20040416Said Direct Testimony Exhibits.pdf

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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 MAY 16,
2004 THROUGH MAY 15, 2005
iSSION
CASE NO. IPC-04-
IDAHO POWER COMPANY
DIRECT TESTIMONY
GREGORY W. SAID
Please state your name and business address.
My name is Gregory W. Said 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 the
Manager of Revenue Requirement in the Pricing and Regulatory
Services Department.
Please describe your educational background.
In May of 1975, I received a Bachelor of
Science Degree in Mathematics with honors from Boise State
Uni versi ty. In 2003, I attended the Public Utility
Executives Course at the University of Idaho.
Please describe your work experience with
Idaho Power Company.
I became employed by Idaho Power Company in
1980 as an analyst in the Resource Planning Department. In
1985, the Company applied for a general revenue requirement
increase. I was the Company witness addressing power supply
expenses.
In August of 1989, after nine years in the
Resource Planning Department, I was offered and I accepted a
position in the Company s Rate Department. With the
Company s application for a temporary rate increase in 1992
my responsibilities as a witness were expanded. While I
SAID, DI
Idaho Power Company
continued to be the Company witness concerning power supply
expenses, I also sponsored the Company s rate computations
and proposed tariff schedules in that case.
Because of my combined Resource Planning and
Rate Department experience, I was asked to design a Power
Cost Adjustment (PCA) which would impact customers ' rates
based upon changes in the Company s net power supply
expenses. I presented my recommendations to the Idaho Public
Utilities Commission (IPUC) in 1992 at which time the IPUC
established the PCA as an annual adjustment to the Company
rates. I have sponsored the Company s annual PCA adjustment
in each of the years 1996 through 2003.
In 1996, I was promoted to Director of
Revenue Requirement.
Are you the same Gregory Said that presented
testimony in the Company I s general revenue requirement case
(IPUC Case No. IPC-03-13)?
Yes. In my testimony in the Company I s general
revenue requirement case, I discussed changes in loads and
resources since the Company s last general revenue
requirement case and the impact of those changes on the
Company s power supply expenses. I sponsored the exhibi ts
that provided the basis for determining the Company
normalized net power supply expenses for ratemaking
purposes. I discussed how the new normalized power supply
SAID, DI
Idaho Power Company
expenses impact future PCA computations until the Company
next general revenue requirement case.
Did you recommend any PCA computational
changes for the establishment of the new PCA regression
formula as part of the Company I s general revenue requirement
filing?
Yes. I recommended that three PCA
computational factors be updated as a result of the review
of power supply expenses. First, for PCA projection
calculations, a new normalized base PCA rate was calculated.
Second, a new Idaho jurisdictional percentage was
calculated. Third a new expense adjustment rate to be
applied to load growth (EARG) or decline was calculated.
Did you also present a non-computational
recommendation with regard to the PCA in your testimony in
Case No. IPC-03-13?
Yes. I recommended that the PCA recovery
period be moved from a May 16 through May 15 period to a
June 1 through May 31 time period. No other changes to PCA
time frames would be required. PCA proj ection and true-
computations would still be based upon an April 1 through
March 31 time frame and the Company would still file its PCA
request by April 15 each year.
Based upon your recommendation that this
year s PCA become effective on June 1, 2004, what do you
SAID, DI
Idaho Power Company
recommend as the PCA rate from May 16, 2004 through May 31,
2004?
Rather than having two rate adjustments
within fifteen days, I recommend that the current PCA rate
be extended throughout May 2004.
Are tariff changes required to accommodate
your proposal?
Yes. Exhibit 1 contains the tariff changes
required to accommodate my proposal.
What is the impact of using a June 1, 2004,
PCA effective date, as recommended in your testimony in the
IPC-03-13 general revenue requirement case and discussed
previously in this testimony?
If the current PCA rates become effective on
June 1, 2004 instead of May 16, 2004, the Company will
collect at the 2003/2004 PCA rate for an additional one-half
month. However, the True-up of the True-up provision of the
PCA will distribute any over-collection or under-collection
from this event back to the Company I s customers as a
component of the 2005/2006 PCA. Additionally, the Company
has recommended that any potential rate change from the
general revenue requirement case become effective on the
same date as the 2004/2005 PCA.
Did the IPUC receive any testimony in
opposi tion of the changes you recommended in Case No. IPC-
SAID, DI
Idaho Power Company
03-13?
Yes. Staff opposed my recommendation
regarding computation of the EARG. The issue of the
appropriate EARG was removed from the general revenue
requirement case forum and the determination of the EARG
will occur later this year.None of my other PCA
recommendations were opposed.
What is this year 's proj ection of PCA
expenses?
Based upon the updated PCA constants , the
proj ection of PCA expenses for the period April 1, 2004
through March 31, 2005 is $129,823,425. This amount is
$35,722,268 more than the $94,101,157 normalized level of
PCA expenses as filed in Case No. IPC-03-13.
What is the basis for the projection of
April 1, 2004 through March 31, 2005 PCA expenses?
The IPUC, 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 runoff to compute the proj ection of
April through March PCA expenses. Assuming that the
derivation of that equation will be updated as a result of
the Company I s filing in Case No. IPC-03-13, the new PCA
regression equation is:
SAID, DI
Idaho Power Company
Annual PCA expense = $1,140,615,325
- $+ $
70,685,112
46,413,057
* In (Brownlee runoff)
Details of the data underlying the PCA
regression equation are contained in Exhibit 2. Qualifying
Facilities ("QF") purchase expenses were updated and are
included in the projection computation.
In this formula, the $1,140,615,325 is the
updated constant that represents the prediction of annual
net power supply expense that would occur if there was zero
April through July Brownlee runoff. For each unit increase
in the natural logarithm of the Brownlee runoff data the
proj ection of annual power supply expenses will be reduced
by $70,685,112, the second of the updated constants in the
equation above. The $46,413,057 is the updated constant for
QF purchase expense.
What is the April through July Brownlee
runoff forecast that you used to arrive at the projection of
PCA expenses?
The National Weather Service I s Northwest
River River Forecast Center (NWRFC) , in its April 1
forecast, proj ected April through July Brownlee runoff to be
13 million acre-feet. Inserting this value into the
equation results in a proj ection of net PCA expenses of
$129,823,425 for the period April 1, 2004 through March 31,
SAID, DI
Idaho Power Company
2005. This amount is $35,722,268 more than the normalized
level of PCA expenses of $94,101,157. The Brownlee runoff
information supplied by the NWRFC is contained on Exhibit
The Brownlee Reservoir inflow appears on page 2 of 5 of
Exhibi t 3.
You have stated that the projected net PCA
expenses are more than the normalized level of PCA expenses
by $35,722,268. What is the rate adjustment associated with
the projected increase in PCA expenses of $35,722,268 from
the normalized level of PCA expenses?
The updated normalized PCA expense of
$94,101,157, divided by the updated normalized system firm
sales of 12,863,484 Megawatt-hours, is used to arrive at the
normalized base power cost of 0.7315 cents per kilowatt-
hour. For the period April 1, 2004 through March 31, 2005,
the proj ected power cost of serving firm loads is 1.0092
cents per kilowatt-hour which is computed by dividing the
projected incremental PCA expense of $35,722,268 by the
12,863,484 Megawatt-hours normalized system firm sales. The
Company adjusts its rates by 90 percent of the difference
between the projected power cost of serving firm loads
(1.0092 cents per kilowatt-hour) and the normalized base
power cost (0.7315 cents per kilowatt-hour). Restated, this
year s computation is (.9)(1.0092-7315)=0.2499. The
resulting adjustment is a 0.2499 cents per kilowatt-hour
SAID, DI
Idaho Power Company
increase from the normalized base power cost.
Please describe the True-Up required from the
comparison of the April 1, 2003 through March 31, 2004
actual results to last year 1 s proj ections .
The PCA True-Up deferral for the year
April 1, 2003 through March 31, 2004 is shown on Exhibit
This sheet compares the actual results to last year '
projections, month by month, with the differences
accumulated in a deferred expense account. Interest has been
applied to the deferred expense account monthly. The balance
in the deferred expense account at the end of March 2004 was
$44,285,289 as shown on Exhibit 4. This is the amount that
was under-collected during the PCA year. The Accounting
Department has advised me that the deferral will be
amortized during the current PCA year.
How is the $44,285,289 from Exhibit 4
reflected in the True-Up portion of the PCA?
In accordance with Order No. 29334 from Case
No. IPC-03-05, the True-Up component is calculated by
dividing the deferred expense balance of $44 285,289 by the
Company s "best estimate of the total Idaho jurisdictional
sales that will be made during the ensuing PCA year
(Exhibi t 5, page 4, paragraph 2) .The Company has filed
updated normalized Idaho jurisdictional firm sales of
12,096,838 Megawatt-hours as part of the IPC-03-13 general
SAID, DI
Idaho Power Company
revenue requirement case and believes this is the best
estimate for Megawatt-hours sales during the 2004/2005 PCA
year. The result of dividing the deferred expense balance by
the Idaho jurisdictional firm sales is 0.3661 cents per
kilowatt-hour, which is the True-Up portion of the PCA.
Were there any decisions made by the IPUC in
Order No. 29334 that will require adjustments to the
2004/2005 PCA rate?
Yes.Item 2 in the Stipulation approved by
the Commission in Order No. 29334 addressed a "True-up of
the True-up.Item 4 in the Stipulation addressed class
specific adjustments.
How will the True-up of the True-up be
reflected in this year s PCA?
The Company collected all but $556,693 of the
$38,658,298 True-up deferral balance from last year.
Dividing the $556,693 by the Idaho jurisdictional sales
value of 12,096,838 Megawatt-hours results in 0.0046 cents
per kilowatt-hour as the True-up of the True-up rate.
Please describe the class specific
adjustments contained in Item 4 of the Stipulation.
The Company will make three class specific
rate adjustments to the 2004/2005 PCA rate. The three
classes and their respective adjustment credits are:
1) Schedule 7, Small Commercial, -0189 cents per kilowatt
SAID , DI
Idaho Power Company
hour; 2) Schedule 19, Industrial -0222 cents per kilowatt
hour; and 3) Schedule 24, Irrigation, -0811 cents per
kilowatt hour. The calculation of the adjustments is shown
on page 5 of Exhibi t 5.
What is the PCA rate as a result of (1) the
adjustment for the 2004/2005 Projected power cost of serving
firm loads,(2) the 2003/2004 'True-Up portion of the PCA,
and 3) the True-up of the 2002/2003 True-up?
The Company s PCA rate for the 2004/2005 PCA
year is 0.6206 cents per kilowatt-hour. The rate is
comprised of: 1) the 0.2499 cents per kilowatt-hour
adjustment for 2004/2005 projected power cost of serving
firm loads, 2) the 0.3661 cents per kilowatt-hour for the
2003/2004 True-Up portion of the PCA, and 3) the 0.0046
cents per kilowatt-hour for the True-up of the 2002/2003
True-up. The components used to calculate the 0.6206 cents
per kilowatt-hour are shown in Exhibit 6, the Company
proposed Schedule 55.
How does the new PCA rate of 0.6206 cents per
kilowatt-hour compare to the existing PCA rate?
The 2004/2005 PCA rate of 0.6206 cents per
kilowatt-hour is 0.0167 cents per kilowatt-hour greater than
the 0.6039 cents per kilowatt-hour PCA rate that existed for
all classes except Schedule 7 , Schedule 19 and Schedule 24.
In light of the Company s pending general
SAID , DI
Idaho Power Company
revenue requirement case and an anticipated general rate
increase coming from that general revenue requirement case,
does the Company have an additional PCA recommendation this
year?
Yes. The Company has frequently stated that
its hope was for a Brownlee runoff forecast sufficient to
provide for a PCA reduction to coincide wi th the general
rate increase. Unfortunately, that did not occur. Rather
than create additional upward pressure on rates, the Company
proposes to keep the overall PCA rate at the same level as
last year, 0.6039 cents per kilowatt-hour. To accomplish
this, the True-up component rate would be adjusted down by
0167 cents per kilowatt-hour. The three customer classes
previously identified will still experience PCA rate
reductions, in addition to the reduction from their current
rates, to the 2004/2005 PCA rate minus their class-specific
credi ts .
Will the Company forfeit the additional
revenue to which it is entitled?
No. Based upon the difference between the
enti tIed rate of 0.6206 cents per kilowatt-hour and the
proposed retention of the 0.6039 cents per kilowatt-hour
rate, the Company would under-collect its entitled expense
by $2,020,172 ((0.6206-6039) cents per kilowatt-
hour)*12,096,838 Megawatt-hours). Because there is now a
SAID, DI
Idaho Power Company
True-up of the True-up, any under-collection of True-up
amounts will be captured next year. In other words, with the
beginning balance for the True-up of the True-up set at
$44,841,981 ($44,285,289+$556,693) and PCA True-up component
rates established to recover $42,818,861, at PCA year end,
the Company will have under-collected $2,020,172, which
would flow into next year s True-up of the True-up balance.
The Company is proposing this unique rate treatment to avoid
pancaking " rate increases in 2004.
What are the 2004/2005 PCA rates for
Schedule 7, Schedule 19 and Schedule 24 customers?
Because of the pre-established credits, the
Schedule 7 PCA rate will be 0.5850 cents per kilowatt-hour
(0.6039-0189), the Schedule 19 PCA rate will be 0.5817
cents per kilowatt-hour (0.6039-0222), and the Schedule 24
PCA rate will be 0.5228 cents per kilowatt-hour (0.6039-
0811) .
What percentage decrease from existing rates
including PCA, to new rates including PCA, will these
classes see as an offset to any general rate increase?
Exhibit 7 details the percentage rate change
that all customer classes will see as an offset to rate
increases ordered in the general revenue requirement case.
