20111007Lobb Direct.pdf

RECË1\lEr)
BEFORE THE
2Uil OCT -7 Ai; 10: 24
IDAHO PUBLIC UTILITIES COMMISSIONUTH.¡8'fH~J
IN THE MATTER OF THE APPLICATION OF )
IDAHO POWER COMPANY FOR ) CASE NO. IPC-E-11-08
AUTHORITY TO INCREASE ITS RATES )
AND CHARGES FOR ELECTRIC SERVICE )IN IDAHO. )
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)
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DIRECT TESTIMONY OF RANDY LOBB
IN SUPPORT OF THE STIPULATION
AND SETTLEMENT
IDAHO PUBLIC UTILITIES COMMISSION
OCTOBER 7,2011
1 Q.Please state your name and business address for
2 the record.
3 A.My name is Randy Lobb and my business address is
4 472 West Washington Street, Boise, Idaho.
5 Q.By whom are you employed?
6 A.I am employed by the Idaho Public Utilities
7 Commission as Utilities Division Administrator.
8 Q.What is your educational and professional
9 background?
10 A.I received a Bachelor of Science Degree in
11 Agricul tural Engineering from the Uni versi ty of Idaho in
12 1980. I then worked for the Idaho Department of Water
13 Resources from June of 1980 to November of 1987. I received
14 my Idaho license as a registered professional Civil Engineer
15 in 1985 and began work at the Idaho Public Utilities
16 Commission in December of 1987. My duties at the Commission
17 currently include case management and oversight of all
18 technical Staff assigned to Commission filings. I have
19 conducted analysis of utility rate applications, rate
20 design, proposed tariffs and customer petitions. I have
21 testified in numerous proceedings before the Commission
22 including cases dealing with rate structure, Cost of
23 Service, power supply, line extensions, regulatory policy
24 and facility acquisitions.
25 Q.What is the purpose of your testimony in this
CASE NO. IPC-E-11-810/07/11 LOBB , R . (D i ) 1
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1 case?
2 A.The purpose of my testimony is to describe the
3 Stipulation (the Proposed Partial Settlement) filed in this
4 case and to explain the rationale for Staff's support. I
5 will also present Staff's proposed reduction in the Energy
6 Efficiency Tariff Rider.
7 Q.Please summarize your testimony.
The Stipulation resolves most of the issues in the8A.
9 general rate case and is agreed to by all parties but one.
10 Based on Staff's audit of Idaho Power Company's results of
11 operations, evaluation of proposed proforma adjustments and
12 consideration of all issues associated with Cost of Service,
13 rate design and customer impact, Staff supports the Proposed
14 Partial Settlement resulting in an increase in base rates of
15 4.19%. Staff further proposes reducing the Energy
16 Efficiency Tariff Rider (Schedule 91) by 0.75%, thereby
17 reducing the overall net increase to 3.44%. Finally, based
18 on its review of the Company's filing and in consideration
19 of issues and concerns expressed by other parties to the
20 case in settlement negotiations, Staff believes the broad
21 Proposed Partial Settlement is in the public interest, is
22 just and reasonable and should be approved by the
23 Commission.
24 Q.How is your testimony organized?
25 A.My testimony is subdivided under the following
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 2
STAFF
1 headings:
5
Stipulation Overview Page 3
The Settlement Process page 5
Revenue Adj ustments Page 8
Cost of Service Page 11
Rate Design Page 14
Separate Dockets Page 18
The Energy Efficiency Rider Page 19
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8 Stipulation Overview
9 Q.Please provide an overview of the Stipulation and
10 Proposed Partial Settlement.
11 A.The Stipulation provides for an annual overall
12 increase in electric base revenue of $34 million or 4.07%.
13 The increase, spread uniformly to all customer classes, is
14 actually 4.19% because the overall increase does not apply
15 to Hoku Material's first block energy. The Stipulation
16 encourages the Commission to make the new rates effective on
17 January 1, 2012.
18 The Stipulation specifies annual power supply cost
19 levels for the Power Cost Adjustment (PCA) mechanism, the
20 amortization schedule for Bennett Mountain combustor
21 inspection costs, and the amortization schedule for the
22 Light Detection and Radar Survey (LIDAR) costs. It also
23 specifies a 7.86% overall rate of return (ROR) without
24 specifying a new authorized Return on Equity (ROE).
