oregon Power Cost Adjustment ("PCA")
22 calculations, and the marginal cost of energy used in the
23 Company's Marginal Cost Analysis. I also provide
WRIGHT, DI 1
Idaho Power Company
1 analytical support for other regulatory acti vi ties wi thin
2 the Pricing and Regulatory Services Department.
3 Q.What is the scope of your testimony in this
4 proceeding?
5 A. My testimony is divided into several
6 sections. The first section of my testimony describes the
7 changes in the PCA base as a result of Order No. 30722
8 issued in Case No. IPC-E-08-10, the Company's general rate
9 case, and Order No. 30715 issued in Case No. IPC-E-08-19,
10 the PCA methodology case. The next section quantifies the
11 proj ection of PCA expense using the methodology approved in
12 Order No. 30715. The final section quantifies the True-Up
13 and the True-Up of the True-Up, resulting in a final PCA
14 rate.
15 Q.Please describe the components of the PCA
16 base.
17 A. The PCA base is comprised of the following
18 FERC accounts: FERC account 501, fuel (coal); FERC account
19 536, water for power; FERC account 547, fuel (gas); FERC
20 account 555, purchased power (both PURPA and non-PURPA
21 purchases); FERC account 565, transmission of electricity
22 by others; and FERC account 447, sales for resale
23 (typically referred to as surplus sales).
WRIGHT, DI 2
Idaho Power Company
1 Q.Have any PCA base accounts changed from last
2 year as a result of changes in PCA methodology approved in
3 Order No. 30715?
4 A.Yes. FERC account 565, transmission of
5 electricity by others, is a new PCA base account. When
6 Idaho Power purchases transmission wheeling from other
7 companies, it is because wheeling is required to facilitate
8 ei ther purchases or sales of energy. Wi thin FERC account
9 555, purchases of energy from other utilities to replace
10 losses associated with the wheeling of energy on their
11 system were previously excluded from PCA tracking. With
12 the inclusion of FERC Account 565 in the PCA, it was also
13 determined that the purchase of energy to replace these
14 losses should be included.
15 Q.Did Order No. 30715 change the sharing
16 percentage for any of the PCA base accounts?
17 A.Yes. The sharing percentage was changed so
18 customers now take a 95 percent share of some PCA base
19 accounts. Customers are still responsible for 100 percent
20 of PURPA expenses.
21 Q.Please quantify the amounts included in the
22 new PCA base from which deviations are to be tracked based
23 on customers taking a 95 percent share.
WRIGHT, DI 3
Idaho Power Company
1 A.Order No. 30722 issued in Case No. IPC-E-08-
2 10, the Company's last general rate case, quantified PCA
3 base amounts from which deviations are to be tracked at 95
4 percent for customer responsibility as follows:
5 account 501, coal $133,454,723
6 account 536, water for power $ 67,519
7 account 547, gas $ 6,125,180
8 account 555, non PURPA $ 57,231,921
9 account 565, transmission $ 10,469,726
10 account 447, surplus sales $116,568,567
11 Net of 95 percent accounts $ 90,780,502
12 Q.Please quantify the amounts included in the
13 new PCA base from which deviations are to be tracked based
14 upon a 100 percent customer sharing percentage.
15 A.Order No. 30722 quantified PCA base amounts
16 from which deviations are to be tracked at 100 percent for
17 customer responsibility as follows:
18 account 555, PURPA $ 63,269,889
19 Q.Did Order No. 30715 change the way the
20 Company calculated this year's projection of PCA expenses
21 for the April 2009 through March 2010 time period?
22 A.Yes. Order No. 30715 allows the Company to
23 utilize the results of its most recent Operating Plan as
24 the basis for the April proj ection of PCA expenses. This
WRIGHT, DI 4
Idaho Power Company
1 method replaces the previous method which was based upon
2 inserting a Brownlee runoff forecast into a regression
3 formula derived from rate case data. The Company's most
4 recent Operating Plan was reviewed by the Company's Risk
5 Management Committee on March 26, 2009, and was presented
6 to the Customer Advisory Committee on March 31, 2009.