Schedule 7 customer will see a 3.66% decrease, Schedule 19
customers will see a 6.66% decrease and Schedule 24
SAID, DI
Idaho Power Company
customers will see a 15.75% decrease. All other customer
classes will see no change as a result of the new PCA.
Are you aware that the Idaho Supreme Court
has reversed the IPUC' s decision in Case No. IPC-01-34 and
ruled that Idaho Power Company is entitled to the collection
of lost revenues?
Yes.
Have you included any amounts in this year
PCA to reflect the Supreme Court decision?
No.
Why not?
Counsel for the Company has advised me that
at the time of the filing of my testimony in this
proceeding, the decision of the Idaho Supreme Court is not
final and the matter has not been remanded to the IPUC.
Does that conclude your testimony?
Yes.
SAID , DI
Idaho Power Company
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-O4-
IDAHO POWER COMPANY
EXHIBIT NO.
G. SAID
Original & legislative Tariff Schedules
IDAHO POWER COMPANY FOURTEENTH REVISED SHEET NO. 1-
CANCELS
THIRTEENTH REVISED SHEET NO. 1-I.P.C. NO. 26, TARIFF 101
SCHEDULE
RESIDENTIAL SERVICE
(Continued)
RESIDENTIAL SP ACE HEATING
All space heating equipment to be served by the Company s system shall be single phase
equipment approved by Underwriters' Laboratories, Inc., and the equipment and its installation shall
conform to all National, State and Municipal Codes and to the following:
Individual resistance-type units for space heating larger than 1 ,650 watts shall be
designed to operate at 240 or 208 volts, and no single unit shall be larger than 6 kW.
Heating units of two kW or larger shall be controlled by approved thermostatic
devices. When a group of heating units, with a total capacity of more than 6 kW.
to be actuated by a single thermostat, the controlling switch shall be so designed
that not more than 6 kW can be switched on or off at anyone time. Supplemental
resistance-type heaters, that may be used with a heat exchanger, shall comply with
the specifications listed above for such units.
MONTHLY CHARGE
The Monthly Charge is the sum of the Customer and the Energy Charges at the following rates:
Customer Charae
$2.51 per meter per month
Enerav Charae
Base Rate
9303!t
Power Cost
Adiustment*
6039!t
Effective
Rate
5342!t
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge and the Energy Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
PAYMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 1 of 44
I.P.C. NO. 26. TARIFF NO. 101
ELEVENTH REVISED SHEET NO. 7-
CANCELS
TENTH REVISED SHEET NO. 7-
IDAHO POWER COMPANY
SCHEDULE 7
SMALL GENERAL SERVICE
(Continued)
MONTHLY CHARGE (Continued)
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge and the Energy Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 2 of 44
I.P.C. NO. 26 TARIFF NO. 101
SIXTEENTH REVISED SHEET NO. 9-
CANCELS
FIFTEENTH REVISED SHEET NO. 9-
IDAHO POWER COMPANY
SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)
SECONDARY SERVICE (Continued)
Facilities Charae
None
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Basic Charge. the
Demand Charge, and the Energy Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
PRIMARY SERVICE
Customer Charae
$85.58 per meter per month
Basic Charae
$0.77 per kW of Basic Load Capacity
Demand Charae
$2.65 per kW for all kW of Demand
Enerav Charae
Base Rate
1308!t
Power Cost
Adiustment*
6039!t
Effective
Rate
7347!t per kWh for all kWh
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.7
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Basic Charge, the
Demand Charge, the Energy Charge, and the Facilities Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 3 of 44
I.P.C. NO. 26, TARIFF NO. 101
SIXTEENTH REVISED SHEET NO. 9-
CANCELS
FIFTEENTH REVISED SHEET NO. 9-
IDAHO POWER COMPANY
SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)
TRANSMISSION SERVICE
Customer Charge
$85.58 per meter per month
Basic Charae
$0.39 per kW of Basic Load Capacity
Demand Charae
$2.57 per kW for all kW of Demand
Enerav Charae
Base Rate
0833!t
Power Cost
Adiustment*
6039!t
Effective
Rate
6872!t per kWh for all kWh
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.7
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Basic Charge, the
Demand Charge, the Energy Charge, and the Facilities Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 4 of 44
I.P.c. NO. 26, TARIFF NO. 101
THIRTEENTH REVISED SHEET NO. 15-
CANCELS
TWELFTH REVISED SHEET NO. 15-
IDAHO POWER COMPANY
SCHEDULE 15
DUSK TO DAWN CUSTOMER LIGHTING
(Continued)
MONTHLY CHARGES (Continued)
FLOOD LIGHTING
200 Watt
400 Watt
Average Base Power Cost Effective
Lumens Rate ustment*Rate
19,800 $17.$0.41 $17.
45,000 $25.$0.$26.46
High Pressure
Sodium Vapor
Metal Halide
400 Watt
1000 Watt
28,800
88,000
$28.
$52.28
$0.
$2.
$29.47
$54.
* This Power Cost Adjustment is computed as provided in Schedule 55.2. The Monthly Charge for New Facilities to be installed, such as overhead (or equivalent)
secondary conductor, poles, anchors, etc., shall be 1.75 percent of the estimated installed cost thereof.3. The Company may provide underground service from existing secondary facilities when
the Customer pays the estimated nonsalvable cost of underground facilities.
PA YMENT
The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 5 of 44
I.P.C. NO. 26, TARIFF NO. 101
FIFTEENTH REVISED SHEET NO. 19-
CANCELS
FOURTEENTH REVISED SHEET NO. 19-
IDAHO POWER COMPANY
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
SECONDARY SERVICE (Continued)
Facilities Charae
None
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Basic Charge, the
Demand Charge, and the Energy Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
PRIMARY SERVICE
Customer Charae
$85.71 per meter per month
Basic Charae
$0.77 per kW of Basic Load Capacity
Demand Charae
$2.65 per kW for all kW of Billing Demand
Enerav Charae
Base Rate
0839!t
Power Cost
Adiustment*
8217!t
Effective
Rate
9056!t per kWh for all kWh
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.7
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge. the Basic Charge, the
Demand Charge, the Energy Charge, and the Facilities Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 6 of 44
I.P.C. NO. 26. TARIFF NO. 101
FIFTEENTH REVISED SHEET NO. 19-
CANCELS
FOURTEENTH REVISED SHEET NO. 19-
IDAHO POWER COMPANY
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
MONTHLY CHARGE (Continued)
TRANSMISSION SERVICE
Customer Charae
$85.71 per meter per month
Basic Charae
$0.39 per kW of Basic Load Capacity
Demand Charae
$2.57 per kW for all kW of Billing Demand
Enerav Charae
Base Rate
0375!t
Power Cost
Adiustment*
8217!t
Effective
Rate
8592!t per kWh for all kWh
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Basic Charge, the
Demand Charge, the Energy Charge, and the Facilities Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
PA YMENT
The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID. IPCO
Page 7 of 44
I.P.C. NO. 26, TARIFF NO. 101
THIRTEENTH REVISED SHEET NO. 24-
CANCELS
TWELFTH REVISED SHEET NO. 24-
IDAHO POWER COMPANY
SCHEDULE 24
IRRIGATION SERVICE
(Continued)
FACILITIES BEYOND THE POINT OF DELIVERY (Continued)
In the event the Customer requests the Company to remove or reinstall or change Company-
owned Facilities Beyond the Point of Delivery, the Customer shall pay to the Company the "non-
salvable cost" of such removal. reinstallation or change. Non-salvable cost as used herein is comprised
of the total original costs of materials, labor and overheads of the facilities, less the difference between
the salvable cost of material removed and removal labor cost including appropriate overhead costs.
POWER FACTOR ADJUSTMENT
Where the Customer s Power Factor is less than 85 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing
Demand by multiplying the measured kW by 85 percent and dividing by the actual Power Factor.
MONTHLY CHARGE
The Monthly Charge is the sum of the Customer, the Demand, the Energy, and the Facilities
Charges at the following rates.
SECONDARY SERVICE
Customer Charae
$10.07 per meter per month
$ 2.50 per meter per month
Irrigation Season
Out of Season
Demand Charqe
$3.58 per kW of Billing Demand
No Demand Charge
Irrigation Season
Out of Season
Base Rate
841 6!t
6172!t
Enerav Charae
Power Cost
Adiustment*
1.3159!t
1.3159!t
Effective
Rate
1575!t per kWh for all kWh Irrigation Season
9331!t per kWh for all kWh Out of Season
Facilities Charqe
None
Minimum Charqe
The monthly Minimum Charge shall be the sum of the Customer Charge, the Demand Charge,
and the Energy Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 8 of 44
IDAHO POWER COMPANY
I.P.C. NO. 26 TARIFF NO. 101
EIGHTEENTH REVISED SHEET NO. 24-
CANCELS
SEVENTEENTH REVISED SHEET NO. 24-
SCHEDULE 24
IRRIGA TION SERVICE
(Continued)
MONTHLY CHARGE (Continued)
TRANSMISSION SERVICE
Customer Charae
$85.61 per meter per month
$ 2.50 per meter per month
Irrigation Season
Out of Season
Demand Charae
$3.37 per kW of Billing Demand
No Demand Charge
Irrigation Season
Out of Season
Enerav Charae
Power Cost
Adiustment*
3159!t
1.3159!t
Effective
Rate
0180!t per kWh for all kWh Irrigation Season
4.7555!t per kWh for all kWh Out of Season
Base Rate
7021 !t
3.4396!t
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Demand Charge,
the Energy Charge, ,and the Facilities Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
PAYMENT
All monthly billings for Electric Service supplied hereunder are payable upon receipt, and
become past due 15 days from the date on which rendered. (For any agency or taxing district which
has notified the Company in writing that it falls within the provisions of Idaho Code 9 67-2302, the past
due date will reflect the 60 day payment period provided by Idaho Code 9 67-2302.
Deoosit. A deposit payment for irrigation Customers is required under the following conditions:
1 . Existina Customers: Customers who have two or more reminder notices for nonpayment
of Electric Service during a 12-month period or who have service disconnected for non-payment will be
required to pay a deposit. or provide a guarantee of payment from a bank or financial institution
acceptable to the Company. A reminder notice is issued approximately 45 days after the bill issue date
if the balance owing for Electric Service totals $100 or more or approximately 105 days after the bill issue
date for Customers meeting the provisions of Idaho Code 9 67-2302. The deposit for a specific
installation will be computed as follows:
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 9 of 44
IDAHO POWER COMPANY FIFTH REVISED SHEET NO. 25-
CANCELS
FOURTH REVISED SHEET NO. 25-I.P.C. NO. 26 TARIFF NO. 101
SCHEDULE 25
IRRIGATION SERVICE - TIME-OF-USE
PILOT PROGRAM
(OPTIONAL)
(Continued)
MONTHLY CHARGE
The Monthly Charge is the sum of the Customer, the TOU Metering, the Demand, the Energy,
and the Facilities Charges at the following rates.
SECONDARY SERVICE
Customer Charae
$10.07 per meter per month
$ 2.50 per meter per month
Irrigation Season
Out of Season
TOU Meterina Charae
$3.00 per meter per month
No TOU Meter Charge
Irrigation Season
Out of Season
Demand Charae
$3.58 per kW of Billing Demand
No Demand Charge
Irrigation Season
Out of Season
Enerav Charae
Base Rate
Power Cost
Adiustment*
Effective
Rate
On-Peak
Mid-Peak
Off-Peak
IN-SEASON
9728!t
8416!t
1 .4208!t
3159!t
1.31 59!t
1.31 59!t
2887!t per kWh for all kWh
1575!t per kWh for all kWh
7367!t per kWh for all kWh
OUT-OF-SEASON
61 72!t 3159!t 9331!t per kWh for all kWh
Facilities Charae
None
Minimum Charge
The monthly Minimum Charge shall be the sum of the Customer Charge, the TOU Metering
Charge, the Demand Charge, and the Energy Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 10 of 44
IDAHO POWER COMPANY FIFTH REVISED SHEET NO. 25-
CANCELS
FOURTH REVISED SHEET NO. 25-I.P.C. NO. 26. TARIFF NO. 101
SCHEDULE 25
IRRIGATION SERVICE - TIME-OF-USE
PILOT PROGRAM
(OPTIONAL)
(Continued)
MONTHLY CHARGE (Continued)
TRANSMISSION SERVICE
Customer Charae
$85.61 per meter per month
$ 2.50 per meter per month
Irrigation Season
Out of Season
TOU Meterina Charae
None
Demand Charae
$3.37 per kW of Billing Demand
No Demand Charge
Irrigation Season
Out of Season
Enerav Charae
Base Rate
Power Cost
Adiustment*
Effective
Rate
On-Peak
Mid-Peak
Off-Peak
IN-SEASON
4. 7287!t
7021 !t
1.3511 !t
1.3159!t
3159!t
3159!t
0446!t per kWh for all kWh
0180!t per kWh for all kWh
6670!t per kWh for all kWh
OUT-OF-SEASON
3.4396!t 1.3159!t 7555!t per kWh for all kWh
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Demand Charge,
the Energy Charge, and the Facilities Charge.
This Power Cost Adjustment is computed as provided in Schedule 55.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 11 of 44
I.P.C. NO. 26. TARIFF NO. 101
THIRTEENTH REVISED SHEET NO. 26-
CANCELS
TWELFTH REVISED SHEET NO. 26-
IDAHO POWER COMPANY
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
SCHEDULE 26
FOR
MICRON TECHNOLOGY, INC.
BOISE. IDAHO
SPECIAL CONTRACT DATED SEPTEMBER 1. 1995
(Continued)
MONTHLY ENERGY CHARGE
Enerav Charge
Base Rate
12.783
Power Cost
Adiustment*
039
Effective
Rate
18.822 mills per kWh for all energy
This Power Cost Adjustment is computed as provided in Schedule 55.
MONTHLY 0 & M CHARGES
0.4 percent of total cost of Substation Facilities.