25 Although the Stipulation comprehensively settles
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 3
STAFF
1 all revenue requirement issues in the case, it does not
2 specify revenue adjustments to the Company's case or an
3 authorized ROE. While the Stipulation uses the Company's
4 Class Cost of Service Study (COS): 1) to establish fixed
5 costs for the Fixed Cost Adjustment mechanism (FCA); 2) to
6 reset the Load Change Adjustment Rate (LCAR) for the PCA;
7 and 3) to modify rate components within individual customer
8 classes, the COS has not been used to spread the revenue
9 increase among customer classes. Rather, the Stipulation
10 uniformly spreads revenue among the classes. The
11 Stipulation is attached as Staff Exhibit No. 101.
12 Q.Does the Stipulation resolve all issues presented
13 by the Company in its original filing?
14 A.No. Several issues remain. Two issues will be
15 addressed in separate dockets: 1) Whether the FCA pilot
16 should be made permanent; and 2) Overhead amounts associated
17 with line extensions under Rule H. Three other issues are
18 not resolved and will be addressed at hearing. These three
19 unresolved issues are: 1) the level of funding for Low
20 Income Weatherization Assistance; 2) the calculation of
21 facility charges associated with industrial Schedules 9 and
22 19 customers; and 3) the appropriate level of the Energy
23 Efficiency Rider.
24 Q.How does the annual base revenue requirement
25 increase proposed in the Stipulation compare to the increase
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di)
STAFF
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1 originally proposed by Idaho Power?
2 A.The Company originally proposed increasing annual
3 base electric revenue by $83 million or 9.9%. The
4 Stipulation would increase annual base electric revenue by
5 $34 million or approximately 41% of the original request.
6 The Settlement Process
7 Q.Would you please describe the process leading to
8 the Stipulation?
9 A.Yes. The Company filed its rate application with
10 the Commission on June 1, 2011 and Staff immediately began
11 its review. The Commission set a July 1, 2011 intervention
12 deadline. Parties ultimately approved for intervention
13 included: The Community Action Partnership Association of
14 Idaho (CAPAI), the u. S. Department of Energy (DOE), the
15 Industrial Customers of Idaho Power (ICIP), the Idaho
16 Irrigation Pumpers Association (IIPA), Kroger Company,
17 Micron, the Northwest Energy Coalition (NWEC), the Idaho
18 Conservation League (ICL), the Snake River Alliance (SRA)
19 and Hoku Materials.
20 Once parties to the case were determined, they met
21 to establish a procedural schedule that included production
22 request deadlines, direct and rebuttal testimony prefile
23 dates, hearing dates and two dates for settlement
24 negotiations. The settlement conferences were held on
25 August 31 and September 8, 2011 in the Commission hearing
CASE NO. IPC-E-11-810/07/11 LOBB , R . (D i ) 5
STAFF
1 room. All parties participated in both conferences.
2 Settlement discussions focused primarily on
3 revenue requirement with specific discussion regarding ROE,
4 Company salaries, Power Supply Costs and amortization of a
5 variety of test year expenses. Other topics discussed
6 included the FCA pilot program, Cost of Service, low income
7 weatherization, facilities charges, line extension
8 overheads, rate design and the appropriate level of the
9 Energy Efficiency Rider.
10 The parties stated their positions on the various
11 revenue requirement issues and presented proposals on all of
12 the other topics. There was frank and thorough discussion
13 of all issues. Tentative agreement was reached by the end
14 of the conference on the 8th by all parties except CAPAI.
15 Q.Were there further efforts and discussions about
16 issues after September 8th?
17 A.Yes, the Energy Efficiency Rider level issue was
18 still in dispute after the September 8th conference. After
19 further discussions, the parties agreed to designate the DSM
20 Rider issue as unresolved and address it at the December
21 technical hearing. After several rounds of review, all
22 parties except CAPAI signed the Stipulation and it was
23 submitted to the Commission for approval on September 23,
24 2011.
25 Q.How did Commission Staff evaluate the Proposed
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di)
STAFF
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1 Partial Settlement to determine that it was reasonable?