7 Q.Please quantify the amounts included in the
8 PCA proj ection for which deviations from base are to be
9 tracked based upon a 95 percent customer sharing
10 percentage.
11 A.Based upon the March 26,2009,Operating
12 Plan,the PCA proj ection of amounts for which deviations
13 from base are to be tracked at 95 percent for customer
14 responsibility is as follows:
15 account 501,coal $152,223,739
16 account 536,water for power $2,000,000
17 account 547,gas $17,382,025
18 account 555,non PURPA $87,943,236
19 account 565,transmission $8,451,318
20 account 447,surplus sales $59,622,584
21 Net of 95 percent accounts $208,377,734
22 Q.Does the recently approved Hoku special
23 contract impact PCA compu ta t ions?
WRIGHT, DI 5
Idaho Power Company
1 A.Yes. Order No. 30748 approved the Energy
2 Sales Agreement between Idaho Power and Hoku, which
3 provides that the Hoku first block revenues are to be
4 reflected in PCA computations as if they were surplus
5 sales. The March 26, 2009, Operating Plan reflects Hoku
6 loads that would generate $18,539,291 of Hoku first block
7 revenues. Subtracting this amount from the $208,377,734
8 results in an adjusted net of $189,838,443.
9 Q.What is the difference between the Operating
10 Plan amount of $189,838,443 and the $90,780,502 PCA base
11 amount from the last general rate case?
12 A. The difference between $189,838,443 and
13 $90,780,502 is $99,057,941.
14 Q. What is the Operating Plan quantification of
15 PURPA expenses anticipated from April 2009 through March
16 2010?
17 A.The March 26, 2009, Operating Plan
18 anticipates $51,767,620 of PURPA expenses during the April
19 2009 through March 2010 time period.
20 Q.How does this amount compare to the base
21 level of PURPA expenses quantified in the last general rate
22 case?
WRIGHT, DI 6
Idaho Power Company
1 A.The Operating Plan quantification of PURPA
2 expenses is $11,502,269 below the $63,269,889 quantified in
3 the Company's last general rate case.
4 Q.What is the rate for the proj ection portion
5 of the PCA for April 2009 through March 2010?
6 A.The rate for the projection portion of the
7 PCA is equal to the sum of: (1) 95 percent of the
8 difference between the non-PURPA expenses quantified in the
9 Operating Plan and those quantified in the Company's last
10 general rate case and (2) 100 percent of the difference
11 between PURPA related expenses quantified in the Operating
12 Plan and those quantified in the Company's last general
13 rate case divided by (3) the Company's normalized system
14 firm sales.
15 The rate for non-PURPA expenses is 0.6451 cents per
16 kWh, which is calculated by multiplying $99,057,941 by 95
17 percent and then dividing it by the normalized system firm
18 sales of 14,586,634 MWh ((99,057,941 * .95) /14,586,634).
19 The rate for PURPA expenses is negative 0.0789 cents per
20 kWh, which is calculated by dividing negative $11,502,269
21 by the normalized system firm sales of 14,586,634 MWh. The
22 projection portion of the PCA rate is 0.5662 cents per kWh,
23 which is calculated by adding 0.6451 cents per kWh with a
24 negative 0.0789 cents per kWh.
WRIGHT, DI 7
Idaho Power Company
1 Q.Please describe the True-Up portion of the
2 PCA rate.
3 A.The True-Up portion of the PCA rate starts
4 wi th the Deferral Expense Report. The Deferral Expense
5 Account Report is attached as Exhibit NO.1. This report
6 compares actual PCA account results to last year's PCA
7 account proj ections on a monthly basis, with the
8 differences accumulated as the deferral balance. The
9 balance at the end of March 2009, with interest applied,
10 was $107,891,769, as shown on row 84 of Exhibit NO.1.
11 Q.Were there anyone-time adjustments to the
12 PCA True-Up balances in the April 2008 through March 2009
13 time frame?
14 A.Yes. There was an adj ustment for the sale
15 of S02 credits, which reduces the True-Up amount by
16 $4,591,632.