CONSERVATION PROGRAMS RECOVERY CHARGE
$5,703 per month
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 12 of
I.P.C. NO. 26, TARIFF NO. 101
FOURTEENTH REVISED SHEET NO. 29-
CANCELS
THIRTEENTH REVISED SHEET NO. 29-
IDAHO POWER COMPANY
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
SCHEDULE 29
J. R. SIMPLOT COMPANY
POCATELLO, IDAHO
SPECIAL CONTRACT DATED AUGUST 27.1973
MONTHLY CONTRACT RATE
Demand Charge
$6.68 per kW of Billing Demand 11)
Enerav Charae
Base Rate
14.080
Power Cost
Adiustment*
039
Effective
Rate
20.119 mills per kWh for all energy (2)
Minimum Charae
The minimum monthly charge shall be the amount computed in accordance with Paragraph
1, but not less $100,188.61 for any month during the effective term of this Agreement.
This Power Cost Adjustment is computed as provided in Schedule 55.
CONSERVATION PROGRAMS RECOVERY CHARGE
$5,061 per month
Contract Chanaes
(1)Contract Paraaraoh No 5.1 (aL
No Change
(2)Contract Paraaraoh No. 5.1 (b)
Change 33.450 mills to 20.119 mills
(3)Contract Paraaraoh No. 5.
No Change
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 13 of
I.P.C. NO. 26, TARIFF NO. 101
FOURTEENTH REVISED SHEET NO. 30-
CANCELS
THIRTEENTH REVISED SHEET NO. 30-
IDAHO POWER COMPANY
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
SCHEDULE 30
FOR
UNITED STATES DEPARTMENT OF ENERGY
IDAHO OPERATIONS OFFICE
SPECIAL CONTRACT DATED MAY 16, 2000
CONTRACT NO. GS-OOP-99-BSD-0124
AVAILABILITY
This schedule is available for firm retail service of electric power and energy delivered for the
operations of the Department of Energy facilities located at the Idaho National Engineering
Laboratory site, as provided in the Contract for Electric Service between the parties.
MONTHLY CHARGE
The monthly charge for electric service shall be the sum of the Demand. Energy, and
Conservation Programs Recovery Charges determined at the following rates:
Demand Charae
$5.10 per kW of Billing Demand Per Month
Enerav Charae
Base
Rate
13.404
Power Cost
Adiustment*
039
Effective
Rate
19.443 mills per kWh for all energy
Conservation Proarams Recovery Charae
$3,521 per month
This Power Cost Adjustment is computed as provided in Schedule 55.
SPECIAL CONDITIONS
Billina Demand:
The Billing Demand shall be the average kW supplied during the 30-minute period of maximum
use during the month.
Power Factor Adjustment:
When the Power Factor is less than 95 percent during the 30-minute period of maximum load for
the month, Company may adjust the measured Demand to determine the Billing Demand by
multiplying the measured kW of Demand by 0.95 and dividing by the actual Power Factor.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 14 of
IDAHO POWER COMPANY FOURTH REVISED SHEET NO. 32-
CANCELS
THIRD REVISED SHEET NO. 32-I.P.C. NO. 26. TARIFF NO. 101
IDAHO POWER COMPANY
AGREEMENT FOR SUPPLY OF SHIELDED
STREET LIGHTING SERVICE
SCHEDULE 32
FOR THE CITY OF KETCHUM, IDAHO
SPECIAL CONTRACT DATED JUNE 12,2001
MONTHLY CHARGE PER LAMP
High Pressure
Sodium Vaoor
70 Watt
100 Watt
200 Watt
Average
Lumens
6.400
500
22,000
Base
Rate
$ 7.
$ 7.
$ 9.
Power Cost
Adiustment*
$0.
$0.
$0.41
Effective
Rate
$ 7.
$ 7.
$10.
This Power Cost Adjustment is computed as provided in Schedule 55.
ADDITIONAL MONTHLY RATE
For Company-owned poles installed after October 5, 1964 required to be used for street
lighting only:
Wood pole ..........................................................................$1.71 per pole
Steel pole ............................................................................$6.80 per pole
PAYMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 15 of 44
IDAHO POWER COMPANY SIXTEENTH REVISED SHEET NO. 40-
CANCELS
FIFTEENTH REVISED SHEET NO. 40-I.P.C. NO. 26, TARIFF NO. 101
SCHEDULE 40
UN METERED GENERAL SERVICE
AVAILABILITY
Service under this schedule is available at points on the Company s interconnected system
within the State of Idaho where existing secondary distribution facilities of adequate capacity, phase
and voltage are available adjacent to the Customer s Premises and the only investment required by
the Company is an overhead service drop.
APPLICABILITY
Service under this schedule applies to Electric Service for the Customer s single- or multiple-unit
loads up to 1,800 watts per unit where the size of the load and period of operation are fixed and, as a
result, actual usage can be accurately determined. Service may include, but is not limited to. street
and highway lighting, security lighting, telephone booths and CATV power supplies which serve line
amplifiers. Facilities to supply service under this schedule shall be installed so that service cannot be
extended to the Customer s loads served under other schedules. Service under this schedule is not
applicable to shared or temporary service, or to the Customer s loads on Premises which have metered
service.
SPECIAL TERMS AND CONDITIONS
The Customer shall pay for all Company investment, except the overhead service drop, required
to provide service requested by the Customer. The Customer is responsible for installing, owning and
maintaining all equipment, including necessary underground circuitry and related facilities to connect
with the Company s facilities at the Company designated Point of Delivery. If the Customer
equipment is not properly maintained, service to the specific equipment will be terminated.
Energy used by CATV power supplies which serve line amplifiers will be determined by the power
supply manufacturer s nameplate input rating assuming continuous operation.
The Company is only responsible for supplying energy to the Point of Delivery and, at its expense,
may check energy consumption at any time.
MONTHLY CHARGE
The average monthly kWh of energy usage shall be estimated by the Company, based on the
Customer s electric equipment and one-twelfth of the annual hours of operation thereof. Since the
service provided is unmetered, failure of the Customer s equipment will not be reason for a reduction in
the Monthly Charge. The Monthly Charge shall be computed at the following rate:
Base Rate
68!t
Power Cost
Adiustment
604!t
Effective
Rate
284!t per kWh for all kWh
Minimum Charae
$1 .50 per month
This Power Cost Adjustment is computed as provided in Schedule 55.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 16 of
IDAHO POWER COMPANY FOURTEENTH REVISED SHEET NO. 41-
CANCELS
THIRTEENTH REVISED SHEET NO. 41-I.P.c. NO. 26, TARIFF NO. 101
SCHEDULE 41
STREET LIGHTING SERVICE
AVAILABILITY
Service under this schedule is available throughout the Company s service area within the State
of Idaho where street lighting wires and fixtures can be installed on the Company s existing distribution
facilities.
APPLICABILITY
Service under this schedule is applicable to service required by municipalities or agencies of
federal, state, or county governments for the lighting of public streets, alleys, public grounds, and
thoroughfares. Street lighting lamps will be energized each night from dusk until dawn.
SERVICE LOCATION AND PERIOD
Street lighting facility locations, type of unit and lamp sizes, as changed from time to time by
written request of the Customer and agreed to by the Company, shall be as shown on an Exhibit A for
each Customer receiving service under this schedule. The in-service date for each street lighting facility
will be maintained on the Exhibit A.
The minimum service period for any street lighting facility is 10 years. The Company, upon written
notification from the Customer, will remove a street lighting facility:
A t no cost to the Customer. if such facility has been in service for no less than the
minimum service period:
Upon payment to the Company of the removal cost. if such facility has been in service
for less than the minimum service period.
A" - OVERHEAD LIGHTING - COMPANY-OWNED SYSTEM
The facilities required for supplying service, including fixture, lamp, control relay, mast arm or
mounting on an existing utility pole, and energy for the operation thereof. are supplied, installed, owned
and maintained by the Company. All necessary repairs, maintenance work, including group lamp
replacement and glassware cleaning, will be performed by the Company during the regularly
scheduled working hours of the Company on the Company s schedule. Individual lamps will be
replaced on burnout as soon as reasonably possible after notification by the Customer and subject to
the Company s operating schedules and requirements.
MONTHLY CHARGE PER LAMP
High Pressure Average Base Power Cost Effective
Sodium Va Lumens Rate Adiustment*Rate
100 Watt 550 $ 6.$0.$ 6.
200 Watt 19,800 $ 7.44 $0.48 $ 7.
400 Watt 45,000 $10.$1.$11.60
This Power Cost Adjustment is computed as provided in Schedule 55.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 17 of 44
I.P.C. NO. 26, TARIFF NO. 101
FOURTEENTH REVISED SHEET NO. 41-
CANCELS
THIRTEENTH REVISED SHEET NO. 41-
IDAHO POWER COMPANY
SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)
ADDITIONAL MONTHLY RATE
For Company-owned poles installed after October 5, 1964 required to be used for street
lighting only:
Wood pole ..........................................................................$1.71 per pole
Steel pole ............................................................................$6.80 per pole
UNDERGROUND CIRCUITS will be installed when the Customer pays the estimated cost
difference between overhead and underground, or the Customer agrees to pay a monthly charge
75 percent of the estimated cost difference.
B" - CUSTOMER-OWNED SYSTEM
The Customer s lighting system, including posts or standards, fixtures, initial installation of lamps
and underground cables with suitable terminals for connection to the Company s distribution system, is
installed and owned by the Customer.
Service supplied by the Company includes operation of the system, energy, lamp renewals,
cleaning of glassware, and replacement of defective ballasts and photocells which are standard to the
Company-owned street light units. Service does not include the labor or material cost of replacing
cables, standards, broken glassware or fixtures, or painting or refinishing of metal poles.
MONTHLY CHARGE PER LAMP
High Pressure Average Base Power Cost Effective
Sodium Vapor Lumens Rate Adiustment*Rate
100 Watt 550 $3.45 $0.$ 3.
200 Watt 19,800 $4.$0.48 $ 5.23
250 Watt 24,750 $5.$0.$ 6.
400 Watt 45,000 $7.$1.$ 8.
This Power Cost Adjustment is computed as provided in Schedule 55.
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
past due 15 days from the date on which rendered.
IDAHO
Issued - April 15, 2004
Effective - May 1 6, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 18 of 44
I.P.C. NO. 26, TARIFF NO. 101
FIFTEENTH REVISED SHEET NO. 41-
CANCELS
FOURTEENTH REVISED SHEET NO. 41-
IDAHO POWER COMPANY
SCHEDULE 41
STREET LIGHTING SERVICE
NO NEW SERVICE
(Continued)
MONTHLY CHARGE PER LAMP
Mercury Vaoor
175 Watt
400 Watt
700
18,800
Base Power Cost Effective
Rate ustment*Rate
$ 6.$0.42 $ 7.41
$11.59 $0.$12.
Average
Lumens
High Pressure
Sodium Vaoor
150 Watt
250 Watt
13,800
24,750
$ 6.
$ 8.42
$0.
$0.
$ 7.
$ 9.
This Power Cost Adjustment is computed as provided in Schedule 55.
ADDITIONAL MONTHLY RATE
For Company-owned poles installed after October 5, 1964 required to be used for street
lighting only.
Wood Pole ..........................................................................$1.71 per pole
Steel Pole ............................................................................$6.80 per pole
UNDERGROUND CIRCUITS will be installed when the Customer pays the estimated cost difference
between overhead and underground, or the Customer agrees to pay a monthly charge of 1.75 percent
of the estimated cost difference.
B" - ORNAMENTAL LIGHTING - CUSTOMER-OWNED SYSTEM
The Customer s lighting system, including posts or standards, fixtures, initial installation of lamps
and underground cables with suitable terminals for connection to the Company s distribution system. is
installed and owned by the Customer.
Service supplied by the Company includes operation of the system, energy, lamp renewals,
cleaning of glassware, and replacement of defective ballasts and photocells which are standard to the
Company owned street light units. Service does not include the labor or material cost of replacing
cables, standards, broken glassware or fixtures, or painting or refinishing of metal poles.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID. IPCO
Page 19 of 44
I.P.C. NO. 26, TARIFF NO. 101
FOURTEENTH REVISED SHEET NO. 41-
CANCELS
THIRTEENTH REVISED SHEET NO. 41-
IDAHO POWER COMPANY
SCHEDULE 41
STREET LIGHTING SERVICE
NO NEW SERVICE
(Continued)
MONTHL Y CHARGE PER LAMP
Average Base Power Cost Effective
Incandescent Lumens Rate ustment*Rate
500 $ 2.$0.40 $ 3.
Mercury Vapor
175 Watt 654 $ 5.$0.42 $ 5.
400 Watt 19,125 $ 8.$0.$ 9.
1000 Watt 47,000 $14.$2.$16.
High Pressure
Sodium Vapor
70 Watt 200 $ 3.$0.$ 3.
This Power Cost Adjustment is computed as provided in Schedule 55.
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 20 of 44
I.P.C. NO. 26 TARIFF NO. 101
SIXTEENTH REVISED SHEET NO. 42-
CANCELS
FIFTEENTH REVISED SHEET NO. 42-
IDAHO POWER COMPANY
SCHEDULE 42
TRAFFIC CONTROL SIGNAL
LIGHTING SERVICE
APPLICABILITY
Service under this schedule is applicable to Electric Service required for the operation of traffic
control signal lights within the State of Idaho. Traffic control signal lamps are mounted on posts or
standards by means of brackets, mast arms, or cable.
The traffic control signal fixtures, including posts or standards, brackets, mast arm, cable. lamps,
control mechanisms, fixtures, service cable, and conduit to the point of. and with suitable terminals for,
connection to the Company s underground or overhead distribution system, are installed. owned.
maintained and operated by the Customer. Service is limited to the supply of energy only for the
operation of traffic control signal lights.