2 A.As in prior cases, Staff evaluated whether a
3 settlement would result in a better outcome for customers
4 than could reasonably be anticipated through litigation. In
5 this case, Cost of Service and revenue spread to the various
6 customer classes, in addition to the overall revenue
7 requirement increase, were of primary concern. Staff
S evaluated the Stipulation's merits by comparing it to what
9 might be expected if all of the parties filed testimony and
10 the case proceeded to hearing. Staff believes the
11 Stipulation, arrived at through give and take of all the
12 parties, results in both a reasonable overall base rate
13 increase and equitable treatment of all customer classes.
14 Q.Doesn' t the Commission decide what the revenue
15 requirement increase should be and how the increase should
16 be allocated to each customer class?
17 A.Yes. The Commission makes the final decision but
lS its decision must be based on the record presented through
19 testimony and other evidence. The parties to the case make
20 revenue requirement adjustment recommendations on the record
21 for the Commission to consider. The parties also make
22 recommendations regarding Cost of Service and how the
23 increase should be allocated to the various customer
24 classes. The potential outcome at hearing must therefore be
25 evaluated based on both the expected quality and quantity of
CASE NO. IPC-E-11-S10/07/11 LOBB , R . (D i )
STAFF
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1 party recommendations presented and on what recommendations
2 the Commission might ultimately accept.
3 Revenue Adjustments
4 Q.What type of adjustments to the Company's proposed
5 revenue requirement had Staff identified and what was the
6 dollar value of those adjustments?
7 A.Staff aggressively evaluated the Company's
S proposed revenue requirement increase and proposed a variety
9 of adjustments at the settlement conferences. Two of the
10 largest adjustments identified by Staff were ROE and
11 salaries. Staff maintained that the Company's proposed ROE
12 of 10.5% was excessive and unjustified under current
13 economic conditions. Similarly, Staff maintained that
14 salary increases awarded to employees in 2011 and 2012 were
15 excessive and should not be allowed for cost recovery. The
16 Staff positions of lowering the ROE to a more reasonable
17 level in combination with lower employee salaries would, in
lS our judgment, reduce the Company's revenue requirement
19 request by more than $16 million.
20 Staff also proposed various other adjustments
21 including amortization of test year expenses incurred for
22 the Bennett Mountain combustor inspection and the LIDAR
23 Survey costs; removal of Fish and Game and civic
24 organization expenses; adj ustments for FERC allocated costs,
25 smart grid investments, board of directors' compensation,
CASE NO. IPC-E-11-S10/07/11 LOBB, R. (Di)
STAFF
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1 P-Card expenses and revenue normalization. The combined
2 effect of other Staff-proposed adjustments may have reduced
3 revenue requirement by an additional $7. S million.
4 Q.Did Staff take a position on any other revenue
5 requirement issues?
6 A.Yes. The single largest adjustment proposed by
7 Staff was removing $23.9 million in Cogeneration and Small
S Power Production (CSPP) costs from base rate recovery. The
9 identified CSPP costs were associated with contracted wind
10 projects anticipated to come on line in 2011 or 2012.
11 The Company had included this level of CSPP costs
12 to offset $23.9 million in first block revenue currently
13 generated from the Hoku service contract. Both revenue from
14 the contract and the CSPP costs are captured in the PCA as
15 power supply costs if not captured in base rates. Staff
16 agreed that Hoku revenues should be included in base rates
17 because they were actually being generated. The Company's
lS intent was to hold net power supply costs in base rates at
19 levels previously approved by the Commission. However,
20 Staff did not believe it was necessary or appropriate to
21 include CSPP cost in base rates because they were projected
22 based on anticipated proj ect online dates and were not
23 actually being incurred. If the proj ects do come on line
24 and costs are incurred, they will flow through the PCA at
25 100% if they are not included in base rates. Removing the
CASE NO. IPC-E-11-S10/07/11 LOBB, R . (D i) 9
STAFF
1 CSPP cost offset to the Hoku revenue significantly decreases
2 the required base rate increase and moves recovery of the
3 CSPP costs to the PCA if and when they are actually
4 incurred.
5 Q.How confident was Staff that its adjustments could
6 be justified on the record and accepted by the Commission
7 upon hearing?
