20100416Tatum Direct.pdf

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BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPAN FOR
AUTHORITY TO IMPLEMENT POWER COST
ADJUSTMENT ("PCA") RATES FOR
ELECTRIC SERVICE FROM JUNE 1,
2010, THROUGH MAY 31, 2011.
CASE NO. IPC-E-10-12
IDAHO POWER COMPAN
DIRECT TESTIMONY
OF
TIMOTHY E. TATUM
1 Q.Please state your name and business address.
2 A.My name is Timothy E. Tatum and my business
3 address is 1221 West Idaho Street, Boise, Idaho.
4 Q.By whom are you employed and in what
5 capacity?
6 A.I am employed by Idaho Power Company ("Idaho
7 Power" or "Company") as a Manager of Cost of Service in the
8 Pricing and Regulatory Services Department.
9 Q.Please describe your educational background.
10 A.I have earned a Bachelor of Business
11 Administration degree in Economics and Master of Business
12 Administration degree from Boise State University. I have
13 also attended electric utility ratemaking courses,
14 including "Practical Skills for The Changing Electrical
15 Industry," a course offered through New Mexico State
16 university's Center for Public Utilities, "Introduction to
1 7 Rate Design and Cost of Service Concepts and Techniques"
18 presented by Electric Utilities Consultants, Inc., and
19 Edison Electric Institute's "Electric Rates Advanced
20 Course."
21 Q.Please describe your work experience with
22 I daho Power.
23 A.I began my emplOYment with Idaho Power in
24 1996 as a Customer Service Representative in the Company's
TATUM, DI 1
Idaho Power Company
1 Customer Service Center where I handled customer phone
2 calls and other customer-related transactions. In 1999, I
3 began working in the Customer Account Management Center
4 where I was responsible for customer account maintenance in
5 the area of billing and metering.
6 In June of 2003, after seven years in customer
7 service, I began working as an Economic Analyst on the
8 Energy Efficiency Team. As an Economic Analyst, I
9 maintained proper accounting for Demand-Side Management
10 ("DSM") expenditures, prepared and reported DSM program
11 accounting and acti vi ty to management and various external
12 stakeholders, conducted cost-benefit analyses of DSM
13 programs ,and provided DSM analysis support for the
14 Company's 2004 Integrated Resource Plan ("IRP").
15 In August of 2004, I accepted a position as a
16 Pricing Analyst in Pricing and Regulatory Services. As a
1 7 Pricing Analyst, I provided support for the Company's
18 various regulatory activities, including tariff
19 administration, regulatory ratemaking and compliance
20 filings, and the development of various pricing strategies
21 and policies.
22 In August of 2006, I was promoted to Senior Pricing
23 Analyst. As a Senior Pricing Analyst, my responsibilities
24 expanded to include the development of complex financial
TATUM, DI 2
Idaho Power Company
1 studies to determine revenue recovery and pricing
2 strategies, including the preparation of the Company's
3 cost-of-service studies.
4 In September of 2008, i was promoted to my current
5 position, Manager of Cost of Service. As Manager of Cost
6 of Service I oversee the Company's cost-of-service
7 acti vi ties such as power supply modeling, jurisdictional
8 separation studies, class cost-of-service studies, and
9 marginal cost studies.
10 Q.What is the Company requesting in this case?
11 A.The Company is requesting that the
12 Commission approve its quantification of the 2010 Power
13 Cost Adjustment ("PCA") decrease and an increase to base
14 rates in compliance with the terms of the settlement
15 stipulation approved by Order No. 30978 ("Stipulation").
1~ The net effect of these two rate adjustments is an overall
17 decrease in revenue to be recovered from customer rates of
18 approximately $58 million.
19 Q.Please describe the Company's testimony in
20 this proceeding?
21 A.The Company has three wi tnesses in this
22 proceeding. Mr. Scott wright provides testimony that
23 quantifies the initial 2010 PCA amount that would have been
24 proposed absent the Stipulation. This initial PCA amount
TATUM, DI 3
Idaho Power Company
1 provides the basis for quantifying the 2010 PCA rate
2 reduction to be shared by the Company and its customers in
3 compliance with the Stipulation. Mr. wright then quantifies
4 a revised 2010 PCA amount based upon an adjusted base level
5 of net power supply expenses ("NPSE"). Mr. Tom Harvey
6 provides testimony that explains why the increased costs of
7 fuel for the Jim Bridger power plant are reasonable and
8 prudent. Mr. Harvey's testimony is presented to comply
9 with the Commission's directions in Order No. 31042.
10 My testimony presents the development of the base
11 rate increases resulting from the sharing of the 2010 peA
12 reduction according to the Stipulation. Further, my
13 testimony will describe the combined revenue impact of the
14 proposed 2010 PCA reduction and base rate increase to
15 become effective June 1, 2010. Finally, my testimony will
16 detail the implementation of the rate design provisions
17 agreed to by the parties in the Stipulation.
18 Q.Have you prepared any exhibi ts as part of
19 your testimony?
20 A.Yes. I have prepared the following exhibits:
21 . Exhibi t No. 2 - Sumary of Revenue Impact
22 . Exhibi t No. 3 - Revised Tari f f Sheets
TATUM, DI 4
Idaho Power Company
1 BACKGROUN
2 Q.Please provide an overview of the events
3 that led to the Stipulation.
4 A.On August 28, 2009, Idaho Power filed a
5 Notice of Intent to file a general rate case. In parallel
6 with its general rate case preparations, the Company met
7 with the Idaho Public Utilities Commission ("IPUC") Staff
8 and parties that typically intervene in general rate case
9 proceedings ("Parties") on September 21, 2009, to discuss
10 the potential for utilizing accumulated deferred investment
11 tax credits ("ADITC") and providing an earnings sharing
12 opportunity as a way to stabilize the Company's earnings
13 and eliminate return on equity ("ROE") as a contested issue
14 in the upcoming rate case.During that meeting, the Staff
15 and several other Parties expressed a desire to implement a
16 moratorium on new general rate case filings.
17 As a result of several follow-up meetings, the
18 Parties reached a settlement agreement under which Idaho
19 Power would not file a general revenue requirement case
20 that would result in a general rate adjustment to become
21 effective prior to January 1, 2012 ("the moratorium"). The
22 moratorium would apply only to base rate adjustments and
23 would exclude the (1) annual PCA, (2) annual Fixed Cost
24 Adjustment,(3) annual advanced metering infrastructure
TATUM, DI 5
Idaho Power Company
1 rate adjustment, (4) annual pension investment recovery,
2 (5) Energy Efficiency Rider adjustment, (6) recovery of
3 governmentally imposed fees, such as franchise agreements
4 or local improvement district fees, and (7) increased
5 funding for low-income weatherization.Further the
6 moratorium would allow for a sharing of an anticipated
7 reduction in the 2010 PCA rates in the form of a base rate
8 increase effective June 1, 2010.