MONTHLY CHARGES
The average monthly kWh of energy usage shall be estimated by the Company based on the
number and size of lamps burning simultaneously in each signal and the average number of hours per
day the signal is operated; PROVIDED, HOWEVER, at the Company s option, the wattage of the signal
may be determined by test.
Base Rate
1O5!t
Power Cost
Adiustment
604!t
Effective
Rate
709!t
This Power Cost Adjustment is computed as provided in Schedule 55.
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO
Issued - April 15, 2004
Effective - May 16, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 21 of 44
I.P.c. NO. 26 TARIFF NO. 101
TWELFTH REVISED SHEET NO. 55-
CANCELS
ELEVENTH REVISED SHEET NO. 55-
IDAHO POWER COMPANY
SCHEDULE 55
POWER COST ADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all Idaho retail Customers served
under the Company s schedules, to the primary portion of the FMC Special Contract. and to all other
Idaho retail 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 and FMC secondary load revenue. The Base Power Cost is
5238 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 0.7971 cents per kWh.
TRUE-
The True-up is based upon the difference between the previous Projected Power Cost and the
power costs actually incurred. The True-up is 0.3579 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 the True-up.
The monthly Power Cost Adjustment applied to the Energy rate for Irrigation Service (Schedules
24 and 25) is 1.3159 cents per kWh, for Small General Service (Schedule 7) is 0.8477 cents per kWh and
Large Power Service (Schedule 19) is 0.8217 cents per kWh. The monthly Power Cost Adjustment
applied to the Energy rate of all other metered schedules and Special Contracts is 0.6039 cents per
kWh. The monthly Power Cost Adjustment applied to the per unit charges of the nonmetered schedules
is the monthly estimated usage times 0.6039 cents per kWh.
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31 , 2004.
IDAHO
Issued - April 15, 2004
Effective - May 16,2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 22 of 44
I.P.C. NO. 26. TARIFF 101
THIRTEENTH REVISED SHEET NO. 1-
CANCELS
TWELFTH REVISED SHEET NO. 1-
IDAHO POWER COMPANY
SCHEDULE
RESIDENTIAL SERVICE
(Continued)
RESIDENTIAL SPACE HEATING
All space heating equipment to be served by the Company s system shall be single phase
equipment approved by Underwriters' Laboratories, Inc., and the equipment and its installation shall
conform to all National, State and Municipal Codes and to the following:
Individual resistance-type units for space heating larger than 1 ,650 watts shall be
designed to operate at 240 or 208 volts, and no single unit shall be larger than 6 kW.
Heating units of two kW or larger shall be controlled by approved thermostatic
devices. When a group of heating units, with a total capacity of more than 6 kW, is
to be actuated by a single thermostat, the controlling switch shall be so designed
that not more than 6 kW can be switched on or off at anyone time. Supplemental
resistance-type heaters, that may be used with a heat exchanger, shall comply with
the specifications listed above for such units.
MONTHLY CHARGE
The Monthly Charge is the sum of the Customer and the Energy Charges at the following rates:
Customer Charae
$2.51 per meter per month
Enerav Charae
Base Rate
9303!t
Power Cost
Adiustment*
6039!t
Effective
Rate
5342!t
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge and the Energy Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55 ), and Effective Rate
expire play 15,2004
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
past due 15 days from the date on which rendered.
EXHIBIT NO, 1
CASE NO, IPC-O4-
G. SAID, IPCO
Page 23 of 44
I.P.C. NO. 26, TARIFF NO. 101
TENTH REVISED SHEET NO. 7-
CANCELS
NINTH REVISED SHEET NO. 7-
IDAHO POWER COMPANY
SCHEDULE 7
SMALL GENERAL SERVICE
(Continued)
MONTHLY CHARGE (Continued)
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge and the Energy Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55), and Effective Rata expire
Mo'l15.2004
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
past due 15 days from the date on which rendered.
EXHIBIT NO.
CASE NO, IPC-O4-
G. SAID, IPCO
Page 24 of 44
I.P.C. NO. 26, TARIFF NO. 101
FIFTEENTH REVISED SHEET NO. 9-
CANCELS
FOURTEENTH REVISED SHEET NO. 9-
IDAHO POWER COMPANY
SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)
SECONDARY SERVICE (Continued)
Facilities Charae
None
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Basic Charge, the
Demand Charge, and the Energy Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55). and Effective Rate expire
May 15.2004
PRIMARY SERVICE
Customer Charae
$85.58 per meter per month
Basic Charae
$0.77 per kW of Basic Load Capacity
Demand Charae
$2.65 per kW for all kW of Demand
Enerav Charae
Base Rate
1308!t
Power Cost
Adiustment*
6039!t
Effective
Rate
7347!t per kWh for all kWh
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Basic Charge. the
Demand Charge, the Energy Charge, and the Facilities Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55), and Effective Rate expire
May 15,2004
EXHIBIT NO.
CASE NO, IPC-O4-
G. SAID, IPCO
Page 25 of 44
I.P.C. NO. 26, TARIFF NO. 101
FIFTEENTH REVISED SHEET NO. 9-
CANCELS
FOURTEENTH REVISED SHEET NO. 9-
IDAHO POWER COMPANY
SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)
TRANSMISSION SERVICE
Customer Charae
$85.58 per meter per month
Basic Charae
$0.39 per kW of Basic Load Capacity
Demand Charae
$2.57 per kW for all kW of Demand
Enerav Charae
Base Rate
0833!t
Power Cost
Adiustment*
6039!t
Effective
Rate
6872!t per kWh for all kWh
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.7
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge. the Basic Charge, the
Demand Charge, the Energy Charge, and the Facilities Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55), and Effective Rate
expire ,~,.A..ay 15,2001
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
EXHIBIT NO, 1
CASE NO. IPC-O4-
G, SAID , IPCO
Page 26 of 44
I.P.c. NO. 26, TARIFF NO. 101
TWELFTH REVISED SHEET NO. 15-
CANCELS
ELEVENTH REVISED SHEET NO. 15-
IDAHO POWER COMPANY
SCHEDULE 15
DUSK TO DAWN CUSTOMER LIGHTING
(Continued)
MONTHLY CHARGES (Continued)
FLOOD LIGHTING
200 Watt
400 Watt
Average Base Power Cost Effective
Lumens Rate ustment*Rate
19,800 $17.$0.41 $1 7.
45,000 $25.$0.$26.46
High Pressure
Sodium Vapor
Metal Halide
400 Watt
1000 Watt
28,800
88,000
$28.
$52.
$0.
$2.
$29.47
$54.
* This Power Cost Adjustment is computed as provided in fSchedule 55), and Effective Rate
expire May 15.20042. The Monthly Charge for New Facilities to be installed. such as overhead (or equivalent)
secondary conductor, poles, anchors, etc.. shall be 1.75 percent of the estimated installed cost thereof.
3. The Company may provide underground service from existing secondary facilities when
the Customer pays the estimated nonsalvable cost of underground facilities.
PA YMENT
The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
EXHIBIT NO.
CASE NO. IPC-O4-
G. SAID , IPCO
Page 27 of 44
IDAHO POWER COMPANY FOURTEENTH REVISED SHEET NO. 19-
CANCELS
THIRTEENTH REVISED SHEET NO. 19-I.P.C. NO. 26, TARIFF NO. 101
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
SECONDARY SERVICE (Continued)
Facilities Charae
None
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Basic Charge, the
Demand Charge, and the Energy Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55). and EffeGtive Rate
oxpiro pAa'l15, 2004.
PRIMARY SERVICE
Customer Charae
$85.71 per meter per month
Basic Charae
$0.77 per kW of Basic Load Capacity
Demand Charae
$2.65 per kW for all kW of Billing Demand
Enerav Charae
Base Rate
0839!t
Power Cost
Adiustment*
8217!t
Effective
Rate
9056!t per kWh for all kWh
Facilities Charqe
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.7
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Basic Charge, the
Demand Charge, the Energy Charge, and the Facilities Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55), and EffectivE) Rate
expire Ma'l15. 2004
EXHIBIT NO, 1
CASE NO. IPC-O4-
G. SAID, IPCO
Page 28 of 44
IDAHO POWER COMPANY FOURTEENTH REVISED SHEET NO. 19-
CANCELS
THIRTEENTH REVISED SHEET NO. 19-I.P.C. NO. 26, TARIFF NO. 101
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
MONTHLY CHARGE (Continued)
TRANSMISSION SERVICE
Customer Charae
$85.71 per meter per month
Basic Charae
$0.39 per kW of Basic Load Capacity
Demand Charae
$2.57 per kW for all kW of Billing Demand
Eneray Charae
Base Rate
0375!t
Power Cost
Adiustment*
8217!t
Effective
Rate
8592!t per kWh for all kWh
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.7
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Basic Charge, the
Demand Charge, the Energy Charge, and the Facilities Charge.
Thi~ Power Cost Adjustment is computed as provided in fSchedule 55). and Effective Rate
expire May 15.2004
PA YMENT
The monthly bill for service supplied hereunder is payable upon receipt. and becomes past due
15 days from the date on which rendered.
EXHIBIT NO, 1
CASE NO. IPC-O4-
G. SAID, IPCO
Page 29 of 44
I.P.C. NO. 26. TARIFF NO. 101
TWELFTH REVISED SHEET NO. 24-
CANCELS
ELEVENTH REVISED SHEET NO. 24-
IDAHO POWER COMPANY
SCHEDULE 24
IRRIGATION SERVICE
(Continued)
FACILITIES BEYOND THE POINT OF DELIVERY (Continued)
In the event the Customer requests the Company to remove or reinstall or change Company-
owned Facilities Beyond the Point of Delivery, the Customer shall pay to the Company the "non-
salvable cost" of such removal. reinstallation or change. Non-salvable cost as used herein is comprised
of the total original costs of materials, labor and overheads of the facilities, less the difference between
the salvable cost of material removed and removal labor cost including appropriate overhead costs.
POWER FACTOR ADJUSTMENT
Where the Customer s Power Factor is less than 85 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing
Demand by multiplying the measured kW by 85 percent and dividing by the actual Power Factor.
MONTHLY CHARGE
The Monthly Charge is the sum of the Customer. the Demand, the Energy, and the Facilities
Charges at the following rates.
SECONDARY SERVICE
Customer Charae
$10.07 per meter per month
$ 2.50 per meter per month
Irrigation Season
Out of Season
Demand Charae
$3.58 per kW of Billing Demand
No Demand Charge
Irrigation Season
Out of Season
Base Rate
841 6!t
61 72!t
Eneray Charae
Power Cost
Adiustment*
1.3159!t
1.3159!t
Effective
Rate
1575!t per kWh for all kWh Irrigation Season
9331!t per kWh for all kWh Out of Season
Facilities Charae
None
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Demand Charge,
and the Energy Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55 ), and Effectivo Rate
expire Ma'l15, 2004.
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID , IPCO
Page 30 of 44
I.P.C. NO. 26 TARIFF NO. 101
SEVENTEENTH REVISED SHEET NO. 24-
CANCELS
SIXTEENTH REVISED SHEET NO. 24-
IDAHO POWER COMPANY
SCHEDULE 24
IRRIGATION SERVICE
(Continued)
MONTHLY CHARGE (Continued)
TRANSMISSION SERVICE
Customer Charae
$85.61 per meter per month
$ 2.50 per meter per month
Irrigation Season
Out of Season
Demand Charge
$3.37 per kW of Billing Demand
No Demand Charge
Irrigation Season
Out of Season
Eneray Charae
Power Cost
Adiustment*
3159!t
1.3159!t
Base Rate
7021 !t
3.4396!t
Effective
Rate
0 180!t per kWh for all kWh Irrigation Season
7555!t per kWh for all kWh Out of Season
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Demand Charge,
the Energy Charge, and the Facilities Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55). and Effective Rata
expire May 15.2004.
PA YMENT
All monthly billings for Electric Service supplied hereunder are payable upon receipt, and
become past due 15 days from the date on which rendered. (For any agency or taxing district which
has notified the Company in writing that it falls within the provisions of Idaho Code ~ 67-2302, the past
due date will reflect the 60 day payment period provided by Idaho Code ~ 67-2302.
Deposit. A deposit payment for irrigation Customers is required under the following conditions:
1 . Existinq Customers: Customers who have two or more reminder notices for nonpayment
of Electric Service during a 12-month period or who have service disconnected for non-payment will be
required to pay a deposit, or provide a guarantee of payment from a bank or financial institution
acceptable to the Company. A reminder notice is issued approximately 45 days after the bill issue date
if the balance owing for Electric Service totals $100 or more or approximately 105 days after the bill issue
date for Customers meeting the provisions of Idaho Code ~ 67-2302. The deposit for a specific
installation will be computed as follows:
EXHIBIT NO, 1
CASE NO. IPC-O4-
G, SAID , IPCO
Page 31 of 44
I.P.C. NO. 26 TARIFF NO. 101
FOURTH REVISED SHEET NO. 25-
CANCELS
THIRD REVISED SHEET NO. 25-
IDAHO POWER COMPANY
SCHEDULE 25
IRRIGATION SERVICE - TIME-OF-USE
PILOT PROGRAM
(OPTIONAL)
(Continued)
MONTHL Y CHARGE
The Monthly Charge is the sum of the Customer, the TOU Metering. the Demand, the Energy,
and the Facilities Charges at the following rates.