8 A.Staff was reasonably confident that at least some
9 of the proposed adjustments would be accepted by the
10 Commission at hearing. Similar ROE and employee salary
11 adjustments were favorably addressed by the Commission in
12 the recent Pacificorp general rate case (PAC-E-10-7). Staff
13 also believed that the Commission would accept the proposed
14 treatment of future CSPP costs through the PCA. However,
15 other proposed adjustments have not been addressed at
16 hearing and were less certain to be accepted by the
17 Commission. Staff was not as confident that it could
18 successfully defend the other adjustments on the record in
19 the face of rebuttal testimony provided by the Company.
20 Q.Did any of the other parties propose adjustments
21 to the Company's requested revenue requirement?
22 A.Yes. Other parties suggested adjusting ROE,
23 limiting test year proforma adjustments, modifying revenue
24 normalization and adjusting non-labor O&M. However, most of
25 these suggestions were already incorporated in Staff
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 10
STAFF
1 adj ustments, previously decided by the Commission, or in
2 Staff's view, were without sufficient support.
3 Consequently, Staff evaluated the revenue requirement
4 settlement primarily based on Staff adjustments alone.
5 Q.Why doesn' t the Stipulation specify a new ROE and
6 the other revenue requirement adjustments?
7 A.Rather than identifying a specific ROE, the
8 Stipulation specifies an overall ROR of 7.86% which combines
9 ROE, capital structure and cost of debt. Specifying a ROR
10 establishes a range of possible input parameters and
11 represents a compromise to facilitate agreement on the
12 overall revenue requirement.
13 Although the Stipulation is silent on the value of
14 many adjustments considered in arriving at the specified
15 revenue requirement increase, it does specify a few. For
16 example, the Stipulation incorporates Staff's proposed
17 amortization of Bennett Mountain Combustor Inspection costs
18 over a four-year period and a ten-year amortization of LIDAR
19 survey cost. The Stipulation also specifies the base level
20 of Net Power Supply Expenses (NPSE) for use in the PCAthat
21 includes Hoku sales revenue but excludes offsetting CSPP
22 costs.
23 Cost of Service
24 Q.Please describe the Stipulation as to customer
25 class Cost of Service and revenue spread among the classes.
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 11
STAFF
1 A.The Stipulation does not accept any specific class
2 Cost of Service methodology in spreading the revenue
3 increase to the customer classes. The parties agree that
4 the Company's class Cost of Service can be used in this case
5 for the limited purpose of establishing fixed costs for the
6 FCA mechanism, establishing an LCAR for use in the PCA and
7 for setting various rate components within individual
8 customer classes. Fixed costs in the FCA and the LCAR for
9 the PCA must be updated periodically, as are base rate power
10 supply costs, for the mechanisms to function properly. The
11 Company's proposed class Cost of Service provides a
12 reasonable basis for establishing these components.
13 Q.Why was the Company's proposed Cost of Service not
14 used to spread the revenue increase among the customer
15 classes?
16 A.Class Cost of Service has always been one of the
17 most contentious issues addressed in general rate cases.
18 Appropriate Cost of Service methodology and equitable
19 revenue spread to customer classes was also an important
20 issue in this case. Acceptance of the Company's proposed
21 class Cost of Service would have resulted in increases
22 significantly above the overall average for irrigators and
23 high load factor industrial customers while residential
24 customers would see increases below the average. The
25 proposed uniform increase for all customer classes
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 12
STAFF
1 represents a compromise that allowed the parties to achieve
2 a comprehensive revenue requirement settlement.
3 Q.Why did Staff agree to a uniform spread given the
4 results of the Company's COS?
5 A.Staff believes that some move toward Cost of
6 Service should be made based on the Company proposed Cost of
7 Service study. Therefore, in order to reach compromise on
8 rate spread, Staff evaluated the effects of moving $23.9
9 million in CSPP costs from base rate recovery to PCA
10 recovery. Staff determined that if CSPP costs are incurred
11 in 2011/2012 as anticipated by the Company, high energy
12 users such as irrigators and large industrial customers will
13 pay a larger, disproportionate share of the costs through
14 the PCA. In fact, Staff analysis showed that the spread of
15 potential CSPP cost combined with the uniform base rate
16 increase results in an overall revenue spread that generally
17 reflects the Company's proposed class Cost of Service.
18 Consequently, Staff supports the uniform base revenue spread
19 in this case.
