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BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AUTHORITY TO IMPLEMENT POWER
COST ADJUSTMENT (PCA) RATES FOR
ELECTRIC SERVICE FROM JUNE 1
2006 THROUGH MAY 31 , 2007
CASE NO. IPC-06-
IDAHO POWER COMPANY
DIRECT TESTIMONY
CELESTE SCHWENDIMAN
please state your name and business address.
My name is Celeste Schwendiman and my
business address is 1221 West Idaho Street, Boise, Idaho.
By whom are you employed and in what
capaci ty?
I am employed by Idaho Power Company as a
Senior Pricing Analyst in the pricing and Regulatory
Services Department.
Please describe your educational background.
In 1993, I received a Bachelor of Arts in
Psychology from Eastern Oregon Uni versi ty.In 1998, I
attended the Center for Public Utili ties and National
Association of Regulatory Utility Commissioners Practical
Skills for a Changing Utility Environment conference.
2000, I received a Master s degree in Business
Administration from Northwest Nazarene University, and in
2004, I attended the Edison Electric Institute I s Electric
Rate Advanced Course.
Please describe your work experience with
Idaho Power Company.
I became employed by Idaho Power Company in
1997 as a Research Assistant II in the pricing & Regulatory
Services Department.I have been promoted as follows:
February 1998, Entry Analyst; August 1998, Analyst; and
July 2001, Senior Analyst.From 1998 through 2004, one of
SCHWENDIMAN, DI
Idaho Power Company
my responsibilities was to assist in the preparation of the
Power Cost Adjustment (PCA) filings.In 2005, I sponsored
Additionally, I havetestimony in the Company s PCA filing.
sponsored testimony in Case No. IPC-05-28, the general
revenue requirement filing currently before the Idaho Public
utili ties Commission.
What is this year I s projection of PCA
expense?
The proj ection of PCA expense for the period
April 1, 2006 through March 31, 2007 is $63,316,436.This
amount is $37 600,023 less than the $100,916,459 normalized
level of PCA expense that was included in the stipulation
accepted by all of the parties in the Company s general
The stipulationrevenue requirement Case No. IPC-05-28.
is currently being considered by the Commission.
What is the basis for the proj ection of
April 1, 2006 through March 31 , 2007 PCA expense?
The Commission, in Order No. 24806 issued in
Case No. IPC-92-25, the proceeding which created the PCA,
adopted a natural logarithmic function of proj ected April
through July Brownlee reservoir inflow to compute the
proj ection of April through March PCA expense.The equation
was updated to be consistent with the stipulation.The
present PCA regression equation is:
SCHWENDlMAN, DI
Idaho Power Company
137,165,252Annual PCA Expense
$70,733, 339*ln (Brownlee inflow)
$54,632,157
$1,004,538
$1, 900,000
This year s regression was based on the water years
used in the calculation of the 2003 test year normalized
power supply expense, updated with both costs and reduced
power supply expense for the Bennett Mountain power plant as
approved through Order No. 29790.Details of the regression
equation are contained in Exhibit
In this formula, the $1 137,165,252 is the constant
that represents the prediction of annual net power supply
expense that would occur if there was zero April through
July Brownlee reservoir inflow.For each unit increase in
the natural logarithm of the Brownlee reservoir inflow, the
proj ection of annual power supply expense will be reduced by
$70,733,339, the second of the constants in the equation
$54,632,157 forabove.The other three constants:
Qualifying Facilities (QF) purchase expense; $1,004,538 for
the cloud seeding program expense; and the $1,900,000 for
the associated benefit of the cloud seeding program, were
updated consistent with the stipulation.
What is the April through July Brownlee
reservoir inflow forecast that you used to arrive at the
SCHWENDlMAN, DI
Idaho Power Company
proj ection of PCA expense?