9 Q.How does the Stipulation address the
10 utilization of ADITC and provide an earnings sharing
11 opportunity as a way to stabilize the Company's earnings?
12 A.The Parties agreed that it would be just and
13 reasonable for the Commission to use a 10.5 percent ROE in
14 any Idaho Power regulatory matter to be determined by the
15 Commission before December 31, 2011. For the years 2009,
16 2010,and 2011,if Idaho Power's actual Idaho
17 jurisdictional earned return on year-end equity falls below
18 9.5 percent, the Company will be permitted to modify its
19 amortization methods (i. e., accelerate the amortization) of
20 state and federal accumulated deferred income tax credits
21 in an amount up to $45 million over the three-year period
22 that would allow the Company to achieve a maximum actual
23 ROE of 9.5 percent for the Idaho jurisdiction.The amount
TATUM, DI 6
Idaho Power Company
1 that could have been used to increase the actual 2009 ROE
2 to no more than 9.5 percent was $15 million.
3 Idaho Power did not utilize any of the potential $15
4 million of accelerated amortization of ADITC in 2009. The
5 unused amount will be carried forward for use in subsequent
6 years through 2011. Per the Stipulation, the accelerated
7 amortization of ADITC cannot be greater than $25 million in
8 anyone year.
9 if the Company's actual earned return on year-end
10 equity for the Idaho jurisdiction during 2009, 2010, or
11 2011 exceeds 10.5 percent, amounts in excess of a 10.5
12 percent return will be shared equally between the Company's
13 Idaho customers and the Company's shareholders.The Idaho
14 jurisdictional ROE for 2009 did not exceed 10.5 percent and
15 therefore no sharing will take place in 2010. Any future
16 shared earnings which are allocated to customers will be
17 used to reduce customer rates.
18 Q.Please describe the anticipated PCA
19 reduction sharing provisions included in the Stipulation.
20 A.The Company and Parties anticipated that the
21 June 2010 PCA rate calculation to adjust rates beginning
22 June 1, 2010, would result in a substantial reduction in
23 the PCA rates.Further, sharing the PCA rate reduction
24 between the Company and its customers would allow the
TATUM, DI 7
Idaho Power Company
1 Company to implement the moratorium.The Parties agreed
2 that the 2010 PCA computation would be processed and
3 allocated according to a prescriptive approach allowing
4 base rate increases to be filed simultaneously with the
5 annual PCA filing on April 15, 2010.
6 The amount of any PCA reduction up to and including
7 the first $40 million of any 2010 PCA rate reduction will
8 be allocated equally between customers and the Company.
9 All of the portion of any 2010 PCA rate
10 reduction that is above $40 million,and up to and
11 including $60 million, will be allocated to customers. The
12 customers'share of this PCA rate reduction will be
13 allocated to customers as a direct customer rate reduction
14 in the 2010 PCA rate change.
15 The portion of any 2010 PCA rate reduction which
16 exceeds $60 million will be applied to absorb any increase
17 in the base level for net power supply expenses reviewed by
18 the Parties and approved by the Commission.
19 Should the 2010 PCA rate reduction exceed the $60
20 million amount plus the adjustment to the base level for
21 net power supply expenses, the next $10 million of any such
22 2010 PCA rate reduction will be allocated equally between
23 customers and the Company in the same manner as the first
24 $40 million.
TATUM, DI 8
Idaho Power Company
1 The portion of any PCA rate reduction which exceeds
2 (1) the sum of $60 million, plus the (2) amount of the
3 increase in the base level for NPSE approved by the
4 Commission, and (3) the final $10 million shared equally
5 between the Company and customers, will be allocated 100
6 percent to customers.
7 IMPLEMATION OF THE STIPULTED SHING PROVISIONS
8 Q.Has the Company calculated the amount of the
9 PCA decrease to be shared by the Company and customers?
10 A.Yes. Company witness Scott wright has
11 prepared the initial 2010 PCA amount based upon the
12 currently approved 2008 base NPSE. That is, Mr. Wright has
13 calculated the 2010 PCA amount that would have been
14 proposed by the Company absent the Stipulation. The
15 difference between current PCA revenue of $188,847,304 and
16 the revenue amount of $102,288,923 required under Mr.
17 Wright's 2010 PCA calculations yields an initial PCA
18 reduction of $86,558,381.
19 Q.Please describe how the approximately $87
20 million PCA reduction is to be shared by the Company and
21 customers according to the settlement Stipulation
22 provisions.
23 A.The Company has allocated the approximately
24 $87 million PCA decrease in compliance with the five-step
TATUM, DI 9
Idaho Power Company
1 allocation process detailed in the Stipulation. The first
2 $40 million of rate reduction has been allocated equally
3 between customers and the Company in the first allocation
4 step. In the second allocation step, the next $20 million
5 has been allocated directly to customers for a total of $40
6 million of direct customer rate reduction in the 2010 PCA
7 rate change.
8 Q.Please describe the implementation of the
9 third allocation step of the Stipulation's 2010 PCA rate
10 reduction sharing process.
11 A.As described earlier in my testimony, the
12 third step of the Stipulation's PCA rate reduction
13 allocation process allows for the portion of the 2010 PCA
14 reduction that exceeds the $60 million allocated in the
15 first two steps to be applied to absorb any increase in the
16 base level for NPSE reviewed by the Parties and approved by
17 the Commission. In this case, the portion of the 2010 PCA
18 reduction that exceeds the $60 million allocated in the
19 first two steps is $26,558,381.
20 Q.Has the Commission approved an increase to
21 base level NPSE to be used in this PCA filing?
22 A.Yes. On April 13, 2010, the Commission
23 issued Order No. 31042 in Case No. IPC-E-l0-0l approving an
24 increase to the Idaho jurisdictional base level NPSE of
TATUM, DI 10
Idaho Power Company
1 $63,701,694, provided that the PCA decrease would allow for
2 such an increase under the Stipulation.
3 Q.What portion of the remaining PCA reduction
4 of $26,558,381 must be applied to absorb the Commission-
5 approved increase to base level NPSE of $63,701,694?
6 A.An increase to base level NPSE of
7 $63,701,694 requires that $3,567,390 of the remaining PCA
8 reduction be allocated to the Company. The approximately
9 $3.6 million recognizes that 100 percent of the $63,701,694
10 will be collected through base rates as opposed to the 95
11 percent recovery that would otherwise be allowed through
12 the PCA. In other words, customers are only impacted by
13 five percent of any change in base level NPSE. However, it
14 is important to note that the $3,567,390 adjustment in this
15 case is not exactly five percent of the $63,701,694 because
16 the ratio of Idaho jurisdictional sales to total system
17 sales for the 2010/2011 PCA test period is not equal to the
18 Idaho jurisdictional allocation factor used to determine
19 the base level NPSE amount of $63,701,694 in Case No. IPC-
20 E-l0-0l.
21 Q.Please describe how the remaining
22 $22,990,992 has been allocated to customers and the Company
23 in the final two steps of the Stipulation's 2010 PCA rate
24 reduction sharing process?