20 Q.Is it reasonable to further delay consideration of
21 class Cost of Service methodology until the next general
22 rate case?
23 A.Yes. If reasonable allocation can occur with the
24 base rate settlement and subsequent treatment of future CSPP
25 cost through the PCA, then class Cost of Service litigation
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 13
STAFF
1 can wait until the next general rate case.
2 The reality of class Cost of Service is that it is
3 a moving target that is never fully resolved or fully
4 implemented. Nevertheless, the longer the Commission goes
5 without significant rate movement based on Cost of Service
6 the more difficult it will be to implement in the future.
7 Rate Design
8 Q.How are individual rate components proposed to be
9 changed under the Stipulation?
10 A.The Parties agreed to accept, for the purposes of
11 this case, the Company proposal to adjust rate components
12 within each class based, in part, on the Company's proposed
13 Cost of Service results. Specifically, the Stipulation
14 states that: "the signing parties agree that the existing
15 tariff rate components for all schedules should be increased
16 in a manner that is consistent with the rate design
17 originally filed by the Company in this case..." For many
18 rate components within each customer class, the Company's
19 originally-filed rate design incorporates a 5% move toward
20 Cost of Service as identified in the Company's Cost of
21 Service study.
22 Q.How does the proposed rate design impact the
23 various customer classes?
24 A.For Residential Schedule 1 customers, the customer
25 charge will increase from $4 to $5 per month. The increase
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 14
STAFF
1 in the energy rate components will depend on the season of
2 the year. Summer energy rates for each block will increase
3 by approximately 4.1%. The first and second-tier energy
4 rates in the non-summer period will increase by
5 approximately 3.1%, while the third-tier energy rate will
6 remain unchanged.
7 For Residential Schedules 3, 4 and 5, the
8 Stipulation applies the Company-proposed change in the
9 customer charge from $4 to $5 per month. The energy rate
10 for Schedule 3, Master Metered Mobile Home Parks, increases
11 by 4.13%. With respect to The Energy Watch Program (Schedule
12 4) and the Time-Of-Day (TOD) Program (Schedule 5), the
13 Stipulation accepts the Company's proposed modification from
14 three daily TOD and tiered block rates to seasonal peak and
15 off -peak rates.
16 Rate Components for Small General Service
17 (Schedule 7), Large General Service (Schedule 9), Large
18 Power Service (Schedule 19) and Agricultural Irrigation
19 Service (Schedule 24), have all been modified based in part
20 on the Cost of Service study to achieve the revenue
21 requirement allocated to each class. The individual rate
22 components proposed for each class are shown in Exhibit
23 No. 3 to the Stipulation.
24 Q.Please explain Staff's support for rate component
25 modification based on the Company's COS.
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 15
STAFF
1 A.Staff has generally supported the Company's COS
2 with respect to class revenue requirement. Staff has not
3 necessarily supported Cost of Service to adjust rate
4 components. However, in the spirit of compromise and
5 because Cost of Service can provide insight into the size
6 and relationship of the rate components within each customer
7 class, Staff agreed to the Company's rate design proposal in
8 this case. Staff additionally notes that the Company's
9 proposed Cost of Service adjustment was relatively modest
10 and was made smaller by the reduced revenue requirement
11 increase.
12 Q.Why does Staff support the increase in the
13 residential customer charge?
14 A.Staff supports the customer charge increase as
15 part of the negotiated Settlement and to recognize the
16 Company's increased investment to install sophisticated
17 automated meters and the customer information system
18 infrastructure needed for operation. The $5 customer charge
19 is also consistent with Avista's monthly charge of $5.25 and
20 Rocky Mountain Power's monthly customer charge of $5.
21 Q.Could you please explain Staff's support for the
22 proposed changes in the residential non-summer energy rates?
23 A.Yes. Staff agrees that energy production costs in
24 the non- summer period are lower than the summer period and
25 should therefore be reflected in the relative energy rates
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 16
STAFF
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paid by customers. Staff also recognizes that customers
wi th all electric homes are most severely impacted by the
third block energy rates in the non-summer period. Staff
believes that maintaining the third block non-summer energy
rate at its current level will moderate the impact on this
group of customers while continuing to provide a reasonable
price signal. Staff further believes that rural Idaho Power
customers with all electric homes have few options to
control winter electric consumption when natural gas is not
available. The proposed rate design helps reduce the cost
burden on those customers with non-discretionary winter
heating load.