17 Q. What is this year's True-Up rate?
18 A. This year's True-Up component of the PCA is
19 $103,300,137. The True-Up is computed by reducing the
20 deferral balance of $107,891,769 by the proceeds from the
21 sale of S02 credits of $4,591,632. The revised deferral
22 balance of $103,300,137 divided by the Company's projected
23 Idaho jurisdictional sales of 13,838,689 MWh results in a
24 rate of 0.7465 cents per kWh.
WRIGHT, DI 8
Idaho Power Company
1 Q.What is this year's True-Up of the True-Up
2 rate?
3 A.The Company under collected this year's PCA
4 True-Up balance by $22,003,335, as shown on row 103 of the
5 Deferral Expense Account Report. The True-Up of the True-
6 Up rate is calculated by dividing $22,003,335 by the
7 projected 2009 Idaho jurisdictional sales of 13,838,689
8 MWh, which results in 0.1590 cents per kWh.
9 Q.What is the resulting PCA rate when you
10 combine all of the described components?
11 A.The Company's PCA rate for the 2009/2010 PCA
12 year is 1.4717 cents per kWh. The rate is comprised of:
13 (1) the 0.5662 cents per kWh adjustment for the 2009/2010
14 projected power cost of serving firm loads under the
15 current PCA methodology and 95 percent sharing, (2) the
16 0.7465 cents per kWh for the 2008/2009 True-Up portion of
17 the PCA, and (3)the 0.1590 cents per kWh for the True-Up of
18 the True-Up. The components used to calculate the 1.4717
19 cents per kWh are shown in Attachment No. 1 of the
20 Application, the Company's proposed Schedule 55.
21 Q.How does the new PCA rate of 1.4717 cents
22 per kWh compare to the existing PCA rate?
WRIGHT, DI 9
Idaho Power Company
1 A.The 2009/2010 rate of 1.4717 cents per kWh
2 is 0.6853 cents per kWh higher than the 0.7864 cents per
3 kWh currently in place for all customers.
4 Q.What is the overall percentage increase in
5 the Company's Idaho Jurisdictional revenues as a result of
6 the PCA increase?
7 A.The overall Idaho Jurisdictional revenues
8 must increase by 11.40 percent from the current levels in
9 order for the Company to recover its PCA related Power
10 Supply Expenses during the June 2009 through May 2010 time
11 frame.
12 Q.What factors have contributed to the
13 increase in this year's PCA rate as compared to the
14 previous year's PCA rate?
15 A.There are three primary factors driving the
16 increase in the 2009/2010 PCA rate. First, the Company's
17 projected NPSE is significantly higher than the current
18 base NPSE. This is due to the proj ected below normal
19 streamflow conditions in 2009 as compared to the normal
20 streamflow conditions that served as the basis for the
21 2008/2009 PCA rate. Furthermore, the projected NPSE
22 includes the combination of higher fuel costs and lower
23 revenue from surplus sales as compared to the base levels.
WRIGHT, DI 10
Idaho Power Company
1 Second, the proposed PCA rate was developed
2 according to the modified forecasting methodology approved
3 in Order No. 30715. Because the modified forecasting
4 methodology more accurately projects the Company's NPSE,
5 the impact of lower than normal streamflow conditions is
6 better reflected in the forecast, as opposed to being
7 captured in the following year's True-Up. Finally, last
8 year's projected NPSE was set at the base level NPSE¡
9 however, the actual NPSE for the period was considerably
10 higher than the base level, resulting in the current True-
11 Up balance.
12 Q.Should the IPUC Commission approve the
13 Company's computation of the PCA rate?
14 A.Yes. The IPUC Commission should approve the
15 Company's computation of the PCA rate. The calculation of
16 the PCA rate follows the methodology that was approved in
17 Order No. 30715. Furthermore, the proposed PCA rate will
18 more closely align actual revenues with actual costs as
19 they occur.
20 Q.Does this conclude your testimony?
21 A.Yes.
WRIGHT, DI 11
Idaho Power Company
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-09-11
IDAHO POWER COMPANY
WRIGHT, 01
TESTIMONY
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