TATUM, DI 11
Idaho Power Company
1 A.The fourth step of the Stipulation's 2010
2 peA rate reduction sharing process allows for the next $10
3 million of the remaining $22,990,992 of 2010 PCA rate
4 reduction to be allocated equally between customers and the
5 Company. The final $12,990,992 was then allocated 100
6 percent to customers.
7 Q.What is the final net customer rate
8 reduction resul ting from the implementation of the
9 Stipulation's PCA rate reduction allocation process?
10 A.The implementation of the Stipulation's PCA
11 rate reduction allocation process results in net rate
12 reduction for customers in the amount of $57,990,992 to
13 become effective June 1, 2010.
14 Q.Has the Company recalculated the 2010 PCA
15 amount after applying the $63,701,694 increase to the base
16 level NPSE?
17 A.Yes. Mr. wright has recalculated the 2010
18 PCA amount after applying the $63,701,694 increase to the
19 base level NPSE. As a result of this adjustment, the
20 revised 2010 PCA amount proposed by the Company is
21 $42,154,618, a decrease of $146,692,686 from the current
22 PCA amount of $188,847,304. Mr. Wright provides the details
23 of his calculation in his direct testimony. The revised
24 2010 PCA decrease of $146,692,686 from the initial
TATUM, DI 12
Idaho Power Company
1 $86,558,381 preserves the overall $58 million reduction for
2 cus tomers .
3 Q.What is the total base rate increase
4 resulting from the implementation of the Stipulation's PCA
5 rate reduction allocation process?
6 A.The total base rate increase resulting from
7 the implementation of the Stipulation's PCA rate reduction
8 allocation process is $88,701,694 ($20,000,000 + $63,701,694
9 + $5,000,000 = $88,701,694).
10 Q.Please describe the manner in which the
11 $88,701,694 increase to base rates has been allocated to
12 customer classes consistent with the Stipulation.
13 A.The $88,701,694 permanent increase to base
14 rates has been allocated to all customer classes and
15 special contract customers on a uniform percentage basis.
16 Q.Have you prepared an exhibit that details
17 the combined impact of the final 2010 PCA rate reduction
18 and base rate increase?
19 A.Yes. Exhibit No. 2 details the combined
20 impact of the final 2010 PCA rate reduction and base rate
21 increase. The proposed 2010 PCA amount is $42,154,618, a
22 decrease of $146,692,686 from the current PCA amount of
23 $188,847,304. The proposed base rate increase is $88,700,982
24 (the initial $88,701,694 base rate revenue increase changes
TATUM, DI 13
Idaho Power Company
1 slightly due to rounding that occurs in the rate design
2 process), which reduces the PCA decrease of $146,692,686 to
3 retain the final net customer rate reduction of $57,991,704
4 (again,the initial calculated net rate reduction of
5 $57,990,992 changes slightly due to rounding that occurs in
6 the rate design process) .
7 Q.Does the proposed adjustment to revenue from
8 base rates have an effect on the level of Energy Efficiency
9 Rider ("Rider") funding the Company expects to collect from
10 customers?
11 A.Yes. Because the Rider is applied as 4.75
12 percent of base rate revenue, the increase to base rate
13 revenue will also increase the level of revenue collected
14 through the Rider.
15 RATE DESIGN
16 Q.Please describe the base rate design
17 proposed for Schedule 1 and Schedule 7 customer classes.
18 A.In keeping with the Stipulation, the Company
19 proposes that Schedule 1 and Schedule 7 customer classes
20 receive the total base rate increase placed on their
21 respective energy rates in a manner that maintains the
22 current tier differentials.
TATUM, DI 14
Idaho Power Company
1 Q.Please describe the base rate design
2 proposed for all other customer classes and the special
3 contract customers.
4 A.All other customer classes and the special
5 contract customers will receive a uniform percentage
6 increase on all billing components.
7 Q.Has the Company included revised tariff
8 sheets for each of the affected classes that illustrates
9 the proposed rate design?
10 A.Yes. The revised tariff sheets for each of
11 the affected classes are provided as Exhibit No.3.
12 Q.How long does the Company propose that this
13 increase in base rates remain in effect?
14 A.As per the approved Stipulation, this
15 increase in base rates is to remain in effect until new
16 base rates, which are ordered in a future Idaho Power
17 Company general rate case, become effective.
18 Q.Does this conclude your testimony?
19 A.Yes, it does.
TATUM, DI 15
Idaho Power Company
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC.E.10.12
IDAHO POWER COMPANY
TATUM, DI
TESTIMONY
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Case No. IPC-E-10-12
T. Tatum, IPC
Page 8 of 25
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Case No. IPC-E-10-12
T. Tatum, IPC
Page 10 of 25
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Exhibit No.2
Case No. IPC-E-10-12
T. Tatum, IPC
Page 13 of 25
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T. Tatum, IPC
Page 16 of 25
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Case No. IPC-E-10-12
T. Tatum, IPC
Page 19 of 25
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Case No. IPC-E-10-12
T. Tatum, IPC
Page 21 of 25
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Exhibit No.2
Case No. IPC-E-10-12
T. Tatum, IPC
Page 25 of 25
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-10-12
IDAHO POWER COMPANY
TATUM, DI
TESTIMONY
EXHIBIT NO.3
Idaho Power Company Foi:rthFifth Revised Sheet No. 1-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 +RFourth Revised Sheet No. 1-2
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 1 of 27
SCHEDULE 1
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 2 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 controllng 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.
SUMMER AND NON-SUMMER SEASONS
The summer season begins on June 1 of each year and ends on August 31 of each year. The
non-summer season begins on September 1 of each year and ends on May 31 of each year.
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98
(Residential and Small Farm Energy Credit).
Summer Non-summer
Service Charge, per month $4.00 $4.00
Energy Charge, per kWh
First 800 kWh
801-2000 kWh
All Additional kWh Over 2000
6.Q99139Ø
7.43138.4229Ø
8.Q17710.1077Ø
5.êQ536.4552Ø
ê.32827.1725Ø
7.27748.2484Ø
PAYMENT
The monthly bil rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued PQer IPUC Order No. 3082QJohn R Gale, Vise PFOsìdentGregorv W. Said. General Manager, Regulatory A1
Effective - June 1, 20010 1221 West Idaho Street, Boise, ID
Idaho Power Company ~Second Revised Sheet No. 3-2
Cancels
I.P.U.C. No. 29. Tariff No. 101 OriginalFirst Revised Sheet No. 3-2
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 2 of 27
SCHEDULE 3
MASTER-METERED MOBILE HOME PARK
RESIDENTIAL SERVICE
(Continued)
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98
(Residential and Small Farm Energy Credit):
Service Charge, per month $4.00
Energy Charge, per kWh
all kWh ê.21747.0018Ø
Minimum Charge
The monthly Minimum Charge shall be the sum of the Service Charge, the Energy Charge, and
the Power Cost Adjustment.
