20100416Wright Direct.pdf

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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
ELECTRIC SERVICE FROM JUNE 1 i
2010 i THROUGH MAY 31 i 2011.
CASE NO. IPC-E-10-12
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 ("Idaho
7 Power" or "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 also attended the Center for Public Utili ties' "Practical
12 Skills for a Changing Electric Industry" course at New
13 Mexico State University 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 in the Pricing and
17 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 AURORAp model to calculate
20 net power supply expenses ("NPSE") for ratemaking purposes,
21 as well as the marginal cost of energy used in the
22 Company's marginal cost analysis. I also provide
23 analytical support for other regulatory activities within
WRIGHT, DI 1
Idaho Power Company
1 the Pricing and Regulatory Services Department, as well as
2 providing testimony in Company filings.
3 Q.What is the scope of your testimony in this
4 proceeding?
5 A.My testimony is divided into three sections.
6 In the first section of my testimony, i will provide my
7 determination of the PCA forecast rate using the 2008 PCA
8 base components approved in Order No. 30722, Case No. IPC-
9 E-08-10.
10 In the next section of my testimony, i will quantify
11 the True-Up and the True-Up of the True-Up, and combine
12 those amounts with the PCA forecast amount calculated from
13 the 2008 PCA base components. I provided these
14 computations to Mr. Tatum, who describes the PCA decrease
15 from the prior year in his testimony. Mr. Tatum also
16 describes the increase in base level power supply expenses
17 resulting from implementing the provisions of the
18 settlement Stipulation approved by Order No. 30978, Case
19 No. IPC-E-09-30 ("Stipulation").
20 In the final section of my testimony, I detail the
21 recalculation of the 2010 PCA forecast rate subsequent to
22 the increase to the base level NPSE provided to me by Mr.
23 Tatum. The 2010 PCA base level NPSE adjustment is based
24 upon the individual power supply cos t and revenue
WRIGHT, DI 2
Idaho Power Company
1 components approved per Order No. 31042, Case No. IPC-E-10-
2 01. This section combines the adjusted PCA forecast rate
3 using the 2010 PCA base components with the True-Up and the
4 True-Up of the True-Up resulting in a final PCA rate.
5 Q.Please describe the components of the PCA
6 base.
7 A. The PCA base is comprised of the following
8 FERC accounts: FERC Account 501, fuel (coal); FERC Account
9 536, water for power; FERC Account 547, fuel (gas); FERC
10 Account 555, purchased power (both PURPA and non-PURPA
11 purchases); FERC Account 565, transmission of electricity
12 by others; and FERC Account 447, sales for resale
13 (typically referred to as surplus sales).
14 PCA FORECAST USING 2008 PCA BASE COMPONENTS
15 Q.Please quantify the amounts described above
16 that are included in the PCA base from which deviations are
17 to be tracked based on customers receiving a 95 percent
18 share.
19 A.Order No. 30722 issued in Case No. IPC-E-08-
20 10, the Company's last general rate case, quantified PCA
21 base amounts from which deviations are to be tracked at 95
22 percent for customer responsibility as follows:
23 Account 501, coal $133,454,723
24 Account 536, water for power $67,519
WRIGHT, DI 3
Idaho Power Company
5
Account 547,gas $6,125,180
Account 555,non PURPA $57,231,921
Account 565,transmission $10,469,726
Account 447,surplus sales $116,568,567
Net of 95 percent accounts $90,780,502
1
2
3
4
6 Q.Please quantify the amounts included in the
7 PCA base from which deviations are to be tracked based upon
8 a 100 percent customer sharing percentage.
9 A.Order No. 30722 quantified PCA base amounts
10 from which deviations are to be tracked at 100 percent for
11 customer responsibility as follows:
12 Account 555, PURPA $ 63,269,889
13 Q.Please detail the amounts included in the
14 PCA proj ection for which deviations from base are to be
15 tracked based upon a 95 percent customer sharing
16 percentage.