SECONDARY SERVICE
Customer Charae
$10.07 per meter per month
$ 2.50 per meter per month
Irrigation Season
Out of Season
TOU Meterina Charae
$3.00 per meter per month
No TOU Meter Charge
Irrigation Season
Out of Season
Demand Charae
$3.58 per kW of Billing Demand
No Demand Charge
Irrigation Season
Out of Season
Eneray Charae
Base Rate
Power Cost
Adiustment*
Effective
Rate
On-Peak
Mid-Peak
Off-Peak
IN-SEASON
9728!t
8416!t
1 .4208!t
1.3159!t
1.3159!t
1.3159!t
6.2887!t per kWh for all kWh
1575!t per kWh for all kWh
7367!t per kWh for all kWh
OUT-OF-SEASON
6172!t 3159!t 9331!t per kWh for all kWh
Facilities Charae
None
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the TOU Metering
Charge, the Demand Charge, and the Energy Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55), and EffoctivG Rate oxpire
Ma'l15.2004
EXHIBIT NO.
CASE NO. IPC-O4-
G, SAID, IPCO
Page 32 of 44
I.P.c. NO. 26. TARIFF NO. 101
FOURTH REVISED SHEET NO. 25-
CANCELS
THIRD REVISED SHEET NO. 25-
IDAHO POWER COMPANY
SCHEDULE 25
IRRIGATION SERVICE - TIME-OF-USE
PILOT PROGRAM
(OPTIONAL)
(Continued)
MONTHLY CHARGE (Continued)
TRANSMISSION SERVICE
Customer Charae
$85.61 per meter per month
$ 2.50 per meter per month
Irrigation Season
Out of Season
TOU Meterina Charae
None
Demand Charae
$3.37 per kW of Billing Demand
No Demand Charge
Irrigation Season
Out of Season
Enemy Charae
Base Rate
Power Cost
Adiustment*
Effective
Rate
On-Peak
Mid-Peak
Off-Peak
IN-SEASON
7287!t
7021 !t
1.3511 !t
3159!t
1.31 59!t
1.3159!t
0446!t per kWh for all kWh
0 180!t per kWh for all kWh
6670!t per kWh for all kWh
OUT-OF-SEASON3.4396!t 1.3159!t 7555!t per kWh for all kWh
Facilities Charae
The Company s investment in Company-owned Facilities Beyond the Point of Delivery times 1.
percent.
Minimum Charae
The monthly Minimum Charge shall be the sum of the Customer Charge, the Demand Charge,
the Energy Charge, and the Facilities Charge.
This Power Cost Adjustment is computed as provided in fSchedule 55). and Effective Rate
expire Ma'l15. 2004.
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID , IPCO
Page 33 of 44
I.P.C. NO, 26. TARIFF NO. 101
TWELFTH REVISED SHEET NO. 26-
CANCELS
ELEVENTH REVISED SHEET NO. 26-
IDAHO POWER COMPANY
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
SCHEDULE 26
FOR
MICRON TECHNOLOGY, INC.
BOISE, IDAHO
SPECIAL CONTRACT DATED SEPTEMBER 1,1995
(Continued)
MONTHLY ENERGY CHARGE
Enemy Charae
Base Rate
12.783
Power Cost
Adiustment*
039
Effective
Rate
18.822 mills per kWh for all energy
This Power Cost Adjustment is comouted as orovided in fSchedule 55). and Effecti'/o Rate
expire May 15.2004
MONTHLY 0 & M CHARGES
0.4 percent of total cost of Substation Facilities.
CONSERVATION PROGRAMS RECOVERY CHARGE
$5,703 per month
EXHIBIT NO.
CASE NO. IPC-O4-
G, SAID, IPCO
Page 34 of 44
I.P.C. NO. 26, TARIFF NO. 101
THIRTEENTH REVISED SHEET NO. 29-
CANCELS
TWELFTH REVISED SHEET NO. 29-
IDAHO POWER COMPANY
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
SCHEDULE 29
J. R. SIMPLOT COMPANY
POCATELLO, IDAHO
SPECIAL CONTRACT DATED AUGUST 27,1973
MONTHLY CONTRACT RATE
Demand Charae
$6.68 per kW of Billing Demand (1)
Eneray Charae
Base Rate
14.080
Power Cost
Adiustment*
039
Effective
Rate
20.119 mills per kWh for all energy (2)
Minimum Charae
The minimum monthly charge shall be the amount computed in accordance with Paragraph
1, but not less $100,188.61 for any month during the effective term of this Agreement.
This Power Cost Adjustment is computed as provided in fSchedule 55 ). and Effecti'lo Rata
expire May 15, 200~
CONSERVATION PROGRAMS RECOVERY CHARGE
$5,061 per month
Contract Changes
(1 )Contract Paraaraph No 5.la!.
No Change
(2)Contract Paraaraph No. 5.1 Ibl
Change 33.450 mills to 20.119 mills
(3)Contract Paraaraph No. 5.
No Change
EXHIBIT NO.
CASE NO. IPC-O4-
G. SAID, IPCO
Page 35 of 44
I.P.C. NO. 26, TARIFF NO. 101
THIRTEENTH REVISED SHEET NO. 30-
CANCELS
TWELFTH REVISED SHEET NO. 30-
IDAHO POWER COMPANY
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
SCHEDULE 30
FOR
UNITED STATES DEPARTMENT OF ENERGY
IDAHO OPERA nONS OFFICE
SPECIAL CONTRACT DATED MAY 16, 2000
CONTRACT NO. GS-OOP-99-BSD-0124
AVAILABILITY
This schedule is available for firm retail service of electric power and energy delivered for the
operations of the Department of Energy facilities located at the Idaho National Engineering
Laboratory site, as provided in the Contract for Electric Service between the parties.
MONTHLY CHARGE
The monthly charge for electric service shall be the sum of the Demand, Energy, and
Conservation Programs Recovery Charges determined at the following rates:
Demand Charae
$5.10 per kW of Billing Demand Per Month
Eneray Charae
Base
Rate
13.404
Power Cost
Adiustment*
039
Effective
Rate
19.443 mills per kWh for all energy
Conservation Proarams Recoverv Charae
$3,521 per month
This Power Cost Adjustment is computed as provided in fSchedule 55). and Effective Rate
oxpire May 15, 2004.
SPECIAL CONDITIONS
Billina Demand:
The Billing Demand shall be the average kW supplied during the 30-minute period of maximum
use during the month.
Power Factor Adiustment:
When the Power Factor is less than 95 percent during the 30-minute period of maximum load for
the month, Company may adjust the measured Demand to determine the Billing Demand by
multiplying the measured kW of Demand by 0.95 and dividing by the actual Power Factor.
EXHIBIT NO.
CASE NO. IPC-O4-
G. SAID, IPCO
Page 36 of 44
I.P.C. NO. 26. TARIFF NO. 101
THIRD REVISED SHEET NO. 32-
CANCELS
SECOND REVISED SHEET NO. 32-
IDAHO POWER COMPANY
IDAHO POWER COMPANY
AGREEMENT FOR SUPPLY OF SHIELDED
STREET LIGHTING SERVICE
SCHEDULE 32
FOR THE CITY OF KETCHUM, IDAHO
SPECIAL CONTRACT DATED JUNE 12,2001
MONTHLY CHARGE PER LAMP
High Pressure
Sodium Vaoor
70 Watt
100 Watt
200 Watt
Average
Lumens
6,400
500
22,000
Base
Rate
$ 7.
$ 7.
$ 9.
Power Cost
Adiustment*
$0.
$0.
$0.41
Effective
Rate
$ 7.
$ 7.
$10.
This Power Cost Adjustment is comouted as orovided in fSchedule 55 ) and this Effective Rate
oxpire May 15,2004
ADDITIONAL MONTHLY RATE
For Company-owned poles installed after October 5, 1964 required to be used for street
lighting only:
Wood pole ..........................................................................$1.71 per pole
Steel pole ............................................................................$6.80 per pole
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
EXHIBIT NO.
CASE NO. IPC-04-
G, SAID , IPCO
Page 37 of 44
I.P.C. NO. 26, TARIFF NO. 101
FIFTEENTH REVISED SHEET NO. 40-
CANCELS
FOURTEENTH REVISED SHEET NO. 40-
IDAHO POWER COMPANY
SCHEDULE 40
UNMETERED GENERAL SERVICE
AVAILABILITY
Service under this schedule is available at points on the Company s interconnected system
within the State of Idaho where existing secondary distribution facilities of adequate capacity. phase
and voltage are available adjacent to the Customer s Premises and the only investment required by
the Company is an overhead service drop.
APPLICABILITY
Service under this schedule applies to Electric Service for the Customer s single- or multiple-unit
loads up to 1,800 watts per unit where the size of the load and period of operation are fixed and, as a
result. actual usage can be accurately determined. Service may include, but is not limited to. street
and highway lighting, security lighting, telephone booths and CATV power supplies which serve line
amplifiers. Facilities to supply service under this schedule shall be installed so that service cannot be
extended to the Customer s loads served under other schedules. Service under this schedule is not
applicable to shared or temporary service, or to the Customer s loads on Premises which have metered
service.
SPECIAL TERMS AND CONDITIONS
The Customer shall pay for all Company investment, except the overhead service drop, required
to provide service requested by the Customer. The Customer is responsible for installing, owning and
maintaining all equipment, including necessary underground circuitry and related facilities to connect
with the Company s facilities at the Company designated Point of Delivery. If the Customer
equipment is not properly maintained, service to the specific equipment will be terminated.
Energy used by CATV power supplies which serve line amplifiers will be determined by the power
supply manufacturer s nameplate input rating assuming continuous operation.
The Company is only responsible for supplying energy to the Point of Delivery and, at its expense.
may check energy consumption at any time.
MONTHLY CHARGE
The average monthly kWh of energy usage shall be estimated by the Company, based on the
Customer s electric equipment and one-twelfth of the annual hours of operation thereof. Since the
service provided is unmetered, failure of the Customer s equipment will not be reason for a reduction in
the Monthly Charge. The Monthly Charge shall be computed at the following rate:
Base Rate
68!t
Power Cost
Adiustment
604!t
Effective
Rate
6.284!t per kWh for all kWh
Minimum Charae
$1 .50 per month
This Power Cost Adjustment is computed as provided in fSchedule 55). and Effective Rate expire
Ma'l15,2004
EXHIBIT NO.
CASE NO. IPC-O4-
G. SAID, IPCO
Page 38 of 44
I.P.C. NO. 26, TARIFF NO. 101
THIRTEENTH REVISED SHEET NO. 41-
CANCELS
TWELFTH REVISED SHEET NO. 41-
IDAHO POWER COMPANY
SCHEDULE 41
STREET LIGHTING SERVICE
AVAILABILITY
Service under this schedule is available throughout the Company s service area within the state
of Idaho where street lighting wires and fixtures can be installed on the Company s existing distribution
facilities.
APPLICABILITY
Service under this schedule is applicable to service required by municipalities or agencies of
federal. state, or county governments for the lighting of public streets, alleys, public grounds, and
thoroughfares. Street lighting lamps will be energized each night from dusk until dawn.
SERVICE LOCATION AND PERIOD
Street lighting facility locations, type of unit and lamp sizes. as changed from time to time by
written request of the Customer and agreed to by the Company, shall be as shown on an Exhibit A for
each Customer receiving service under this schedule. The in-service date for each street lighting facility
will be maintained on the Exhibit A.
The minimum service period for any street lighting facility is 10 years. The Company, upon written
notification from the Customer, will remove a street lighting facility:
A t no cost to the Customer, if such facility has been in service for no less than the
minimum service period;
Upon payment to the Company of the removal cost. if such facility has been in service
for less than the minimum service period.
A" - OVERHEAD LIGHTING - COMPANY-OWNED SYSTEM
The facilities required for supplying service, including fixture. lamp, control relay, mast arm or
mounting on an existing utility pole, and energy for the operation thereof. are supplied, installed. owned
and maintained by the Company. All necessary repairs, maintenance work, including group lamp
replacement and glassware cleaning, will be performed by the Company during the regularly
scheduled working hours of the Company on the Company s schedule. Individual lamps will be
replaced on burnout as soon as reasonably possible after notification by the Customer and subject to
the Company s operating schedules and requirements.
MONTHLY CHARGE PER LAMP
High Pressure Average Base Power Cost Effective
Sodium Va Lumens Rate Adiustment*Rate
100 Watt 550 $ 6.$0.$ 6.
200 Watt 19,800 $ 7.44 $0.48 $ 7.
400 Watt 45,000 $10.$1.$11.60
This Power Cost Adjustment is com outed as provided in fSchedule 55). and EffGcti'le Rate
oxpire May 15,2004
EXHIBIT NO.
CASE NO. IPC-O4-
G. SAID, IPCO
Page 39 of 44
IDAHO POWER COMPANY THIRTEENTH REVISED SHEET NO. 41-
CANCELS
TWELFTH REVISED SHEET NO. 41-I.P.C. NO. 26, TARIFF NO. 101
SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)
ADDITIONAL MONTHLY RATE
For Company-owned poles installed after October 5, 1964 required to be used for street
lighting only:
Wood pole ..........................................................................$1.71 per pole
Steel pole ............................................................................$6.80 per pole
UNDERGROUND CIRCUITS will be installed when the Customer pays the estimated cost
difference between overhead and underground, or the Customer agrees to pay a monthly charge
75 percent of the estimated cost difference.
B" - CUSTOMER-OWNED SYSTEM
The Customer's lighting system, including posts or standards. fixtures, initial installation of lamps
and underground cables with suitable terminals for connection to the Company s distribution system, is
installed and owned by the Customer.
Service supplied by the Company includes operation of the system, energy, lamp renewals,
cleaning of glassware, and replacement of defective ballasts and photocells which are standard to the
Company-owned street light units. Service does not include the labor or material cost of replacing
cables, standards, broken glassware or fixtures, or painting or refinishing of metal poles.