PAYMENT
The monthly bil rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued PQer IPUC Order No._dQ82QJohn R Gale, Vioe PresidentGregorv W. Said. General Manager, Regulatory Ai
Effective - June 1, 20010 1221 West Idaho Street, Boise, Idaho
Idaho Power Company ::Fourth Revised Sheet No. 4-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 SesenElThird Revised Sheet No. 4-3
Exhibit No.3
Case No. IPC-E-10-12
1. Tatum, IPC
Page 3 of 27
SCHEDULE 4
RESIDENTIAL SERVICE
ENERGY WATCH PROGRAM
(OPTIONAL)
(Continued)
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98
(Residential and Small Farm Energy Credit).
Summer Non-summer
Service Charge, per month $4.00 $4.00
Energy Charge, per kWh
Summer
Energy Watch Event hours
All other hours
Non-summer
First 800 kWh
801-2000 kWh
All Additional kWh Over 2000
20.0000ø
6.32817.1508Ø
nla
nla
nla
nla
nla
5.69536.4552:-
6.32817.1725Ø
7.27748.2484Ø
PAYMENT
The monthly bil rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued P.Qer IPUC Order NO._30829Jehn R Gale, Vise PFesiElentGregorv W. Said, General Manager, Regulatory Ai
Effective - June 1,20010 1221 West Idaho Street, Boise, ID
Idaho Power Company +lFourth Revised Sheet No. 5-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 SesondThird Revised Sheet No. 5-3
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, fPC
Page 4 of 27
SCHEDULE 5
RESIDENTIAL SERVICE
TIME-OF-DAY PROGRAM
(OPTIONAL)
(Continued)
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98
(Residential and Small Farm Energy Credit).
Summer Non-summer
Service Charge, per month $4.00 $4.00
Energy Charge, per kWh
Summer
On-Peak
Mid-Peak
Off-Peak
Non-summer
First 800 kWh
801-2000 kWh
All Additional kWh Over 2000
Q.184010.3525it
ê.7ã2Q7.6119it
5.0ê7081 it
n/a
n/a
n/a
n/a
n/a
n/a
ã.êQã36.4552it
ê.32817.1725it
7.27748.2484it
PAYMENT
The monthly bil rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued PQer IPUC Order No._3082QJohn R. Gale, Vise PresidentGregorv W. Said. General Manager, Regulatory A1
Effective - June 1,20010 1221 West Idaho Street, Boise, ID
Idaho Power Company ~Fifth Revised Sheet No. 7-2
Cancels
I.P.U.C. No. 29. Tariff No. 101 +AFourth Revised Sheet No. 7-2
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 5 of 27
SCHEDULE 7
SMALL GENERAL SERVICE
(Continued)
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91
(Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98
(Residential and Small Farm Energy Credit).
Summer Non-summer
Service Charge, per month $4.00 $4.00
Energy Charge, per kWh
First 300 kWh
All Additional kWh
7.09268.0823Ø
8.44429.6227Ø
7.09268.0823Ø
7.4 9698. 5430Ø
PAYMENT
The monthly bil rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued PQer IPUC Order NO._d0829Jehn R Gale, ViGe PresidentGregory W. Said. General Manager, Regulatory Ai
Effective - June 1, 20010 1221 West Idaho Street, Boise, Idaho
Idaho Power Company ~Fifth Revised Sheet No. 9-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 :iFourth Revised Sheet No. 9-4
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 6 of27
SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)
MONTHLY CHARGE (Continued)
SECONDARY SERVICE Summer Non-summer
Service Charge, per month $1~.07 $1~.07
Basic Charge, per kW of Basic Load Capacity
First 20 kW
All Additional kW
$0.00
$0.êS77
$0.00
$0.êS77
Demand Charge, per kW of Biling Demand
First 20 kW
All Additional kW
$0.00~.49 $0.00 $3.~9
Energy Charge, per kWh
First 2,000 kWh9ê7.8397t
All Additional kWh
7.80658.7873t
3.~7662t
ê-
2. Q8523.3597t
Facilities Charge
None.
IDAHO Issued by IDAHO POWER COMPANY
Issued P.Qer IPUC Order No._d082QcloRR R Gale, Vise PFesideRtGregorv W. Said, General Manager, Regulatory A1
Effective - June 1,20010 1221 West Idaho Street, Boise, Idaho
Idaho Power Company ~Second Revised Sheet No. 9-5
Cancels
I.P.U.C. No. 29, Tariff No. 101 OriainalFirst Revised Sheet No. 9-5
Exhibit NO.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 7 of 27
SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)
MONTHLY CHARGE (Continued)
PRIMARY SERVICE Summer Non-summer
Service Charge, per month $215.0042.04 $215.0042.04
Basic Charge, per kW of
Basic Load Capacity ~1.09 ~1.09
Demand Charge, per kW of
Billng Demand ~.15 $3.403
On-Peak Demand Charge, per kW of
On-Peak Biling Demand $0.ê978 n/a
Energy Charge, per kWh
On-Peak
Mid-Peak
Off-Peak
3.d07162Ø
3.003789Ø
2.ß0523.1581Ø
n/a2.~9499Ø2.~292Ø
Facilties Charge
The Company's investment in Company-owned Facilties Beyond the Point of Delivery times 1.7
percent.
IDAHO Issued by IDAHO POWER COMPANY
Issued P.Qer IPUC Order No. 30754clol=n R Gale, Vise PresidentGregorv W. Said, General Manager, Regulatory A1
Effective - AfJune 1, 20010 1221 West Idaho Street, Boise, 10
Idaho Power Company First Revised Sheet No. 9-6
Cancels
Original Sheet No. 9-6
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 8of27
I.P.U.C. No. 29, Tariff No. 101
SCHEDULE 9
LARGE GENERAL SERVICE
(Continued)
MONTHLY CHARGE (Continued)
TRANSMISSION SERVICE
Basic Charge, per kW of
Basic Load Capacity
Summer Non-summer
$215.0042.04 $215.0042.04
$0.5Q§$0.5Q
$3.~97 $3.~8
$0.ê978 nfa
3.24563t nfa
2.Q5Q03.3327t 2.WO9172t
2.77003.1198t 2.4Q066t
Service Charge, per month
Demand Charge, per kW of
Biling Demand
On-Peak Demand Charge, per kW of
On-Peak Biling Demand
Energy Charge, per kWh
On-Peak
Mid-Peak
Off-Peak
Facilities Charge
The Company's investment in Company-owned Facilties Beyond the Point of Delivery times 1.7
percent.