The National Weather Service s Northwest
River Forecast Center (NWRFC), in its official (final) April
forecast, proj ected April through July Brownlee reservoir
Inserting this valueinflow to be 8.38 million acre-feet.
into the equation results in a projection of net PCA expense
of $63,316,436 for the period April 1, 2006 through
This amount is $37,600,023 less than theMarch 31, 2007.
normalized level of PCA expense of $100,916,459.The
forecast information supplied by the NWRFC is contained on
Exhibi t 2.
You have stated that the projected net PCA
expense is less than the normalized level of PCA expense by
What is the rate adjustment associated with$37 600,023.
the proj ected decrease in PCA expense of $37 600,023 from
the normalized level of PCA expense?
The normalized PCA expense of $100,916,459,
divided by the normalized system firm sales of 13,497,550
Megawatt-hours, is used to arrive at the normalized base
power cost of 0.7477 cents per kilowatt-hour.For the
period April 1, 2006 through March 31, 2007, the customer-
level proj ected power cost of serving firm loads is 0.4691
cents per kilowatt-hour which is computed by dividing the
projected net PCA expense of $63,316,436 by the 13,497 550
Megawatt-hours normalized system firm sales.The Company
SCHWENDIMAN, DI
Idaho Power Company
adjusts its rates by 90 percent of the difference between
the customer-level projected power cost of serving firm
loads (0.4691 cents per kilowatt-hour) and the normalized
base power cost (0.7477 cents per kilowatt-hour.Restated,
this year I s computation is (.9) (0.4691- 0.7477) = negative
2507.The resulting adjustment is a 0.2507 cents per
kilowatt-hour decrease from the normalized base power cost.
Please describe the True-Up required from the
comparison of the April 1, 2005 through March 31, 2006
actual results to last year 's proj ections.
The Deferral Expense Account report for the
April 1, 2005 through March 31, 2006 PCA year is attached as
Exhibi t 3.This sheet compares the actual results to last
year s proj ections, month by month , with the differences
accumulated as the deferral balance.Interest has been
applied to the balance monthly.The balance at the end of
March 2006 was negative $39,513,704 as shown on Exhibit
The Accounting Department has advised me that the deferral
balance will be amortized during the current PCA year.
What change has been made to the Deferral
Expense Account report as a result of Order No. 29790?
In Order No. 29790, the Commission approved
recovery of Bennett Mountain power plant costs and required
that the related reduction in power supply expense be
included in the Company s 2006/2007 PCA.Row 54 of the
SCHWENDlMAN, DI
Idaho Power Company
Exhibi t 3 reflects the reduction of power supply costs
resulting from the Bennett Mountain Power plant as a monthly
credi t.
What change was made to the Deferral Expense
Account report, in the 2005/2006 PCA filing as a result of
Order No. 29600?
As a result of Order No. 29600, which
approved a settlement of specific 2004 general revenue
requirement case issues, an adjustment to reflect the
settlement of the disputed Valmy outage replacement power,
and a non-recurring tax credit was added (row 53,
This line item will provide a total credit ofExhibi t 3.
$19.3 million to customers through a monthly adjustment of
$804,167 over a 2-year term (June 2004 through May 2006.
What change has been made as a result of
Order No. 29789?
In Order No. 29789, the Commission authorized
the Company to collect $11 638,229, which was an estimated
balance based on an $11,504,667 regulatory asset associated
wi th income taxes with one year of in teres t .The Company
used actual PCA year loads for June 2004 through March of
2005 and estimated April and May 2005 loads to calculate a
PCA-year ending balance of $11 638,229 (row 28, Exhibit 4.
Later , the Company adjusted the April and May loads to
actual and reduced the June 1, 2005 beginning balance to
SCHWENDlMAN, DI
Idaho Power Company
$11,592,035 (row 28, Exhibit 5) as a result of the
difference between the estimate and actual loads for April
This value, plus one year of interest wasand May.
collected over the 2005/2006 PCA year.As of March 2006,
all but $1 962,462 (row 20, Exhibit 6) was collected through
rates.The Company has estimated that it will collect an
additional $1.7 million in April and May of this year.The
remaining balance (currently estimated at $300,681) will be
adjusted based upon the actual April and May collection and
added to the True-up of the True-up as a lump sum in June of
2006 and collected in the 2007/2008 PCAyear , through the
2007/2008 True-up of the True-up.