MONTHLY CHARGE PER LAMP
High Pressure Average Base Power Cost Effective
Sodium Vaoor Lumens Rate Adiustment*Rate
100 Watt 550 $3.45 $0.$ 3.
200 Watt 19,800 $4.$0.48 $ 5.
250 Watt 24,750 $5.$0.$ 6.
400 Watt 45,000 $7.$1.$ 8.
This Power Cost Adjustment is com outed as orovided in fSchedule 55). and Effective Rate
expire Ma'l15. 2004
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 40 of 44
I.P.C. NO. 26. TARIFF NO. 101
FOURTEENTH REVISED SHEET NO. 41-
CANCELS
THIRTEENTH REVISED SHEET NO. 41-
IDAHO POWER COMPANY
SCHEDULE 41
STREET LIGHTING SERVICE
NO NEW SERVICE
(Continued)
MONTHLY CHARGE PER LAMP
Mercury Vaoor
175 Watt
400 Watt
700
18,800
Base Power Cost Effective
Rate ustment*Rate
$ 6.$0.42 $ 7.41
$11.59 $0.$12.
Average
Lumens
High Pressure
Sodium Vaoor
150 Watt
250 Watt
13,800
24,750
$ 6.
$ 8.42
$0.
$0.
$ 7.
$ 9.
This Power Cost Adjustment is com outed as orovided in fSchedule 55), and Effective Rate expire
May 15.2004
ADDITIONAL MONTHLY RATE
For Company-owned poles installed after October 5, 1964 required to be used for street
lighting only.
Wood Pole ..........................................................................$1.71 per pole
Steel Pole ............................................................................$6.80 per pole
UNDERGROUND CIRCUITS will be installed when the Customer pays the estimated cost difference
between overhead and underground, or the Customer agrees to pay a monthly charge of 1.75 percent
of the estimated cost difference.
B" - ORNAMENTAL LIGHTING - CUSTOMER-OWNED SYSTEM
The Customer s lighting system, including posts or standards, fixtures, initial installation of lamps
and underground cables with suitable terminals for connection to the Company s distribution system, is
installed and owned by the Customer.
Service supplied by the Company includes operation of the system, energy, lamp renewals,
cleaning of glassware, and replacement of defective ballasts and photocells which are standard to the
Company owned street light units. Service does not include the labor or material cost of replacing
cables, standards, broken glassware or fixtures, or painting or refinishing of metal poles.
EXHIBIT NO.
CASE NO, IPC-O4-
G. SAID , IPCO
Page 41 of 44
I.P.C. NO. 26. TARIFF NO. 101
THIRTEENTH REVISED SHEET NO. 41-
CANCELS
TWELFTH REVISED SHEET NO. 41-
IDAHO POWER COMPANY
SCHEDULE 41
STREET LIGHTING SERVICE
NO NEW SERVICE
(Continued)
MONTHLY CHARGE PER LAMP
Mercury Vapor
175 Watt
400 Watt
1000 Watt
654
19,125
47,000
Base Power Cost Effective
Rate Adiustment*Rate
$ 2.$0.40 $ 3.
$ 5.$0.42 $ 5.
$ 8.$0.$ 9.
$14.$2.$16.
Incandescent
Average
Lumens
500
High Pressure
Sodium Vapor
70 Watt 200 $ 3.$0.$ 3.
This Power Cost Adjustment is computed as provided in fSchedule 55). and Effective Rate
expiro Ma'l15, 2001
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
past due 15 days from the date on which rendered.
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 42 of 44
IDAHO POWER COMPANY FIFTEENTH REVISED SHEET NO. 42-
CANCELS
FOURTEENTH REVISED SHEET NO. 42-I.P.C. NO. 26, TARIFF NO. 101
SCHEDULE 42
TRAFFIC CONTROL SIGNAL
LIGHTING SERVICE
APPLICABILITY
Service under this schedule is applicable to Electric Service required for the operation of traffic
control signal lights within the State of Idaho. Traffic control signal lamps are mounted on posts or
standards by means of brackets, mast arms, or cable.
The traffic control signal fixtures, including posts or standards, brackets, mast arm, cable. lamps,
control mechanisms, fixtures, service cable, and conduit to the point of. and with suitable terminals for,
connection to the Company s underground or overhead distribution system, are installed. owned.
maintained and operated by the Customer. Service is limited to the supply of energy only for the
operation of traffic control signal lights.
MONTHLY CHARGES
The average monthly kWh of energy usage shall be estimated by the Company based on the
number and size of lamps burning simultaneously in each signal and the average number of hours per
day the signal is operated; PROVIDED, HOWEVER, at the Company s option, the wattage of the signal
may be determined by test.
Base Rate
105!t
Power Cost
Adiustment
604!t
Effective
Rate
709!t
This Power Cost Adjustment is computed as provided in fSchedule 55). and Effective Rate
expire Ma'l15. 2004.
PA YMENT
The monthly bill rendered for service supplied hereunder is payable upon receipt. and becomes
past due 15 days from the date on which rendered.
EXHIBIT NO.
CASE NO. IPC-O4-
G. SAID, (PCO
Page 43 of 44
I.P.C. NO. 26, TARIFF NO. 101
ELEVENTH REVISED SHEET NO. 55-
CANCELS
TENTH REVISED SHEET NO. 55-
IDAHO POWER COMPANY
SCHEDULE 55
POWER COST ADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all Idaho retail Customers served
under the Company s schedules, to the primary portion of the FMC Special Contract, and to all other
Idaho retail 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 and FMC secondary load revenue. The Base Power Cost is
5238 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 0.7971 cents per kWh.
TRUE-
The True-up is based upon the difference between the previous Projected Power Cost and the
power costs actually incurred. The True-up is 0.3579 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 J2!.\& the True-up.
The monthly Power Cost Adjustment applied to the Energy rate for Irrigation Service (Schedules
24 and 25) is 1.3159 cents per kWh, for Small General Service (Schedule 7) is 0.8477 cents per kWh and
Large Power Service (Schedule 19) is 0.8217 cents per kWh. The monthly Power Cost Adjustment
applied to the Energy rate of all other metered schedules and Special Contracts is 0.6039 cents per
kWh. The monthly Power Cost Adjustment applied to the per unit charges of the nonmetered schedules
is the monthly estimated usage times 0.6039 cents per kWh.
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May B;2_L 2004.
EXHIBIT NO, 1
CASE NO. IPC-O4-
G. SAID, IPCO
Page 44 of 44
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-O4-
.a.q
IDAHO POWER COMPANY
EXHIBIT NO.
G. SAID
PCA Reg ression Derivation
PCA REGRESSION DERIVATION
obs,vear runoff m(runoff)npsc predicted v regression statistics
1928 966,928 15,24,896,784 177 543 multiple r 8861
1929 689,911 15.50,873 982 71,886 172 r square 7852
1930 911,496 14,98,727,170 080,931 adjusted r square 7823
1931 381,175 14.106,958,582 345 159 standard error 148 522
1932 861 787 15.40 646,054 58,043 790 observations
1933 250,553 15.740,688 263,784 anova
1934 381 897 14.131 019,720 336 631
1935 172 748 14.103,166,102 77,994,972 regression
1936 136 066 15.45 68,134,235 803 973 residual
1937 195,479 14,67,351,698 77,726,475 total
1938 167,188 15.664 916 812 051 coefficients
1939 522,159 15,69,189,270 867,685 intercept 140 615,325
1940 342 590 15.60,822 409 176 628 x variable 1 (70,685,112)
1941 999 227 15.683 087 68,232 480
1942 977,822 15.42 33,478,159 56,673,167
1943 546,645 16.156 051 705 541
1944 579,035 15,57,457,371 195 857
1945 309,857 15.49 349,386 751 118
1946 055 496 15.634,128 131 365
1947 348,955 15.49 35,644,106 52,289,285
1948 895,433 15.192,016 45,834 203
1949 448,833 15.36,487 169 109,514
1950 849,217 15.16,413,270 567,964
1951 103,576 15.141 713 563 444
1952 10,862,977 16.22,402 752 (12 843,179)
1953 407 278 15.088,318 39,788,217
1954 554,042 15,56,282 988 866,767
1955 866,501 15,288,665 69,800 259
1956 902,304 15.602 283 128 749
1957 295,186 15,16,827,186 17,487,967
1958 496 672 15.839 082 26,920 132
1959 184,210 15.54,882,387 047 439
1960 357,605 15.891 892 63,999 270
1961 096 603 14,93,255,958 894,414
1962 076,278 15.44 952 360 55,510 195
1963 052,040 15.44 538,500 796,498
1964 384,427 15,11,281,426 058,143
1965 015,991 16.242,774 973 705
1966 273,937 15,83,086,380 76,799,715
1967 483,615 15,21,541 691 698,662
1968 361,950 15.33,490,176 75,760,097
1969 078 054 15.503,094 864 906
1970 586,665 15,748,587 669,269
1971 260,594 16,867 224 (17,539 886)
1972 267 498 15.384 317 815 013
1973 010,676 15,141,798 097,248
1974 976,606 16.24,672,812 373,224)
1975 101 832 16.910 962 959,742
1976 948,088 15.34,409,346 587,936
1977 161 615 14.856,791 89,938,639
1978 050,594 15.291 623 001 418
1979 840 423 15.63,731 656 70,108,305
1980 377,115 15.17.816,446 144,502
1981 055,248 15.55,844,377 570 750
1982 782 115 16,972 516 (75 864)
1983 10,702,685 16,(5,749,822) $(10 949,783)
1984 12,630,563 16.(8,366 250) $(33,722 175)
1985 636,055 15.29,873,368 898,022
1986 819,397 15,589,769 11,295 900
1987 826,920 14.802 567 079 946
1988 629,206 14,97,566,626 415 378
1989 617,913 15.156,115 60,924,464
1990 015,713 14.111,640 117 849,898
1991 771,215 14,115,906 144 737 951
1992 967,302 14.49 132 400 389 233 891
1993 085,398 15.494 407 43,590,308
1994 615,546 14,97,009,455 576,734
1995 779,568 15.25,980,878 35,390,675
1996 398,725 15.25,197,262 264 946
1997 908,172 16.915 497 (1,564 874)
1998 951 599 16.859 071 734 306
1999 985,776 15.443,802 142 760
2000 370,706 15.79,021,382 844 521
2001 392 435 14.120,608,324 212 152
2002 246,067 14.118,285,937 77,128,917 EXHIBIT NO, 2
averages 754 850 15.46 47,494 793 47,494 793 CASE NO. IPC-04-
SAID, IPCO
Page 1 of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-O4-
IDAHO POWER COMPANY
EXHIBIT NO.
G. SAID
National Weather Service
Water Supply Forecast
Water Supply Forecasts
Northwest River Forecast Center
Wednesday April 07 2004 at 21:36 GMT
Full month of observed precipitation
75% prec thru mid April then
Future precip applied at 100% of normal
Snow included in this run
Full complement runoff applied
UPPER COLUMBIA BASINS
Apr-04FINAL WATER SUPPLY FOR CASTS
FORECAST RUNOFF AVERAGE RO PREV YR CURR
STREAM AND STATION PERIOD PROBABLE MAXIMUM MINIMUM RUNOFF PERIOD RO TO
DATE
COLUMBIA RIVER
MICA RESERVOIR INFLOW,JAN-JUL 9170.10500.0 109 7850.9619.9079 2677 131
FEB-SEP 12300.13700.0 106 11000.12960.11800 2677 131
APR-SEP 11900.13200.0 106 10600.12500.11360 2677 131
REVELSTOKE,JAN-JUL 13400.14600.0105 12300.13880.12860 3763 128
ARROW LAKES INFLOW JAN-JUL 19700.21800.0 104 17700.20960.18580 5759 109
FEB-SEP 25000.27100.0 102 22900.26460.22700 5759 109
APR-SEP 23900.25900.0103 21800.25110.21650 5759 109
BIRCHBANK (1)JAN-JUL 35200.40500.0 104 30000.38930.34250 10140 109
APR-SEP 39600.44800.0103 34300.43500.37220 10140 109
GRAND COULEE,WA (1)JAN-JUL 53600.62100.45000.62900.54180 15170
APR-SEP 55500.64000.0100 46900.63990.52740 15170
ROCK ISLAND DAM BLO,WA (1)JAN-JUL 58900.68300.49500.68910.58540 16810
APR-SEP 60300.69700.0 100 50900.69540.56310 16810
THE DALLES NR,(1)JAN-JUL 84200.97800.70600.66 107300.87690 32280
APR-AUG 73400.87000.59900.93090.73770 32280
APR-SEP 77800.91400.64200.98650.77440 32280
KOOTENAI RIVER
LIBBY RES INFLOW (1)JAN-JUL 5290.6590.0 105 3990.6306.5187 1351
APR-AUG 5300.6600.0 106 4000.6248.5084 1351
APR-SEP 5630.6930.0 104 4330.6638.5340 1351
LIBBY,(1)JAN-SEP 6530.7990.0 101 5070.7936.6154 1476
APR-SEP 5940.7400.0 103 4480.7207.5582 1476
LEONIA,(1)APR-JUL 5830.7410.0 105 4250.7041.5608 1721
APR-SEP 6730.8310.0 102 5150.8125.6276 1721
BONNERS FERRY,APR-JUL 6360.7900.0 104 4810.7619.5943 1827
KOOTENAY RIVER
KOOTENAY LAKE INFLOW,JAN-JUL 13500.15700.11200.16010.13420 3604
APR-SEP 14000.16600.0 101 11400.16450.13430 3604
DUNCAN RIVER
DUNCAN RESERVOIR INFLOW, BC JAN-JUL 1740.2110.0 117 1360.1800.1696 540 143
FEB-SEP 2250.2630.0 114 1880.2305.2147 540 143
APR-SEP 2180.2550.0 115 1800.2227.2066 540 143
CLARK FORK
BLACKFOOT RIVER ABV , MT APR-SEP 485.815.0 116 154.704.617 268
MISSOULA ABV, MT APR-SEP 1120.1580.660.1595.1353 475
MISSOULA BLO, MT APR-SEP 2070.2770.1380.2962.2767 766
ST.REGIS, MT (1)APR-SEP 2780.3850.1710.3907.3591 1004
PLAINS NR, MT (1)APR-SEP 8190.10500.5910.11060.8624 1998
WHITEHORSE RAPIDS,(1)APR-SEP 9290.11900.6640.12460.9321 2324
BLACKFOOT RIVER
BONNER NR,APR-SEP 635.920.0 103 345.892.736 208
BITTERROOT RIVER
AT MOUTH, MT APR-SEP 955.1240.670.1364.1317 261
Apr-04FINAL WATER SUPPLY FOR E CASTS
FORECAST RUNOFF AVERAGE RO PREV YR CURR
STREAM AND STATION PERIOD PROBABLE MAXIMUM MINIMUM RUNOFF PERIOD RO TO
DATE
FLATHEAD RIVE
COLUMBIA FALLS NR,APR-SEP 1400.1750.1050.1801.1404 301
FLATHEAD RIVE
WEST GLACIER NR,APR-SEP 1340.1620.1050.1740.1418 234
FLATHEAD RIVE
HUNGRY HORSE RES IN (1)JAN-JUL 1680.2130.1240.2224.1817 364
APR-SEP 1580.2020.1140.2124.1692 364
Exhibit No.