Q. What is the impact of the stipulated changes on
residential and small commercial customer bills?
A. A residential customer using 1000 kWh per month
will see an average monthly bill increase of 4.54% from
$73.33 to $76.66. A residential customer using 4000 kWh per
month will see a bill increase of 2.44% from $329.09 to
$337.13 per month. A small commercial customer using 1000
kWh per month will see an average monthly increase of 3.01%
per month from $92.33 to $95.11. Staff Exhibit No. 102
shows how residential and small commercial monthly bills
will change for different usage levels.
Q. Could you please describe Staff's support for the
modification and expansion of the Company's Energy Watch and
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 17
STAFF
1 Time-Of-Day Programs?
2 A.Yes. Staff fully supports expanding these
3 voluntary programs to allow customers to choose a rate plan
4 that best fits their needs. Expanding these programs also
5 better meets the Company's needs in terms of reducing load
6 on peak hours and during critical peak periods. Staff fully
7 supports the rate design that provides two, time-of-use rate
8 periods throughout the year. The rate design is easier for
9 customers to understand and better reflects the existing
10 peak, off peak, wholesale energy markets. Finally,
11 expanding the program makes better use of the Company's
12 recently installed automated meter technology. These meters
13 were designed to provide just the type of hourly data that
14 allows these pricing programs to be implemented.
15 Separa te Dockets
16 Q.The Stipulation removes two issues from
17 consideration in this case: 1) a permanent FCA mechanism,
18 and 2) changes to Rule H line extension tariff. Why were
19 separate dockets established to consider these issues?
20 A.The FCA mechanism was set up on a pilot basis
21 after more than two years of workshops and considerable
22 review by multiple parties. The pilot itself has been in
23 place for approximately 5 years. In 2010, the Commission
24 denied the Company's request to make the FCA permanent
25 citing issues and concerns raised by various parties.
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 18
STAFF
1 Consequently, Staff believes it is inappropriate to consider
2 whether the FCA should be made permanent as part of this
3 general rate case. Staff maintains that all of the issues
4 associated with the FCA should be heard in a separate docket
5 with appropriate parties focused on the merits of a
6 permanent FCA.
7 Likewise, Staff maintains that modifying the
8 Rule H line extension tariff should be considered outside a
9 general rate case. The proposed increase of overhead
10 charges is a non-recurring charge and may be properly
11 reviewed in a separate proceeding.
12 The Energy Efficiency Rider
13 Q.What is Staff's proposal with respect to the
14 Energy Efficiency Tariff Rider?
15 A.Staff proposes that the Energy Efficiency Tariff
16 Rider be reduced from the current 4.75% of billed revenues
17 to 4.0% of billed revenues for applicable schedules. This
18 reduction helps to mitigate the increase in base rates and
19 recognizes that approximately $16.5 million in annual DSM
20 expenditures have been removed from tariff rider recovery
21 and included in base rates.
22 Q.Will the Company be required to reduce its
23 expenditures for DSM programs as a result of the tariff
24 rider reduction?
25 A.No, the revenue provided to support DSM programs
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 19
STAFF
1 through a combination of base rates and the tariff rider
2 will be significantly greater than needed to support
3 existing Company DSM programs. In his testimony, Staff
4 witness English describes and breaks down the Company's
5 annual DSM expenditures, the annual revenue needed from the
6 tariff rider and the annual revenue generated from the
7 tariff rider at 4.0% of billed revenues.
8 Q.Overall, how does the stipulated base rate
9 increase and the Energy Efficiency Tariff Rider reduction
10 impact customers?
11 A.The Stipulation specifies an overall base rate
12 increase of 4.19% and, when coupled with the 0.75% reduction
13 in the Energy Efficiency Rider, results in a net rate
14 increase of 3.44%.
15 Q.Does the Staff's proposal to reduce the Energy
16 Efficiency Tariff Rider in any way represent a reduced
17 commitment to DSM and energy efficiency?