Were there any other changes made to this
year s PCA?
The base constants in both the PCAYes.
formula and the Deferral Expense Account report including
normalized Idaho jurisdictional sales, and normalized system
firm sales have been updated.These updates reflect the
Company s general revenue requirement filing, Case No. IPC-
05-28 and resulting stipulation.
What is this year s True-up rate?
This year I s True-up component of the PCA
the Deferral Expense Account report balance of negative
$39,513,704 divided by the normalized Idaho jurisdictional
sales of 12 695,163 which results in a rate of negative
SCHWENDlMAN, DI
Idaho Power Company
3113 cents per kilowatt-hour.
What is this year I s True-up of the True-
rate?
The Company collected all but $24, 513,298 of
the 2005/2006 PCA True-up balance (row 98, Exhibit 3.
Dividing the $24,513,298 balance by the normalized Idaho
jurisdictional sales of 12,695,163 Megawatt-hours results in
1931 cents per kilowatt-hour as the True-up of the True-
rate.
Why did the Company under-recover a
significant portion of the True-up of the True-up?
The True-up of the True-up included two non-
tradi tional items.First, in response to the Company '
proposal in its 2005/2006 PCA filing, the Commission agreed
that the Company should mitigate the impact of the below
normal water year projected costs by delaying recovery of
This was achieved by maintainingsome power supply expense.
PCA rates at current levels.To hold the rate constant,
$28.6 million was postponed for recovery in the 2006/2007
PCA year as part of the True-up of the True-up.Second,
irrigation class lost revenues in the amount of $13.
million were authorized for deferred recovery, through the
PCA, by Commission Order No. 29669, and this balance was
placed in the True-up of the True-up balance in May of 2005.
The True-up of the True-up balance, including the
SCHWENDIMAN, DI
Idaho Power Company
two items discussed above, waS offset throughout the
2005/2006 PCA year as a result of credits for intervener
funding and fuel expense (Order No. 29793) and by PCA
revenues.
what is the PCA rate as a result of:1 ) the
adjustment for the 2006/2007 projected power cost of serving
firm loads, 2) the 2005/2006 True-Up portion of the PCA, and
3) the True-up of the True-up?
The Company s PCA rate for the 2006/2007 PCA
year is negative 0.3689 cents per kilowatt-hour.The rate
is comprised of:1) the negative 0.2507 cents per kilowatt-
hour adjustment for 2006/2007 projected power cost of
serving firm loads, 2) the negative 0.3113 cents per
kilowatt-hour for the 2005/2006 True-Up portion of the PCA,
and 3) the 0.1931 cents per kilowatt-hour for the True-up of
the True-up.The components used to calculate the negative
3689 cents per kilowatt-hour are shown in Exhibit 7 , the
Company s proposed Schedule 55.
How does the new PCA rate of negative 0.3689
cents per kilowatt-hour compare to the existing PCA rate?
The 2006/2007 PCA rate of negative 0.3689
cents per kilowatt-hour is 0.9728 cents per kilowatt-hour
less than the 0.6039 cents per kilowatt-hour PCA rate
currently in place for all customers.
What is the overall percentage decrease to
SCHWENDlMAN, DI
Idaho Power Company
all customer classes, as a result of the 0.9728 cents per
kilowatt-hour decrease?
The overall percentage decrease is 19.34%,
a total of $123.5 million dollars as shown in columns 5 and
8 of Exhibit The individual customer class decreases are
also provided in Exhibit
Does that conclude your testimony?
Yes.
SCHWENDIMAN, DI 10
Idaho Power Company
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BEFORE THE
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IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-O6-
IDAHO POWER COMPANY
EXHIBIT NO.