Case No. IPC-O4-
G. Said, IPCO
Page 1 of 5
UPPER/MIDDLE COLUMBIA BASINS
Apr-O 4 FINAL WATER SUPPLY FOR CASTS
FORECAST RUNOFF AVERAGE RO PREV YR CURR
STREAM AND STATION PERIOD PROBABLE MAXIMUM MINIMUM RUNOFF PERIOD RO TO
DATE
FLATHEAD RIVER
COLUMBIA FALLS, MT APR-SEP 4420.5690.3150.5825.4553 919
FLATHEAD LAKE INFLOW,(1)APR-SEP 5100.6480.3720.6713.4984 1104
PRIEST RIVER
PRIEST RIVER,(1)APR-JUL 645.865.0 106 425.814.662 238
PEND OREILLE RIVER
PEND OREILLE LAKE IN,(1)APR-SEP 10100.13000.7220.13910.10350 3266
APR-JUL 9250.12200.6350.12740.9715 3266
BOX CANYON BLO,WA (1)APR-SEP 10400.13400.7460.14090.10850 3271
KETTLE RIVER
LAURIER NR, WA APR-SEP 1640.2000.0 101 1270.1972.1569 157
COEUR D' ALENE RIVE
ENAVILLE,ID (1)APR-SEP 615.810.0 104 420.778.419 428
APR-JUL 585.780.0 106 390.739.393 428
COEUR D' ALENE LAKE IN,APR-JUL 1940.2580.0 101 1310.2552.1367 1176
SPOKANE RIVER
SPOKANE, WA (1)APR-SEP 2180.2260.2100.2744.1623 1310
ST JOE RIVER
CALDER,APR-SEP 950.1180.720.1205.867 320
APR-JUL 895.1120.660.1136.814 320
OKANAGAN RIVER
TONASKET NR, WA (1)APR-SEP 1210.1770.0100 650.1766.847 444
SIMILKAMEEN RIVER
NIGHTHAWK NR, WA (1)APR-JUL 970.1330.605.1350.807 346 128
APR-SEP 1040.1410.680.1450.837 346 128
METHOW RIVER
PATEROS NR,WA (1)APR-SEP 715.960.470.985.674 255 143
CHELAN RIVER
LAKE CHELAN INFLOW,WA (1)APR-SEP 885.1060.710.1185.973 484 147
WENATCHEE RIVER
PESHASTIN, WA APR-SEP 1230.1760.0 108 705.1635.1263 698 110
YAKIMA AND MAINSTEM SNAKE BASINS
Apr-04FINAL WATER SUPPLY FOR CASTS
FORECAST RUNOFF AVERAGE RO PREV YR CURR
STREAM AND STATION PERIOD PROBABLE MAXIMUM MINIMUM RUNOFF PERIOD RO TO
DATE
YAKIMA RIVER
KEECHELUS LAKE IN, WA (1)APR-SEP 105.131. 0 78.133.108
CLE ELUM,APR-SEP 710.810.605.903.667 596
PARKER NR, WA APR-SEP 1540.1760.1320.1918.1554 1184
KACHESS RIVER
KACHESS LAKE INFLOW,WA (1)APR-SEP 95.115.76.120.
CLE ELUM RIVER
CLE ELUM LAKE INFLOW,(1)APR-SEP 350.405.295.448.353 247 104
NACHES RIVER
NACHES NR,APR-SEP 695.790.600.837.714 330
BUMPING RIVER
BUMPING LAKE INFLOW,WA (1)APR-SEP 112.130.95.134.100
TIETON RIVER
RIMROCK LAKE INFLOW,WA (1)APR-SEP 205.235.173.242.198
AHTANUM CREEKS
TAMPICO NR, WA APR-SEP 39.56.0 122 22.46.
SNAKE RIVER
JACKSON LAKE INFLOW,(1)APR-SEP 695.840.555.904.717 180
APR-JUL 630.770.485.815.639 180
PALISADES RES INFLOW,(1)APR-JUL 2390.2930.1850.3331.2288 878
HEISE NR,APR-JUL 2550.3160.1950.3561.2472 1075
SHELLEY NR,ID (1)APR-JUL 3380.4110.2650.4428.2899 1609
BLACKFOOT NR,(1)APR-JUL 3400.4160.2640.4604.
AMER.FALLS RES IN,(1)APR-JUL 1860.2920.795.3242.1071 1810
MILNER,APR-JUL 285.385.280.1228.130
KING HILL,(1)APR-JUL 1670.2620.710.3045.1416 2416
MURPHY NR,ID (1)APR-JUL 1750.2740.755.3092.1399 2590
WEISER,(1)JAN-JUL 5470.7220.3730.9793.5271 4194
APR-JUL 2640.4380.890.5765.3085 4194
BROWNLEE RES INFLOW APR-JUL 3130.5290.970.6313.3522 4561
HELLS CANYON,(1)APR-JUL 3250.5190.1300.6493.3743 4706
LOWER GRANITE RES IN,(1)JAN-JUL 21300.26200.16300.30020.23810 8941
Exhibit No.
Case No. IPC-O4-
G. Said , IPCO
Page 2 of 5
FEB-SEP 21900.26800.17000.30370.23940 8941
APR-JUL 15600.20500.10700.21550.16730 8941
UPPER SNAKE BASINS'
Apr-04FINAL WATER SUPPLY FORECA S T S
FORECAST RUNOFF AVERAGE RO PREV YR CURR
STREAM AND STATION PERIOD PROBABLE MAXIMUM MINIMUM RUNOFF PERIOD RO TO
DATE
GREY'S RIVER
PALISADES ABV,APR-SEP 240.310.170.394.292
SALT RIVER
ETNA NR, WY APR-JUL 198.300.97.342.176 137
HENRYS FORK
ASHTON NR,APR-JUL 465.585.0 102 345.571.378 366
ST. ANTHONY,APR-JUL 550.770.0 105 335.734.382 433
REXBURG NR,APR-JUL 1270.1620.0 104 930.1559.394 623
FALLS RIVER
SQUIRREL NR,(1)APR-JUL 315.380.245.386.187 107
TETON RIVER
ST. ANTHONY NR,APR-JUL 305.420.0 104 185.403.261 157
BIG LOST RIVER
MACKAY RESERVOIR INFLOW APR-JUL 88.146.0 103 31. 0 142.
WILLOW CREEK
RIRIE RESERVOIR INFLOW APR-JUL 41. 0 72.86.
PORTNEUF RIVER
TOPAZ,APR-SEP 59.80.37.95.
GOOSE CREEK
OAKLEY RES INFLOW,APR-JUL 23.37.0 128 29.
BIG WOOD RIVER
HAILEY,(1)APR-JUL 152.240.66.256.229
MAGIC RESERVOIR INFLOW,APR-JUL 128.245.11.291.147
LITTLE WOOD RIVER
CAREY NR,APR-JUL 45.75.15.87.
MIDDLE SNAKE BASINS
Apr-04FINAL WATER SUPPLY FORECA S T S
FORECAST RUNOFF AVERAGE RO PREV YR CURR
STREAM AND STATION PERIOD PROBABLE MAXIMUM MINIMUM RUNOFF PERIOD RO TO
DATE
BRUNEAU RIVER
HOT SPRING NR,APR-JUL 137.235.0 113 38.208.112
OWYHEE RIVER
OWYHEE RES INFLOW MAR-JUL 485.695.0 113 275.613.158 377
OWYHEE RES OUTFLOW APR-JUL 24.185.217.
BOISE RIVER
TWIN SPRINGS NR,(1)APR-JUL 485.605.370.636.586 193
BOISE NR,(1)APR-JUL 970.1270.675.1414.1129 455
PARMA NR,APR-JUL 85.270.46.593.195 325
S. F.BOISE RIVER
ANDERSON RNCH RES IN,(1)APR-JUL 350.455.245.542.393 131
MALHEUR RIVER
DREWSEY NR,MAR-JUL 96.130.0 118 61. 0 110.
N. F. MALHEUR RIVER
BEULAH RES INFLOW,(1)MAR-JUL 70.87.0 107 54.81.
PAYETTE RIVER
HORSESHOE BEND NR,(1)APR-JUL 1150.1530.780.1617.1490 497
EMMETT NR,APR-JUL 705.1120.330.1246.1177 507
DEADWOOD RIVER
DEADWOOD RES INFLOW,(1)APR-JUL 97.122.72.134.133
PAYETTE RIVER
CASCADE RES INFLOW,(1)APR-JUL 370.490.255.495.530 141
WEISER RIVER
WEISER NR,(1)APR-JUL 270.445.0 114 95.391.369 288
BURNT RIVER
HEREFORD NR,MAR-JUL 44.59.0 116 30.51.
LOWER SNAKE AND CENTRAL OREGON BASINS
Apr-04FINAL WATER SUPPLY FORECA S T S
FORECAST RUNOFF AVERAGE RO PREV YR CURR
STREAM AND STATION PERIOD PROBABLE MAXIMUM MINIMUM RUNOFF PERIOD RO TO
DATE
POWDER RIVER
Exhibit No.
Case No. IPC-O4-
G. Said, IPCO
Page 3 of 5
ROGUE RIVER
RAYGOLD,APR-SEP 810.
JAN-JUL 1450.
CHEWAUCAN RIVER
PAISLEY NR,MAR-JUL 63.
SILVIES RIVER
BURNS NR,MAR-JUL 89.
APR-SEP 68.
Forecasts are selected from those prepared by:
National Weather Service
Natural Resource Conservation Service
B. C. Hydro and Power Authority.
Project inflow forecasts have been coordinated with the
U. S. Army Corp of Engineers and U. S. Bureau of Reclamation.
All forecasts are in thousands of acre-feet.
All averages are for the period 1971 through 2000
NOAA/NWS/Northwest River Forecast Center
NNNN
940.0 106
1580.0 100
99.0 111
153.0 119
131.0 132
685.889.
1330.1584.
27.89.
26.129.
99.
786
1369
1127
1127
National Weather Service
Northwest River Forecast Center (NWRFC)
5241 NE 122nd Avenue
Portland , Oregon 97230-1089
Telephone: [phone]
Last Modified: April 13, 2004
Exhibit No.
Case No, IPC-04-
G. Said , IPCO
Page 5 of 5
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-O4-
IDAHO POWER COMPANY
EXHIBIT NO.
G. SAID
PCA Deferral Report
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-O4-
IDAHO POWER COMPANY
EXHIBIT NO.
G. SAID
IPUC Order No. 29334
Office of the Sc:cretuy
Service Da
September 16. 2003
BEFORE THE IDAHO PUBLIC UI1LITIES COMMISSION
IN THE MA TIER OF THE APPLICATION OF
IDAIIO POWER COMPANY FOR AUTHORITY
TO IMPLEMENT A POWER COST
ADJUSTMENT (PCA) RATE FOR ELECTRIC
SERVICE FROM MAY 16, 1003 THROUGH MAY J~200~
CASE NO. IPC-E-O3-S
ORDER NO. 29334
In June 2003, the Commi$Sion urged the parties to move expeditiously S(t that
contested issues invohing the proper amount of normali2ed energy to calculate true-up and class
deferral rates could be resolved in atimcly manner. Order No. 29258 at 2. Following several
months of negotiatio~thepartiesreacbed an agreement regarding the outstanding issues in this
PCA docket. On August 20, 2003, Idaho Power Company CUed a Motion fur A~eptance of
Settlement on behalf of itself, Commission Staff, the Industrial Customers of Idaho Power
(JCIP), and the Idaho Irrigation Pumpers Association (Irrigators). After reviewing the record and
the provisions of the Stipulation, the Commission accepts the Stipulation as a fair. juSt and
reasonable resolution to the contested issues remaining in this ease.
PROCED URALB ACK GROUND
Idaho Power is an eJootric utility engaged in the generation, transmission, distribution
and sale of electric energy and provides retail elet.1ric service to approximately 380,000
customers in southern (daho and eastem Oregon. On April15,2003,ldaho Power Company
filed an Application to decrease its electric rates under theBIU1ua1 Power Cost Adjustment (PCA)
mechanism fust approved by the C~mmission in 1993. In Order No. 29243, the Commission
approved the fates proposed in the Company's Application (with one adjustment) effective May
16, 2003. subject to refund and interest. In addition, the Commission set a preheating conference
10 schedule six disputed issues valucdat approximately $5.1 million for evidentiary hearing.
These six issues included:!) pricing of real-time transactions between Idaho Power and
IDACORPEnergy (IE); 2) recovery of m- Tri State Transmission costs; 3) Company sharing of
the anticipated FERC settlement; 4) continuance of payment for IE management contract
benefits; 5) the proper amount of nonnalized energy to compute the true-up rate; and 6) the
ORDER NO. 29334
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 1 of 7
proper amount of normaJ.jzed energy to compute the rates to be paid on PCA amounts deferred
from the prior PCA period Order No. 29243 at 1 O.