PAYMENT
The monthly bil rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued PQer IPUC Order No. 30754John R. Gale, Vioe PresidentGregorv W. Said, General Manager, ReguiatoryA1Effective - AfJune 1, 2OW10 1221 West Idaho Street, Boise, ID
Idaho Power Company SesondThird Revised Sheet No. 15-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 ~Second Revised Sheet No. 15-2
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 90f27
SCHEDULE 15
DUSK TO DAWN CUSTOMER
LIGHTING
(Continued)
NEW FACILITIES
Where facilties of the Company are not presently available for a lamp installation which wil
provide satisfactory lighting service for the Customets Premises, the Company may install overhead or
underground secondary service facilties, including secondary conductor, poles, anchors, etc., a
distance not to exceed 300 feet to supply the desired service, all in accordance with the charges
specified below.
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).
1. Monthly Per Unit Charge on existing facilties:
AREA LIGHTING
High Pressure
Sodium Vapor
100 Watt
200 Watt
400 Watt
Average BaseLumens Rate8,550 $ ~7.0519,800 $1~1.4045,000 ~18.25
FLOOD LIGHTING
High Pressure
Sodium Vapor
200 Watt
400 Watt
Metal Halide
400 Watt
1000 Watt
Average
Lumens
19,800
45,000
Base
Rate
$1~3.86~20.72
28,800
88,000
$2G,3.16
$â7.5542.27
2. For New Facilities Installed Before June 1, 2004: The Monthly Charge for New Facilties
installed prior to June 1, 2004, such as overhead secondary conductor, poles, anchors, etc., shall be
1.75 percent of the estimated installed cost thereof.
3. For New Facilties Installed On or After June 1, 2004: The non-refundable charge for
New Facilties to be installed, such as underground service, overhead secondary conductor, poles,
anchors, etc., shall be equal to the work order cost.
PAYMENT
The monthly bil for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued PQer IPUC Order No. â0722John R Gale, Vise ProsidontGregory W. Said. General Manager, Regulatory AiEffective - ~ol:)FlaryJune 1, 20010 1221 West Idaho Street, Boise, ID
Idaho Power Company ::Fourth Revised Sheet No. 19-4
Cancels
I.P.U.C. No. 29, Tariff No. 101SecondThird Revised Sheet No. 19-4
Exhibit No.3
Case No. IPC-E-10-12
1. Tatum, IPC
Page 10 of 27
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
MONTHLY CHARGE (Continued)
SECONDARY SERVICE
Basic Charge, per kW of
Basic Load Capacity
Summer Non-summer
$1UG.07 $1UG.07
$0.~77 $0.~77
$3.444 $3.+959
$0.ê978 n/a
4.50Q05.0756Ø n/a3.4á884Ø 3A8JG5822Ø
3.003807Ø 2.76603.1127Ø
Service Charge, per month
Demand Charge, per kW of
Biling Demand
On-Peak Demand Charge, per kW of
On-Peak Biling Demand
Energy Charge, per kWh
On-Peak
Mid-Peak
Off-Peak
Facilties Charge
None.
PRIMARY SERVICE Summer Non-summer
Service Charge, per month
Basic Charge, per kW of
Basic Load Capacity
$215.0042.04
~1.09
$215.0042.04
~1.09
Demand Charge, per kW of
Billng Demand
On-Peak Demand Charge, per kW of
On-Peak Biling Demand
Energy Charge, per kWh
On-Peak
Mid-Peak
Off-Peak
~.15 $3.403
$0.ê978 n/a
3.63624.0937Ø
2.77013.1187Ø
2.407115Ø
n/a2.~874Ø2.~5109Ø
Facilties Charge
The Company's investment in Company-owned Facilities Beyond the Point of Delivery times 1.7
percent.
IDAHO Issued by IDAHO POWER COMPANY
Issued P.Qer IPUC Order No. 30754John R Gale, Vice PFesidentGregorv W. Said. General Manager, Regulatory A1
Effective - AfJune 1, 20010 1221 West Idaho Street, Boise, ID
Idaho Power Company :iFourth Revised Sheet No. 19-5
Cancels
I.P.U.C. No. 29, Tariff No. 101SesondThird Revised Sheet No. 19-5 and 196
Exhibit No.3
Case No. IPC.E-1D-12
1. Tatum, IPC
Page 11 of27
SCHEDULE 19
LARGE POWER SERVICE
(Continued)
MONTHLY CHARGE (Continued)
TRANSMISSION SERVICE Summer Non-summer
Service Charge, per month $215.0042.04 $215.0042.04
Basic Charge, per kW of
Basic Load Capacity $0.502 $0.5Q
Demand Charge, per kW of
Billng Demand $3.~97 $3.m58
On-Peak Demand Charge, per kW of
On-Peak Biling Demand
Energy Charge, per kWh
On-Peak
Mid-Peak
Off-Peak
$0.ê978 nfa
3.60804.0626t
2.76203.1104t
2.4G7040é-
nfa2.~740t2.24988t
Facilties Charge
The Company's investment in Company-owned Facilities Beyond the Point of Delivery times 1.7
percent.
PAYMENT
The monthly bil for service supplied hereunder is payable upon receipt, and becomes past due
15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued PQer IPUC Order No. 30754c1ohn R Gale, Vise PresidentGregory W. Said. General Manager, Regulatory A1
Effective -AfJune 1, 20010 1221 West Idaho Street, Boise, ID
Idaho Power Company +AFourth Revised Sheet No. 24-3
Cancels
I.P.U.C. No. 29, Tariff No. 101SeaondThird Revised Sheet No. 24-3
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 12 of 27
SCHEDULE 24
AGRICULTURAL IRRIGATION
SERVICE
(Continued)
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), Schedule 95
(Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy
Credit).
SECONDARY SERVICE In-Season Out-of-Season
Service Charge, per month
$3.0035
Demand Charge, per kWof
Biling Demand
$1ã,7.70
$ ~5.52 $0.00
Energy Charge
In-Season
First 164 kWh per kW of Demand
All Other kWh per kW of Demand
Out-ot-Season
All kWh
4.88115.4947t
4.Qá5678t
3.93974.4345t
n.a.
n.a.
n.a.
Facilities Charge
None.
TRANSMISSION SERVICE In-Season Out-of-Season
Service Charge, per month $215.0042.00 $3.0038
Demand Charge, per kW of
Biling Demand $ 4:5.19 $0.00
Energy Charge
In-Season
First 164 kWh per kW of Demand
All Other kWh per kW ot Demand
Out-of-Season
All kWh
4.54865.1204t
3.78144.2563t
3.67134.1324t
n.a.
n.a.
n.a.
Facilties Charge
IDAHO Issued by IDAHO POWER COMPANY
Issued P.Qer IPUC Order NO._30829John R Gale, Viae PresidentGregory W. Said, General Manager, Regulatory Ai
Effective - June 1, 20010 1221 West Idaho Street, Boise, ID
Idaho Power Company
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, fPC
Page 13 of 27
+RFourth Revised Sheet No. 24-3
Cancels
I.P.U.C. No. 29. Tariff No. 101SosenelThird Revised Sheet No. 24-3
The Company's investment in Company-owned Facilties Beyond the Point of Delivery times 1.7
percent.