CELESTE SCHWENDIMAN
PCA REGRESSION
PCA REGRESSION DERIVATION
obs year runoff In(runoID npsc predicted y regression statisticsmultiple r 0.8664r square 0.7506adjusted r square 0.7472
standard error 18 484,402observations
1928 660 438 15.675,670 25,824 544
1929 333,945 15.51,400 550 $774 064
1930 680 257 14.704 610 $211,178
1931 195,347 14.106,654 530 $104 327 585
1932 597 987 15.72,326,160 52,035,957
1933 164 069 15.966,490 047 461
1934 330 769 14.129 962,490 100 093,636
1935 032 333 14.103 099,200 $481 295
1936 959,005 15.42 137 980 46,689 478
1937 925 640 14.103,260 014 892
1938 822 575 15.582 700 24,123,287
1939 757 156 15.69,071 320 66,321 001
1940 161 283 15.875,870 59,094 815
1941 736 691 15.348 900 707,343
1942 836,089 15.792 900 464 794
1943 024 815 16.316 090 336,270
1944 291 366 15.262 790 75,683 246
1945 643 867 15.10,989 970 51,333 663
1946 739,646 15.244 870 988,324
1947 178 770 15.46 035,940 622 311
1948 778,546 15.175,660 871,033
1949 306 979 15.48 070,300 892 507
1950 373,426 15.16,037 210 28,940 215
1951 443 611 15.201 870 28,165 546
1952 10,272 230 16.386 040 821,301J
1953 894,428 15.282 800 34,466,591
1954 479 740 15.888 500 39,626 580
1955 3,456 000 15.35,457 560 230,809
1956 788 058 15.19,432 180 761 413
1957 771 260 15.15,302 080 914 142
1958 7,406 335 15.513,780 18,316,175
1959 789 767 15.126 500 65,709 720
1960 218 730 15.800 720 58,125,007
1961 065,597 14.706,460 709,573
1962 433 230 15.988,120 617 028
1963 530 163 15.723 060 087 115
1964 525,141 15.620,340 042 943
1965 391 765 15.750,660 9,480 508
1966 469,492 15.509,090 955 217
1967 676 331 15.21,418 010 840 914
1968 332 063 15.520 440 814 011
1969 787 323 15.33,280 620 24,489 714
1970 105 965 15.930 880 972,625
1971 246,610 16.968,460 644 661J
1972 735 381 15.798 240 15,241,466
1973 861 620 15.15,664 680 381 185
1974 567 549 16.23,958 150 205 516
1975 032 582 15.532 920 574 725
1976 168,628 15.217 360 623 599
1977 118 298 14.98,808 840 106,854 718
1978 057 794 15.44 057 020 45,294 245
1979 861,850 15.63,119,230 376,971
1980 830 780 15.58
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400,240 234 517
1981 160,499 15.367,200 108,133
1982 273 023 16.7,471 330 2,417,177
1983 934,443 16.500 140)~2,456,237)
1984 353,603 16.611 450)901 069)
1985 509,033 15.152 060 249,457
1986 8,412 897 15.142 030 302 613
1987 000,589 14.95,211 690 225 658
1988 487 374 14.196 640 95,493 898
1989 281,227 15.697 890 084 833
1990 875,083 14.111 588 920 85,247 888
1991 672 257 14.115 492 320 90,422 600
1992 866 885 14.44 131 741,330 115 791 284
1993 004 054 15.097,810 163,153
1994 494 387 14.96,876,490 95,294 735
1995 578,715 15.213,410 26,697 804
1996 063 851 15.305,020 299 908
1997 10,019 530 16.708 150 ~3,059 477)
1998 382 875 15.758,430 555 480
1999 679,720 15.743 440 15,752 270
2000 269,779 15.188,370 274 238
2001 382 545 14.119 660 270 98,539 538
2002 306 419 15.117 688,370 75,360 496
anova
regression
residual
total
coefficientsintercept 1 137 165,252x variable 1 (70 733,339)
averages 5,438,108 15.41 $005 199 $005,199
EXHIBIT NO.
CASE NO. IPC-O6-
C. SCHWENDIMAN, I
Page 1 of 1
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BEFORE THE
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IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-O6-
IDAHO POWER COMPANY
EXHIBIT NO.