At the preheating conference held May 30 2003, Idaho Power, Staff, the Irrigators,
m1d ICIP entered appearances. Although the Commission had intended to immediately set a date
for an evidentiary hearing at the preheating conferen-ce, the parties proposed an alternative with
the hope that an evidentiary hearing could be avoided.
To funher explore the possibility of settlement and achieve a quicker resolution than
might be available through an e".identiary hearing, the Commission adopted the parties' proposaJ
to move the following four issues to Case No. IPC- E-O 1-16 for further proceedings: 1) pricing of
real-time tranSactions between IdahQ Power and IE; 2) f1'COvery of IE-Tri State Transmission
costs; 3) Company sharing of the anticipated FERC settlement; and 4) continuance of payment
for IE management contract benefits. Order No. 29258. Because real-time afftliate pricing,
ttansmission costs, and resolution of outstanding !E matters are alread)' part of ongoing
settlement discussions in Case No, IPC-E-O 1-16, the parties felt it would be more efficient to
consolidate these issues under that case num~r. The Commission directed the remaining two
issues involving the proper amount of normalized energy to calculate true-up and class deferral
rates It.) continue undathiscase number (lPC-E..()3-5). !d.
PROPOSED SET1'LEMENT
According to the Stipulation. the parties discussed three major issues. First, the
parties sought to determine the appropriate kWh sales level to use as the denominator for
computing the true-up rate for this case and future PCA periods. Second, Idaho Power proposed
inclusion of a can-ying charge on the unamortized balances during future true-up collection and
refund periods. The JCIP andkrigators were also concerned that collection of their allocated
true-up amounts may be too great if 1993 normalized sales were used rather than the 2000
normalized sales levels initially used to compute the deferral amount.
In the signed settlement document, all four partit$ agreed that:
1. The t:urrently-approved PCA rates win remain in effect through May 15,
2004. Le.., the remainder of this 2003-2004 PCA year,
2. The PCA methodology will be modified to include a UUc-up of the true--
up. At the time tbe Company makes its April 2004 PCA application, the
Company will compute the amount of any under-col1cction or over.
collection of the $38.million true-up anlount approved by the
ORDER NO. 29334
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 2 of 7
Commission in Order No. 29243. This amount will then be applied as a
cr~t (ot d~bit) against the 2004--2005PCA ("true.,up of the ~up
The approved PeA methodology will thereafter include II true-up of the
true-up foreacb succeeding PCA year.
3. Carrying charges on the unamortized balance at the rate of 2% per annum
(the currently approved rate for the true-up deferral balance
accwnwation) win be included during the 2004.2005 true-up of the true-
up period. Thereafter, carrying charges wilt be determined for either the
truc--up collection period or true-up refund period. whichever OCCUI$ from
year to year. Idaho Power wiUcompute the carrying charges using the
same interest rate the Conunission annually determines to be appropriate
tor the ttue-up deferral balance accumulation. The methodology for
computing carrying costs is more particularly described in Appendix 1 to
the Settlement.
4. For Schedule 7, 19, and 24 customers, the tTUe~up of the true-up will not
be applied to the 516 million total of class-specific adders from the 2002-
2003 PCA year. Instead, the customers in those classes will receive a
credit during the 2004-2005 PCA year which will be computed based on
the difference between the true-up rate credit computed under the
currently-approved PCA rate (using 1993 sales data) and the rate credit
that would have been computed using 2000 nonnaHzcd kilowatt-hour
sales for each of the three classes. Attachment 2 to the Settlement
describes this process in more detail and shows the 2004-2005 rate credit
on a cents per kilowatt-hour for Schedule 7, 19 and 24 customers.
5. Beginning with the April 2004 PCA application, the Company VtiU make
its annual PCA application Utilizing its best estimate of the totalldaho
jurisdictional sales that wiUbe made during the ensuing PCA year rather
than a sales constant set in a gcncrnl reVenue requirement case. The
intent of this change to the approved PCA methodology is to set a firm
sales denominator that will minimize the magnitude of subsequent true-
ups of the true-up.
According to the Motion for Acceptance of Settlement, all parties to this case are
signatories to the Stipulation, which is intended to be an integrated documenLFurthermore, the
pmies agree that the Stipulation is in the public interest and aU the tenns of the Stipulation are
fair, just and reasonable. The parties request the Commission issue an Order acupting the
Stipulation in settlement of all remaining issues in this case. M a result. the parties do not
believe that an evidentiary hearing is required according to Procedural Rule 214.
ORDER NO. 29334
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID , IPCO
Page 3 of 7
COMMtSSIONPINDtNGS AND DISCUSSION
Pursuant to Commission Rule 274 we shall decide whether to accept the Stipulation
based on the record cuuently before us. mAPA 31.01.01.274. The record is substantial and all
parties that participated in the settlement negotiations in this case have signed this Stipulation,
AccoIdingly, we find funher proceedings arc not necessary for us to determine whether we
should accept this Stipulation.
Normalized kWh Sales Level
The present PCAmethodology uses the 1993 normalized kWh sales level as the
denominator for computing the true-up rate. Because the last two PCAyears deviated from the
methodology by using 1999 and 2000 normalized sales levels respectively, Staff and brigators
argued for using more recentnonnalized sales data during the 2003-2004 PCAperiod as wen,
Due to variations in energy consumption, actual sales to Idaho juri&dictional customers during
any PCA year will never match the Commission-approved 1993 denominator of 10.802,636
MWh. Order No. 25880.Consequently, the parties agreed to modify the currentPCA
methodology to eliminate under-coUection.over-collection. under-refunding, and over-refunding
of the authorized true-up amounts by ..truing up the true--up.Beginning in its .2004 PCA
application. the Company will make its annual PCA application using its best estimate of the
total Idaho jurisdictional sales that will be made during the ensuing PCA year rather than using
sales constant set in a general rate casc.
After reviewing the Stipulation signed by the parties, the Commission finds that it
embodies an appropriate resolution of the proper amoWlt ofnom1alized energy to ca1culate the
troe--up of the true-up rate in this case and true-up rates ona'8oing forward basis. We also find
that it is appropriate for the Company s future PCA applications to use a,best estimate of total
Idabo jurisdictional sales for theupcomiug PCA year to minimize the magnitude of the true-up
of the true-up. The Stipulation s true-up of the true-up will then eliminate any remaining
imbalance. Thus, ratepayers ",i11 pay for the actual amount of kWh sold by Idaho POWer to meet
native load requirements - no mo~. no 1ess. The C',ammission finds that these changes '0%111
allow an up-to-date normalized sales level to be used even if several years have passed since a
rate case. The Commission believes that these permanent changes to the PCA methodology win
I This Order was later adjuated in Case No. IPCE.98-S for a change in theFMC contract. Order No. 275l6.
ORDER NO. 29334
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 4 of 7
better ensure rdaho Power and itS customers wilt both be treated fairly, particularly during
periods of volatile power supply costs and energy consumption.
Class Deferral Rates
Because payment of their prior true-up amounts were deferred, customers receiving
service under Schedule 7 (Small General Service), Schedule 19 (Large Power Service). and
Schedule 24 (Irrigation Service) have class-spedfic adders that are still to be recovered during
the 2003-2004 PCA year. As a result and unlike most PCA years. these classes have a diffQ1"cnt
PCA true-up rate than do the othQ1" eustomQ1" classes. Thebrigators and JCIP were concerned
that collection of their allocated true-up amountS may be too great if 1993 normalized sales
levels were used to compute the deferral amount rather than the 2000 nonnalized sales levels
initially used during the 2002-2003 PCA year.
As part of the Stipulation, the parties agreed that the currently-approved PCA rates
should remain in effect through May 15. 2004. Le,. the remainder of this 2003-2004 PCA year.
Furthermore. Schedule 7. 19. and 24 customers that have class-specific adders wil1receive a
credit during the 2~2005 PCA year based on the difference betwecn the true-up rate credit
computed under the currently.;approved PCA (using 1993sa1es data) and the rate credit that
would have been computed using 2000 l1onnalizedkilowatt-hoursales for each of the three
classes.
To minimit.e COnfusiO11 and implementation w\te$.the Commission agrees that rates
should remain constant through this current PCA year. Given the unique circumslances of this
case. we believe tbe Stipulation reasonably TCsclvcs the concerns of thepartics regarding the
rates used'to colled class deferrals. Thus, we find it reasonable and appropriate to adopt the
partics' settlement on this issue.
CarrviD2Chanles
The present PCA methodology does not anow computation of carrying charges
during the tme-up collection or true-up refund period. When the PCA was first developed. the
parties agreed that over time the true-up collections and refunds would offset each other. Thus
computation of carrying charges during the term of actual raterccovcry would be symmetrical
and therefore unnecessary. As Doted in the Stipulation, true-up collections inrcccnt years have
not been offset by large tnle-up refunds. Thus, the parties have agreed to include a carrying
charge on the unamortized balance during true-up collections and refunds using the same interest
ORDER NO. 29334
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 5 of 7
this Case No. fPC.E-O3-5. Within seven (7) days after any person has petitioned for
reconsideration, any other person may cross-petition for reconsideration, See Mohr) Code ~ 61-
626.
DONE by Order of the Idaho Public Utilities Commission at Boise, Idaho this /1,""
day of Seplember2003.
ATfEST:
O:fPCEO~ Jn4
ORDER NO, 29334
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 7 of 7
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-O4-
tZ#
IDAHO POWER COMPANY
EXHIBIT NO.
G. SAID
Original & Legislative Schedule
IDAHO POWER COMPANY THIRTEENTH REVISED SHEET NO. 55-
CANCELS
TWELFTH REVISED SHEET NO. 55-I.P.C. NO. 26, TARIFF NO.1 01
SCHEDULE 55
POWER COST ADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all Idaho retail Customers served
under the Company s schedules, to the primary portion of the FMC Special Contract. and to all other
Idaho retail 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 0.7315 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 1.0092 cents per kWh.
TRUE-UP AND TRUE-UP OF THE TRUE-
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 0.3540 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 .12.!.!& the True-ups.
The monthly Power Cost Adjustment applied to the Energy rate for Irrigation Service (Schedules
24 and 25) is 0.5228 cents per kWh, for Small General Service (Schedule 7) is 0.5850 cents per kWh and
Large Power Service (Schedule 19) is 0.5817 cents per kWh. The monthly Power Cost Adjustment
applied to the Energy rate of all other metered schedules and Special Contracts is 0.6039 cents per
kWh. The monthly Power Cost Adjustment applied to the per unit charges of the nonmetered schedules
is the monthly estimated usage times 0.6039 cents per kWh.
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31 , 2005.
IDAHO
Issued - April 15, 2004
Effective - June 1, 2004
EXHIBIT NO.
CASE NO. IPC-04-
G. SAID, IPCO
Page 1 of 2
IDAHO POWER COMPANY TWELFTH REVISED SHEET NO. 55-
CANCELS
ELEVENTH REVISED SHEET NO. 55-I.P.C. NO. 26. TARIFF NO. 101
SCHEDULE 55
POWER COST ADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all Idaho retail Customers served
under the Company s schedules. to the primary portion of the FMC Special Contract, and to all other
Idaho retail 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 and FMC secondary load revenue. The Base Power Cost is
52380.7315 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 G.+9++ 1 .0092 cents per kWh.
TRUE-UP AND TRUE-UP OF THE TRUE-
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 35790.3540 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-up~.
The monthly Power Cost Adjustment applied to the Energy rate for Irrigation Service (Schedules
24 and 25) is 1.31590.5228 cents per kWh, for Small General Service (Schedule 7) is 84770.5850 cents
per kWh and Large Power Service (Schedule 19) is 82170.5817 cents per kWh. The monthly Power Cost
Adjustment applied to the Energy rate of all other metered schedules and Special Contracts is 0.6039
cents per kWh. The monthly Power Cost Adjustment applied to the per unit charges of the nonmetered
schedules is the monthly estimated usage times 0.6039 cents per kWh.
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31, ~2005
EXHIBIT NO.
CASE NO. IPC-O4-
G. SAID , IPCO
Page 2 of 2
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-O4-
DAHO POWER COM P ANY
EXHIBIT NO.
G. SAID
Summary of Revenue Impact
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,
85
4
,
06
7
(1
8
,
30
1
.
8
2
1
)
52
3
,
55
2
,
24
6
47
.
(3
.
38
)
%
So
e
c
i
a
l

C
o
n
t
r
a
c
t
s
:
Mi
c
r
o
n
63
6
,
96
7
,
67
0
19
,
38
4
,
93
5
19
,
38
4
,
93
5
30
.
4
3
00
%
J
R

S
i
m
p
l
o
t
18
6
,
68
4
,
66
5
75
9
,
96
0
75
9
,
96
0
30
.
00
%
DO
E
20
3
.
08
4
.
14
6
84
8
.
83
9
84
8
.
83
9
28
.
00
%
To
t
a
l

S
p
e
c
i
a
l

Co
n
t
r
a
c
t
s
02
6
,
73
6
,
4
8
1
30
,
99
3
,
73
4
30
.
99
3
,
73
4
30
.
00
%
To
t
a
l

Id
a
h
o

Re
t
a
i
l

S
a
l
e
s
40
1
.
6
7
5
12
,
09
6
,
87
1
.
5
1
3
57
2
,
84
7
.
80
1
(1
8
,
30
1
.
8
2
1
)
55
4
,
54
5
.
98
0
45
.
(3
.
19
)
%
EX
H
I
B
I
T

N
O
.
CA
S
E

N
O
.

I
P
C
-
O4
-
G.

S
A
I
D
,
I
P
C
O