#
IDAHO Issued by IDAHO POWER COMPANY
Issued P.Qer IPUC Order No._d082Qclehn R. Gale, Vise PresielentGregorv W. Said. General Manager, Regulatory Ai
Effective - June 1, 20010 1221 Westldaho Street, Boise, ID
Idaho Power Company ~Fourth Revised Sheet No. 26-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 SecondThird Revised Sheet No. 26-1
Exhibit NO.3
Case No. IPC-E-10-12
1. Tatum, ~PC
Page 14 of 27
SCHEDULE 26
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
MICRON TECHNOLOGY, INC.
BOISE, IDAHO
SPECIAL CONTRACT DATED DECEMBER 29, 2009
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).
Monthly Contract Demand Charge
$1.3M6 per kW of Contract Demand.
Monthly Biling Demand Charge
$&9.55 per kW of Billng Demand but not less than Minimum Monthly Billng Demand.
Minimum Monthly Biling Demand
The Minimum Monthly Bniing Demand wil be 25,000 kilowatts.
Daily Excess Demand Charge
$0.24Q70 per each kW over the Contract Demand.
Monthly Energy Charge
1.ã97993Ø per kWh.
IDAHO Issued by IDAHO POWER COMPANY
Issued December 31, 200Qper IPUC Order No. John R Gale, Vice PresideRtGregorv W. Said, General Manager,
Effective - Febrl:aryJune 1,2010 1221 West Idaho Street, Boise, 10
Idaho Power Company SeeondThird Revised Sheet No. 29-1
Cancels
I.P.U.C. No. 29. Tariff No. 101 ~Second Revised Sheet No. 29-1
Exhibit No.3
Case No. IPC-E-10-12
1. Tatum, IPC
Page 15 of 27
SCHEDULE 29
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
J. R. SIMPLOT COMPANY
POCATELLO. IDAHO
SPECIAL CONTRACT DATED JUNE 29, 2004
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).
Contract Demand Charge
$1.7+99 per kW of Contract Demand
Demand Charge,
$6.002 per kW of Biling Demand but no less than the Contract Demand less 5,000 kW
Daily Excess Demand Charge
$0.24070 per each kW over the Contract Demand
Energy Charge
1.êQ8105Ø per kWh
Monthly Facilties Charge
1.7% of the Company's investment in Distribution Facilties
IDAHO Issued by IDAHO POWER COMPANY
Issued PQer IPUC Order No. 30722John R Gale, Viee PresidentGregorv W. Said. General Manager, Regulatory Al
Effective - ¡;esFuary 1, 200QJune 1. 2010 1221 West Idaho Street, Boise, ID
Idaho Power Company SeoondThird Revised Sheet No. 30-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 ~Second Revised Sheet No. 30-1
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 16 of 27
SCHEDULE 30
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
UNITED STATES DEPARTMENT OF ENERGY
IDAHO OPERATIONS OFFICE
SPECIAL CONTRACT DATED MAY 16, 2006
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's facilties located at the Idaho National Engineering Laboratory
site, as provided in the Contract for Electric Service between the parties.
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).
1.Demand Charge, per kW of
Billng Demand ;'~7.38
1.~9387Ø2.Energy Charge, per kWh
SPECIAL CONDITIONS
1. Billng Demand. The Billng Demand shall be the average kW supplied during the 30-
minute period of maximum use during the month.
2. 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 Billng Demand by multiplying the measured kW of Demand by 0.95 and dividing by the
actual Power Factor.
IDAHO Issued by IDAHO POWER COMPANY
Issued PQer IPUC Order No. J0722John R Gale, Vioe PFesidentGregorv W. Said, General Manager, Regulatory A1Effective - FebnJai=June 1,200910 1221 West Idaho Street, Boise, ID
Idaho Power Company ::Fourth Revised Sheet No. 31-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 SecenElThird Revised Sheet No. 31-1
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, fPC
Page 17 of 27
SCHEDULE 31
IDAHO POWER COMPANY
AGREEMENT FOR SUPPLY OF
STANDBY ELECTRIC SERVICE
FOR
THE AMALGAMATED SUGAR COMPANY
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).
Standby Contract Demand Charge, per kW of
Standby Contract Demand $0.28
Standby Facilties Contract Demand Charge
Per kW of Standby Facilties Contract Demand:
Paul Facilty:
Nampa Facility:
Twin Falls Facilty:
$0.79
$0.82
$0.45
Standby Biling Demand Charge, per kW of
Standby Billng Demand ~3.30
Excess Demand Charge
$0.50 per day for each kW taken in excess of the Total Contract Demand during the months of
September through March
$0.75 per day for each kW taken in excess of the Total Contract Demand during the months of
April through August
$5.00 per kW for the highest Excess Demand recorded during the Billng Period. (This charge
wil not be prorated.)
Energy Charge Energy taken with Standby Demand wil be priced at the applicable Schedule 19
Energy Charge.
IDAHO Issued by IDAHO POWER COMPANY
Issued per IPUC Order No. 30754dehn R Gale, Vice PFesiElentGregory W. Said, General Manager, Regulatory AffiEffective -ApJune 1, 20010 1221 West Idaho Street, Boise, 10
Idaho Power Company First Revised Sheet No. 32-1
Cancels
Original Sheet No. 32-1
Exhibit NO.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 18 of 27I.P.U.C. No. 28, Tariff No. 101
SCHEDULE 32
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR HOKU MATERIALS, INC.
POCATELLO, IDAHO
ELECTRIC SERVICE AGREEMENT DATED SEPTEMBER 17,2008
APPLICABI L1TY
This schedule is applicable to service to Hoku Materials, Inc. (Hoku) served by Idaho Power
Company under the terms of an Electric Service Agreement (ESA) dated September 17, 2008.
MONTHLY CHARGE
The Monthly Charge is the sum of the following charges and may also include applicable
charges for Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and
Schedule 95 (Adjustment for Municipal Franchise Fees).
FIRST BLOCK MONTHLY CHARGES
First Block Contract Demand Charge
$2.35 per kW times the First Block Contract Demand
First Block Energy Charge
6.166 cents per kWh times the First Block Energy (subject to the Minimum Biled Energy
amount specified in the ESA)
SECOND BLOCK MONTHLY CHARGES
Second Block Contract Demand Charge
$4.Gi53 per kW times the Second Block Contract Demand
Second Block Energy Charge
2.ã4288 cents per kWh times the Second Block Energy (subject to Minimum Biled
Energy amount specified in the ESA)
EXCESS DEMAND CHARGES
Daily Excess Demand Charge
$O.W§ per each kW of Excess Demand per day
Monthly Excess Demand Charge
$5.003 per kW for the highest Excess Demand recorded during the billing period
EXCESS ENERGY CHARGE
7:8.6773 cents per kWh of Excess Energy
IDAHO Issued by IDAHO POWER COMPANY
Issued P.Qer IPUC Order No. a0748John R Gale, Vieo ProsidentGrogory W. Said, General Manager, Regulatory A1
Effective .. DeeoRlberJune 1, 20010
Idaho Power Company +AFourth Revised Sheet No. 40-2
Cancels
I.P.U.C. No. 29, Tariff No. 101SesondThird Revised Sheet No. 40-2
Exhibit NO.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 19 of27
SCHEDULE 40
UNMETERED GENERAL SERVICE
(Continued)
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 wil not be reason for a reduction in
the Monthly Charge. The Monthly Charge shall be computed at the following rate, and may also
include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency
Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees).