17 A.Based upon the March 25, 2010, Operating
18 Plan, the PCA projection of amounts for which deviations
19 from base are to be tracked at 95 percent for customer
20 responsibility is as follows:
21 Account 501, coal $164,409,166
22 Account 536, water for power $ 2,003,640
23 Account 547, gas $ 12,854,025
24 Account 555, non PURPA $ 81,877,623
WRIGHT, DI 4
Idaho Power Company
1 Account 565, transmission $ 7,664,171
2 Account 447, surplus sales $ 62,915,788
3 Net of 95 percent accounts $205,892,837
4 Q.Does the recently approved Hoku special
5 contract impact PCA computations?
6 A.Yes. Order No. 30748 approved the Energy
7 Sales Agreement between Idaho Power and Hoku, which
8 provides that the Hoku first block revenues are to be
9 reflected in PCA computations as if they were surplus
10 sales. The March 25, 2010, Operating Plan reflects Hoku
11 loads that would generate $20,670,405 of Hoku first block
12 revenues. Subtracting this amount from the $205,892,837
13 results in an adjusted net of $185,222,432.
14 Q.Are there any other adjustments that impact
15 PCA computations?
16 A.Yes. The Operating Plan includes a forecast
17 of $7,606,860 for Renewable Energy Credits ("REC") and
18 Sulfur Dioxide (S02) benefits which further reduces this
19 year's PCA forecast. The actual REC and S02 benefits are
20 tracked in the monthly PCA deferral report filed with the
21 Commission. Subtracting this amount from the $185,222,432
22 results in an adjusted PCA forecast amount of $177,615,572.
WRIGHT, DI 5
Idaho Power Company
1 Q.What is the difference between the Operating
2 Plan amount of $177,615,572 and the $90,780,502 PCA base
3 amount from the last general rate case?
4 A. The difference between $177,615,572 and
5 $90,780,502 is $86,835,070.
6 Q. What is the Operating Plan quantification of
7 PURPA expenses anticipated from April 2010 through March
8 2011?
9 A.The March 25, 2010, Operating Plan
10 anticipates $64,054,993 of PURPA expenses during the April
11 2010 through March 2011 time period.
12 Q.How does this amount compare to the base
13 level of PURPA expenses quantified in the last general rate
14 case?
15 A.The Operating Plan quantification of PURPA
16 expenses is $785,104 above the $63,269,889 quantified in
17 the Company's last general rate case.
18 Q.What is the rate for the projection portion
19 of the PCA for April 2010 through March 2011?
20 A.The rate for the projection portion of the
21 PCA is equal to the sum of (1) 95 percent of the difference
22 between the non-PURPA expenses quantified in the Operating
23 Plan and those quantified in the Company's last general
24 rate case and (2) 100 percent of the difference between
WRIGHT, DI 6
Idaho Power Company
1 PURPA related expenses quantified in the Operating Plan and
2 those quantified in the Company's last general rate case,
3 divided by (3) the Company's normalized system firm sales.
4 The rate for non-PURPA expenses is 0.5814 cents per
5 kWh, which is calculated by multiplying $86,835,070 by 95
6 percent and then dividing it by the normalized system firm
7 sales of 14,188,579 MW ((86,835,070 * .95) /14,188,579).
8 The rate for PURPA expenses is 0.0055 cents per kWh, which
9 is calculated by dividing $785,104 by the normalized system
10 firm sales of 14,188,579 MW. The projection portion of
11 the PCA rate is 0.5869 cents per kWh, which is calculated
12 by adding 0.5814 cents per kWh with 0.0055 cents per kWh.
13 TRUE-UP AN TRUE-UP OF THE TRUE-UP
14 Q.Please describe the True-Up portion of the
15 PCA rate.
16 A.The True-Up portion of the PCA rate starts
17 with the Deferral Expense Account Report. The Deferral
18 Expense Account Report is attached as Exhibit No.1. This
19 report compares actual PCA account results to last year's
20 PCA account projections on a monthly basis, with the
21 differences accumulated as the deferral balance. The
22 balance at the end of March 2010, with interest applied,
23 was $11,963,777, as shown on row 78 of Exhibit No.1.