18 A.No, not at all. Staff sees the partial shift in
19 DSM cost recovery as an opportunity to increase funding for
20 DSM programs while simultaneously mitigating the impact of
21 the proposed base rate increase. This proposal results in
22 enhanced ability to provide DSM programs and a more limited
23 overall rate increase in a difficult economy.
24 Q.Does this conclude your direct testimony in this
25 proceeding?
CASE NO. IPC-E-11-810/07/11 LOBB, R. (Di) 20
STAFF
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A.Yes, it does.
CASE NO. IPC-E-11-810/07/11 LOBB, R . (D i) 21
STAFF
LISA D. NORDSTROM (lSB No. 5733)
DONOVAN E. WALKER (ISB No. 5921)
JASON B. WILLIAMS
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
InordstromtWidahopower.com
dwalkertWidahopower.com
jwilliamstWidahopower.com
Attorneys for Idaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF IDAHO POWER COMPANY FOR, ) CASE NO.IPC-E-11-08
AUTHORITY TO INCREASE ITS RATES )
AND CHARGES FOR ELECTRIC ) STIPULATIONSERVICE IN IDAHO. )
)
This stipulation ("Stipulation") is entered into by and among Idaho Power Company
("Idaho Power" or "Company"), the Staff of the Idaho Public Utilties Commission ("StaW),
and other parties to the above referenced case as indicated by their signatures to this
settlement Stipulation. The Company, Staff, and other signing parties are referred to
individually as a "Signing Part or collectively referred to as the "Signing Parties.',1
I. INTRODUCTION
1. The terms and conditions of this Stipulation are set forth herein. The Signing
Parties agree that this Stipulation represents a fair, just, and reasonable compromise of the
1 Although all partes to this case (including the Sta. the Company, and all interveno identied in
paragraph 11.3) participated in settement discussions, CAPAI is not a Signing Part.
STIPULATION - 1 Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
i 0/07111 Page 1 of 53
issues in this proceeding and that this Stipulation is in the public interest. The Signing
Parties maintain that the Stipulation and its acceptance by the Idaho Public Utilties
Commission ("I PUC" or "Commission") represent a reasonable resolution of most issues
identified in this matter. The issues that remain unresolved, as specifed below, wil be
addressed either in this rate case proceeding or in separate proceedings, but wil not
disturb the agreements reached in this Stipulation. Therefore, the Signing Parties
recommend that the Commission, in accordance with RP 274, approve the Stipulation and
all of its terms and conditions wihout material change or condition.
II. BACKGROUND
the Company's revenues would have increased approximately $83 milion annually. Idaho
Power proposed that the rate increase be spread in varyng degrees among all major
customer classes and special contract customers. The Company requested that new rates
become effective July 1, 2011, with the expecttion that the Commission would suspend
implementation of the Company's proposed rates for the statutory period set forth in Idaho
Code § 61-622; The Commission suspended the effective date of the proposed rates for
thirt (30) days plus five (5) months from July 1, 2011, in Order No. 32272, which also
aligned with the terms of the stipulation approved in Case No. IPC-E-09-30 requiring that
any changes to the Company's base rates would not become effective until 2012.
3. Petitions to intervene in this proceeding were filed by the Community Action
Partnership Association of Idaho ("CAPAI"), Idaho Irrgation Pumpers Assciation, Inc.
("IIPA"), the Industrial Customers of Idaho Power ("ICIP"), Micron Technology, Inc.
STIPULATION - 2 Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 2 of 53
("Micron"), the United States Department of Energy ("DOE"), The Kroer Co. ("Kroget'), the
Idaho Conservation League, Snake River Allance, the NW Energy Coalition, and Hoku
Materials, Inc. ("Hoku"). By various orders, the Commission granted these interventions.
IPUC Order Nos. 32266, 32267, 32282, 32285, 32288, 32289, 32316, and 32349.
4. On July 20,2011, an informal scheduling conference was convened by Staff
for the purpose of developing a schedule for holding hearings and completing discovery.
All parties attended the settlement conferences on August 31, 2011, and September 8,
2011.