Energy Charge, per kWh
Minimum Charge, per month
ã.7ê306.4888ct
$1.50
ADDITIONAL CHARGES
Applicable only to municipalities or agencies of federal, state, or county governments with an
authorized Point of Delivery having the potential of intermittent variations in energy usage.
Intermittent Usage Charge, per unit, per month $1.00
PAYMENT
The monthly bil rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued April 10, 2009 per IPUC Order No. John R. Gale, Vise PresidentGregorv W. Said. General Manager, Regi
Effective - June 1, 20010 1221 West Idaho Street, Boise, I D
Idaho Power Company ::Fourth Revised Sheet No. 41-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 SecondThird Sheet No. 41-2
Exhibit No. 3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 20 of 27
SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)
Company-owned lighting systems installed on or after June 1, 2004 shall not be
constructed, operated, or modified in such a way as to allow for the potential or actual variation
in energy usage, such as through, but not limited to, the use of wired outlets or useable plug-ins.
Company-owned systems installed prior to June 1, 2004 that are constructed, operated,
or modified in such a way as to allow for the potential or actual variation in energy usage may
have the estimated annual variations in energy usage charged the Non-Metered Service -
Variable Energy Charge until the potential for variations in energy usage has been eliminated.
Repair, modification or alteration of these facilties is not permitted.
ACCELERATED REPLACEMENT OF EXISTING FIXTURES
In the event a Customer requests the Company perform an accelerated replacement of
existing fixtures with the cut-off fixture, the following charges wil apply:
1. The designed cost estimate which includes labor, time, and mileage costs for the
removal of the existing street lighting fixtures.
2. $65.00 per fixture removed from service.
The total charges identified in 1 and 2 above must be paid prior to the beginning of the
fixture replacement and are non-refundable. The accelerated replacement wil be performed by
the Company during the regularly scheduled working hours of the Company and on the
Company's schedule.
MONTHLY CHARGE
The monthly charges are as follows, and may also include charges as set forth in
Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).
Lamp Charges, per lamp
High Pressure
Sodium Vapor
70 Watt
100 Watt
200 Watt
250 Watt
400 Watt
Average
Lumens
5,540
8,550
19,800
24,750
45,000
Base
Rate
$_+:.51$_~7.67$_7:.98~10.15
$1~2.78
IDAHO Issued by IDAHO POWER COMPANÝ
Issued SepteFRber 2, 200Qper IPUC Order No. John R Gale, 'lice PresidentGregorv W. Said. General ManagEffective -J).IoyemberJune 1, 20010 1221 West Idaho Street, Boise, ID
Idaho Power Company ~Fifth Revised Sheet No. 41-4
Cancels
+RFourth Sheet No. 41-4
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum. IPC
Page 21 of27
I.P.U.C. No. 29, Tariff No. 101
SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)
ENERGY-ONLY SERVICE
Energy-Only Service is available only to a metered lighting system. Service includes
energy supplied from the Company's overhead or underground circuits and does not include
any maintenance to the Customer's facilties.
A street lighting system receiving service under the Energy-Only Service offering is not
eligible to transfer to any street lighting service option under this schedule that includes
maintenance provisions to the Customets facilties.
MONTHLY CHARGE
The monthly charges are as follows, and may also include charges as set forth in
Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).
Non-Metered Service (With Maintenance), per lamp
High Pressure
Sodium Vapor
70 Watt
100 Watt
200 Watt
250 Watt
400 Watt
Average
Lumens
5,450
8,550
19,800
24,750
45,000
Base
Rate~3.65~.15
$5A476
$6.G96
$&9.51
Non-Metered Service - Variable Energy
Energy Charge, per kWh ã.763Q6.4888Ø
Metered Service (With Maintenance), per lamp
High Pressure Sodium Vapor
70 Watt
100 Watt
200 Watt
250 Watt
400 Watt
Meter Charge, per meter
Energy Charge, per kWh
$2.G935$-2.08~2.16
$-2.08~2.14
$8.45
5.G87238Ø
Metered Energy-Only Service (No Maintenance)
Meter Charge, per meter $8.45Energy Charge, per kWh 5.G8~Ø
IDAHO Issued by IDAHO POWER COMPANY
Issued per IPUC Order No. âeßtember 2. 2QQQJohn R Gale, '1ioe PresidentGregorv W. Said. General ManagEffective -_~loveR=berJune 1, 20G10 1221 West Idaho Street, Boise, ID
Idaho Power Company ~Fifth Revised Sheet No. 41-7
Cancels
I.P.U.C. No. 29, Tariff No. 101 +lFourth Revised Sheet No. 41-7
Exhibit NO.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 22 of 27
SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)
NO NEW SERVICE
ENERGY AND MAINTENANCE SERVICE
Energy and Maintenance Service includes operation of the system, energy, lamp
renewals, cleaning of glassware: and replacement of defective 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. 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.
ENERGY-ONLY SERVICE
Energy-Only Service is available only to a metered lighting system. Service includes
energy supplied from the Company's overhead or underground circuits and does not include
any maintenance to the Customer's facilities.
A street lighting system receiving service under the Energy-Only Service offering is not
eligible to transfer to any street lighting service option under this schedule that includes
maintenance provisions to the Customer's facilities.
MONTHLY CHARGE
The monthly charges are as follows, and may also include charges as set forth in
Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).
Non-Metered Service (With Maintenance), per lamp
Mercury Vapor
175 Watt
400 Watt
Average
Lumens
Base
Rate
7,654
19,125
~.28~9.93
Non-Metered Service - Variable Energy
Energy Charge, per kWh 5.7êJQ6.4888Ø
IDAHO Issued by IDAHO POWER COMPANY
Issued September 2, 2QQQper IPUC Order No. John R Gale, Vise PresidentGregorv W. Said. General Manac
Effective -I\Jovember 1, 2QQQJune 1,2010 1221 West Idaho Street, Boise, ID
Idaho Power Company First Revised Sheet No. 41-8
Cancels
Original Sheet No. 41-8
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 23 of27I.P.U.C. No. 29. Tariff No. 101
SCHEDULE 41
STREET LIGHTING SERVICE
(Continued)
NO NEW SERVICE
MONTHLY CHARGE (Continued)
Metered Service (With Maintenance) per lamp
Mercury Vapor
175 Watt $1.93
$2.00
$8.45
4 .Q81 05. 7238il
400 Watt
Meter Charge, per meter
Energy Charge, per kWh
Metered Energy-Only Service (No Maintenance)
Meter Charge, per meter $8.45
5.007238ilEnergy Charge, per kWh
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 by IDAHO POWER COMPANY
Issued Septer:eer 2, 200Qper IPUC Order No. John R Gale, "¡Ge PresidentGregory W. Said. General Manager,
Effective - Nover:eer 1, 200QJune 1, 2010 1221 West Idaho Street, Boise, ID
Idaho Power Company +RFourth Revised Sheet No. 42-1
Cancels
I.P.U.C. No. 29, Tariff No. 101SesenåThird Revised Sheet No. 42-1
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, (PC
Page 24 of 27
SCHEDULE 42
TRAFFIC CONTROL SIGNAL
LIGHTING SERVICE
APPLICABI L1TY
Service under this schedule is applicable to Electric Service required for the operation of traffc
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.