WRIGHT, DI 7
Idaho power Company
1 Q.What is this year's True-Up rate?
2 A.This year's True-Up component of the PCA is
3 $11,963,777 divided by the Company's projected Idaho
4 jurisdictional sales of 13,467,929 MW resulting in a rate
5 of 0.0888 cents per kWh.
6 Q.What is this year's True-Up of the True-Up
7 rate?
8 A.The Company under collected this year's PCA
9 True-Up balance by $11,284,407, as shown on row 97 of
10 Exhibit No.1, the Deferral Expense Account Report. The
11 True-Up of the True-Up rate is calculated by dividing
12 $11,284,407 by the projected 2010 Idaho jurisdictional
13 sales of 13,467,929 MW, which results in 0.0838 cents per
14 kWh.
15 Q.What is the resulting PCA rate when you
16 combine all of the described components?
17 A.The Company's PCA rate for the 2010/2011 PCA
18 year is 0.7595 cents per kWh. The rate is comprised of
19 (1) the 0.5869 cents per kWh adjustment for the 2010/2011
20 projected power cost of serving firm loads under the
21 current PCA methodology and 95 percent sharing, (2) the
22 0.0888 cents per kWh for the 2009/2010 True-Up portion of
23 the PCA, and (3) the 0.0838 cents per kWh for the True-Up
24 of the True-Up.
WRIGHT, DI 8
Idaho Power Company
1 Q.Have you calculated the PCA revenue increase
2 using the PCA rate that was quantified above?
3 A.Yes. The Company would expect to collect
4 $ 1 02 , 288 , 923 ( $ 0 . 007595 * 13, 467 , 929 , 266 kWh =
5 $102,288,923) using the 2008 PCA base components, absent
6 the Stipulation.
7 Q.Are there additional computations that must
8 be performed to determine this year's PCA rate?
9 A.Yes. The settlement Stipulation approved
10 per Order No. 30975, allows the Company to update the 2008
11 PCA base components to 2010 levels dependent upon the level
12 of PCA decrease from the prior year. The Idaho
13 jurisdictional PCA revenue of $102,288,923 using the 2008
14 PCA base components calculated above, was given to Mr.
15 Tatum, who then quantified the PCA reduction to be shared
16 by the Company and customers according to the Stipulation.
17 According to Mr. Tatum's application of the Stipulation's
18 sharing provisions, the Company will adjust the Idaho
19 jurisdictional base level NPSE by the full $63,701,694
20 increase approved by the Commission in Order No. 31042.
21 Q.What part of the jurisdictional base level
22 increase of $63,701,694, provided by Mr. Tatum, is related
23 to the increases in coal expense at the Bridger Coal
24 Company ("Bridger")?
WRIGHT, DI 9
Idaho Power Company
1 A.NPSE are modeled on a total system basis, so
2 the equivalent system numer matching the jurisdictional
3 increase of $63,701,694 provided by Mr. Tatum is
4 $66,719,746. The Bridger coal expense approved in the 2008
5 base level NPSE was $82.1 million, while the 2010 base
6 level NPSE is $106.9 million, an increase of $24.8 million.
7 The details surrounding the increase at Bridger are
8 detailed in Mr. Harvey's testimony.
9 PCA FORECAST USING 2010 PCA BASE COMPONENTS
10 Q.using the PCA base rate components, please
11 quantify the PCA base from which deviations are to be
12 tracked based on customers taking a 95 percent share
13 A.Order No. 31042 issued in Case No. IPC-E-10-
14 01 setting the Company's 2010 PCA components, quantified
15 PCA base amounts from which deviations are to be tracked at
16 95 percent for customer responsibility as follows:
22
Account 501,coal $167,718,084
Account 536,water for power $1,828,640
Account 547,gas $6,062,472
Account 555,non PURPA $66,689,601
Account 565,transmission $8,262,000
Account 447,surplus sales $92,642,114
Net of 95 percent accounts $157,918,683
17
18
19
20
21
23
WRIGHT, DI 10
Idaho Power Company
1 Q.Please quantify the amounts included in the
2 PCA base from which deviations are to be tracked based upon
3 a 100 percent customer sharing percentage.