CELESTE SCHWENDIMAN
NWRFC FORECAST
BRNI1-runoff - 4 7 _0. txt
BROWNLEE RES INFLOW (BRNI1)
Water Year 2006, Forecast period Apr -- Jul, Through Apr 9, 2006
-- --------------
Latest Forecast:
Di fference:
8380 133% (avg) (Apr Final)
8380
----------------
1971-2000 Forecast peri od: Mean 6313 Max 12754 Mi n 1793
uni ts: Kaf
Month obsFcst peri
Month observed %
ACC Normal s
Month Year ACC Accumul ated Fcst Peri Final
Normal Accumulated %Normals Accumulated Forecast
-------- --- -------- ----------- --- ----------- ----------- ----------------------
Oct 690 979 690 979
Nov 680 993 1370 1972
Dec 870 1121 2240 3093
Jan 1318 105 1260 3558 4353 6690
Feb 1218 1307 4776 5660 8010
Mar 1991 110 1818 6767 7478 6940
Apr 1938 9416 8380
1938
May 1949 11365
3887
Jun 1623 12988
5510Jul 802 13790
6312
Aug 679 14469
sep 809 15278
EXHIBIT NO.
CASE NO. IPC-O6-
C. SCHWENDIMAN , I
Page 1 of 1
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IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-O6-
IDAHO POWER COMPANY
EXHIBIT NO.
CELESTE SCHWENDIMAN
DEFERRAL EXPENSE ACCOUNT REPORT
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CASE NO. IPC-O6-Q2
IDAHO POWER COMPANY
EXHIBIT NO.
CELESTE SCHWENDIMAN
REGULATORY ASSET ACCOUNTING
1
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I.P.C. No. 27. Tariff No. 101
Third Revised Sheet No. 55-
Cancels
Second Revised Sheet No, 55-
Idaho Power Company
SCHEDULE 55
POWER COST ADJUSTMENT
APPLICABI LlTY
This schedule is applicable to the electric energy delivered to all Idaho retail Customers served
under the Company s schedules and Special Contracts. These loads are referred to as "firm" load for
purposes of this schedule.
BASE POWER COST
The Base Power Cost of the Company s rates is computed by dividing the Company s power
cost components by firm kWh load. The power cost components are the sum of fuel expense and
purchased power expense (including purchases from cogeneration and small power producers), less
the sum of off-system surplus sales revenue. The Base Power Cost is 0.7477 cents per kWh.
PROJECTED POWER COST
The Projected Power Cost is the Company estimate, expressed in cents per kWh , of the power
cost components for the forecasted time period beginning April 1 each year and ending the following
March 31. The Projected Power Cost is 0.4691 cents per kWh.
TRU&UP AND TRU&UP OF THE TRU&UP
The True-up is based upon the difference between the previous Projected Power Cost and the
power costs actually incurred. The True-up of the True-up is the difference between the previous years
approved True-Up revenues and actual revenues collected. The total True-up is (0.1182) cents per
kWh.
POWER COST ADJUSTMENT
The Power Cost Adjustment is 90 percent of the difference between the Projected Power Cost
and the Base Power Cost plus the True-ups.
The monthly Power Cost Adjustment applied to the Energy rate of all metered schedules and
Special Contracts is (0.3689) cents per kWh. The monthly Power Cost Adjustment applied to the per
unit charges of the nonmetered schedules is the monthly estimated usage time (0.3689) cents per kWh.
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31 2007.
IDAHO
Issued - April 12, 2006
Effective - June 1 , 2006
EXHIBIT NO.
CASE NO. IPC-O6-
C. SCHWENDIMAN, IPC
Page 1 of 1
Issued by IDAHO POWER COMPANY
John R. Gale , Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, Idaho
'i,
BEFORE THE
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IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-O6-Q7
IDAHO POWER COMPANY
EXHIBIT NO.
CELESTE SCHWENDIMAN
SUMMARY OF REVENUE IMPACT
Li
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