CHARACTER OF SERVICE
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.
The installation of a meter to record actual energy consumption is required for all new traffic
control signal lighting systems installed on or after June 1, 2004. For traffic control signal lighting
systems installed prior to June 1, 2004 a meter may be installed to record actual usage upon the
mutual consent of the Customer and the Company.
MONTHLY CHARGE
The monthly kWh of energy usage shall be either the amount 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, or the actual meter reading as applicable. The Monthly Charge
shall be computed at the following rate, and may also include charges as set forth in Schedule 55
(Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95 (Adjustment for
Municipal Franchise Fees).
Energy Charge, per kWh 3.99164.4935t
PAYMENT
The monthly bil rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO Issued by IDAHO POWER COMPANY
Issued P.Qer IPUC Order No._3082QJehn R Gale, Vise PFesiåentGregorv W. Said, General Manager, Regulatory A1
Effective - June 1, 20010 1221 West Idaho Street, Boise, ID
Idaho Power Company SesendThird Revised Sheet No. 45-3
Cancels
I.P.U.C. No. 29. Tariff No. 101Fiecond Revised Sheet No. 45-3
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 25 of 27
SCHEDULE 45
STANDBY SERVICE
(Continued)
PARALLEL OPERATIONS
Parallel operations wil only be authorized by the Company under the terms of the Uniform
Standby Service Agreement with the Customer. The Company wil install a system protection paCkage
at the Customer's expense prior to the start of parallel operations. The Customer will also pay a
Maintenance Charge of 0.7 percent per month times the investment in the protection package.
MONTHLY CHARGE
The Monthly Charge for Standby Service is the sum of the Standby Reservation Charge, the
Standby Demand Charge, and the Excess Demand Charge, if any, at the following rates:
Standby Reservation Charge, per kW of
Available Standby Capacity
Primary Service
Transmission Service
Summer Non-summer
$1.54
$0.44
$1.39
$0.29
Standby Demand Charge, per kW of
Standby Biling Demand
Primary Service
Transmission Service
$5.0074$L5.42 $4.338
$4.001
Excess Demand Charge
$0.50 per kW times the sum of the daily Excess Demands recorded during the Biling Period,
plus $5.00 per kW for the highest Excess Demand recorded during the Billng Period. This
charge wil not be prorated.
Minimum Charge
The monthly Minimum Charge shall be the sum of the Standby Reservation Charge, the
Standby Demand Charge, and the Excess Demand Charge.
CONTRIBUTION TOWARD MINIMUM CHARGES ON OTHER SCHEDULES
Any Standby Service Charges paid under this schedule shall not be considered in determining
the Minimum Charge under any other Company schedule.
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 by IDAHO POWER COMPANY
Issued PQer IPUC Order NO._d0754dehn R Gale, Vise PresidentGregory W. Said. General Manager, Regulatory AiEffective - April 1, 200QJune 1. 2010 1221 West Idaho Street, Boise, ID
Idaho Power Company ::Fourth Revised Sheet No. 55-1
Cancels
I.P.U.C. No. 29, Tariff No. 101SesoneiThird Revised Sheet No. 55-1
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 26 of 27
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 and Special Contracts. These loads are referred to as ''frm'' load for
purposes of this schedule.
BASE POWER COST
The Base Power Cost of the Company's rates is computed by dividing the sum of the
Company's power cost components by firm kWh sales. The power cost components are segmented
into two categories; Category 1 and Category 2. Category 1 power costs include the sum of fuel
expense and purchased power expense (excluding purchases from cogeneration and small power
producers), less the sum of off-system surplus sales revenue and revenue from market-based special
contract pricing. Category 2 power costs include purchased power expense from cogeneration and
small power producers. The Base Power Cost is 1.w.5003 cents per kWh, which is comprised of
Category 1 power costs of 0.59131.0573 cents per kWh and Category 2 power costs of 0.4330
cents per kWh.
PROJECTED POWER COST
The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the
Category 1 and Category 2 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.~407 cents per
kWh, which is comprised of Category 1 power costs of 1.1êê92 cents per kWh and Category 2 power
costs ofO.3ã515 cents per kWh.
TRU&UP AND TRU&UP OF THE TRU&UP
The True-up is based upon the difference between the previous Projected Power Cost and the
power costs actually incurred. The True-up of the True-up is the difference between the previous
year's approved True-Up revenues and actual revenues collected. The total True-up is 0.Wã1726
cents per kWh.
POWER COST ADJUSTMENT
The Power Cost Adjustment is the sum ot 1) 95 percent of the difference between the Projected
Power Costs in Category 1 and the Base Power Costs in Category 1~i 2) 100 percent of the difference
between the Projected Power Costs in Category 2 and the Base Power Costs in Category 2~ and 3) -the
True-ups.
The monthly Power Cost Adjustment applied to the Energy rate of all metered schedules and
Special Contracts is 1.40220.3130 cents per kWh. The monthly Power Cost Adjustment applied to the
per unit charges of the nonmetered schedules is the monthly estimated usage times 1.40220.3130
cents per kWh.
EXPIRATION':
IDAHO Issued by IDAHO POWER COMPANY
Issued P-Qer IPUC Order No. 30ß2ßJohn R Gale, Vise PFBsielentGregorv W. Said, General Manager, Regulatory A1
Effective - June 1, 20010 1221 West Idaho Street, Boise, I D
Idaho Power Company +lFourth Revised Sheet No. 55-1
Cancels
I.P.U.C. No. 29. Tariff No. 101SesondThird Revised Sheet No. 55-1
The Power Cost Adjustment included on this schedule will expire May 31, 201G1.
Exhibit No.3
Case No. IPC-E-10-12
T. Tatum, IPC
Page 27 of 27
IDAHO Issued by IDAHO POWER COMPANY
Issued P-Qer IPUC Order No. âQ828John R Gale, Vise Pi:sidentGregory W. Said. General Manager, Regulatory Ai
Effective - June 1, 20010 1221 West Idaho Street, Boise, ID