4 A.Order No. 31042 quantified PCA base amounts
5 from which deviations are to be tracked at 100 percent for
6 customer responsibility as follows:
7 Account 555, PURPA $ 62,851,454
8 Q.How does the newly established base level
9 NPSE amount of $157,918,683 PCA compare to the Operating
10 Plan forecast for the test period?
11 A.As detailed earlier in my testimony, the
12 Operating Plan forecasts the PCA components which are
13 tracked for 95 percent sharing to be $177,615,572 for the
14 test period. The difference between $177,615,572 and the
15 new PCA base level NPSE amount of $157,918,683 is
16 $19,696,889.
17 Q.How does the Operating Plan quantification
18 of PURPA expenses compare to the base level of PURPA
19 expenses quantified from the 2010 PCA base components
20 approved per Order No. 31042 ?
21 A.The Operating Plan quantification of PURPA
22 expenses of $64,054,993 is $1,203,539 above the newly
23 established base level PURPA expenses of $62,851,454.
WRIGHT, DI 11
Idaho Power Company
1 Q.What is the rate for the proj ection portion
2 of the PCA for April 2010 through March 2011?
3 A.The rate for the proj ection portion of the
4 PCA is equal to the sum of (1) 95 percent of the difference
5 between the non-PURPA expenses quantified in the Operating
6 Plan and those quantified in the settlement stipulation and
7 (2) 100 percent of the difference between PURPA related
8 expenses quantified in the Operating Plan and those
9 quantified in the settlement stipulation, divided by (3)
10 the Company's normalized system firm sales.
11 The rate for non-PURPA expenses is 0.1319 cents per
12 kWh, which is calculated by multiplying $19,696,889 by 95
13 percent and then dividing it by the normalized system firm
14 sales of 14,188,579 MW ((19,696,889 * .95) /14,188,579).
15 The rate for PURPA expenses is 0.0085 cents per kWh, which
16 is calculated by dividing $1,203,539 by the normalized
17 system firm sales of 14,188,579 MW. The projection
18 portion of the PCA rate is 0.1404 cents per kWh, which is
19 calculated by adding 0.1319 cents per kWh with 0.0085 cents
20 per kWh.
21 Q.What is the resulting PCA rate when you
22 combine the PCA forecast using the updated 2010 PCA base
23 components approved in Order No. 31042, with the True-Up
24 and the True-Up of the True-Up?
WRIGHT, DI 12
Idaho Power Company
1 A.The Company's PCA rate for the 2010/2011 PCA
2 year is 0.3130 cents per kWh. The rate is comprised of:
3 (1) the 0.1404 cents per kWh adjustment for the 2010/2011
4 projected power cost of serving firm loads under the
5 current PCA methodology and 95 percent sharing, (2) the
6 0.0888 cents per kWh for the 2009/2010 True-Up portion of
7 the PCA, and (3)the 0.0838 cents per kWh for the True-Up of
8 the True-Up. The components used to calculate the 0.3130
9 cents per kWh are shown in Attachment No. 1 of the
10 Application, the Company's proposed Schedule 55.
11 Q.Have you calculated the PCA revenue using
12 the PCA rate that was quantified above?
13 A.Yes. The Company expects to collect
14 $ 4 2 , 154 , 618 ( $ 0 . 003130 * 13, 467 , 929 , 266 kWh = $ 4 2 , 154 , 618)
15 using the methodology approved under the Stipulation, per
16 Order No. 30975. This amount is $146,692,686 less than the
17 $188,847,304 that would be collected if the current rate of
18 1.4022 cents per kWh were to continue.
19 Q.Should the Commission approve the Company's
20 computation of the PCA rate?
21 A.Yes, the Commission should approve the
22 Company's computation of the PCA rate. The calculation of
23 the PCA rate follows the methodology that was approved in
24 Order Nos. 30715, 30975 and 31042.
WRIGHT, DI 13
Idaho Power Company
1 Q.
2 A.
Does this conclude your testimony?
Yes.
WRIGHT, DI 14
Idaho Power Company
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-10-12
IDAHO POWER COMPANY
WRIGHT, DI
TESTIMONY
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