5. Based upon these settlement discussions, as a compromise of the positions
in this case, and for other consideration as set forth below, the Signing Parties agre to the
following terms:
II. TERMS OF THE STIPULATION
6. Revenue Requirement. The Signing Parties agree that Idaho Power shall be
allowed to implement revised tari schedules designed to recover $34 milion in additional
annual revenue from Idaho jurisdictional base rates, which is a 4.07 percnt overall
increase in the Company's annual Idaho jurisdictional base rate revenues. The Signing
Parties further agree that the $34 milion increase represents a compromise of the revenue
requirement positions in the case for the purpse of settlement and that the agreed upon
amount should be approved by the Commission in its entirety without further adjustment for
any factors other than those described in Section 11 ofthis Stipulation. In determining the
$34 milion additional revenue requirement, the Signing Parties agree on certain revenue
requirement inputs to be explicitly identified in this Stipulation. These are as follows:
STIPULATION - 3 Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 3 of 53
(a) Net Power Supply Expense ("NPSE"). For purpses of calculating the
Power Cost Adjustment ("PCA") mechanism, the system net power supply cost used to
determine the $34 million of additional revenue requirement increase is $208,100,936.
This base level of NPSE includes $11,252,265 of base level demand response incntive
payments that the Signing Parties agree should be tracked as part of the PCA as proposed
by the Company in its original Application and includes $23,921 ,466 of retail sales revenue
associated with Hoku's First Block energy sales that is created as an offset to power supply
expenses in the PCA. Exhibit NO.1 attached hereto details the indivdual PCA component
amounts by Federal Energy Regulatory Commission account that have been agreed upon
by the Signing Parties.
(b) Amortizations. The Signing Parties agree to a deferrl of certin 2011
expenses with multi-year amortizations of those deferr amounts. The Signing Parties
agree to a deferral of $299,546 in expenses associated with the Bennett Mountain
combustor inspection with a four-year amortization period beginning on the date that the
Company's new base rates become effective. Further, the Signing Parties agree to a
deferral of $436,047 in expenses associated with the Light Detection and Ranging
("LiDAR") survey with a ten-year amortization period beginning on the date that the
Company's new base rates becme effective.
(c) Rate of Return. The Signing Parties agree that it would be just and
reasonable for the Commission to allow the Company to earn a 7.86 percent rate of return
on an authorized Idaho jurisdictional rate base of $2,355,906,412. In addition, the Signing
Parties agree that it would be just and reasonable for the Commission to allow the
Company to earn an authorized rate of return of 7.86 percent in any Idaho Power
STIPULATION - 4 Exhibit No. 101
Case No. IPC-E-1l-8
R. Lobb, Staff
10/07/11 Page 4 of 53
regulatory matter to be determined by the Commission until it is subsequently changed by
Commission order.
7. Rate Spread. The Signing Parties agre that the above-escribe $34 milion
revenue requirement increase should be recovered by implementing taris in conformance
with the attached Exhibit No.2, which increase the rates for each customer class and
special contracts customers by a uniform percentage amount of approximately 4.19
percent.2 The Signing Parties further agree that the Company's proposed cost-of-service
study wil be used to determine fixed costs for purpses of the Fixed Cost Adjustment
("FCA") mechanism until the Commission approves a different cost-of-service study. The
Signing Parties agree that the acceptance of the use of the Company's cost-of-service
study in the context of the FCA for the purposes of settlement is not acceptance of any
methodology underlying the Company's cost-of-servce study results, is not binding on the
Signing Parties in future general rate case proceedings, and does not imply agreement on
the merits of the methodology.
8. Rate Design. In determining the indivdual rates for each tariff schedule, the
Signing Parties agree to use the 2011 Test Year customer billng determinants as
proposed by the Company in this case with the exception of agreed upon adjustment in
Schedule 1 residential energy components. The Signing Parties agree that the existing
tariff rate components for all schedules should be increased in a manner that is consistent
with the rate design originally filed by the Company in this case, including increasing the
2 The resulting uniform percntage increase amount of approximatef4.19 pent is gre
than thoverall increase of 4.07 percent beuse the overall increase does not apply to First Block rates for speial
contract customer Hoku Materials, Inc.
STIPULATION - 5 Exhibit No. 101
Case No. IPC-E-1l-8
R. Lobb, Staff
10/07/11 Page 5 of 53
monthly Service Charge for residential Schedules 1, 4, and 5 from $4.00 to $5.00. The
attached Exhibit No. 3 details the specific rates for each schedule.
9. Load Change Adjustment Rate. In determining the agreed-upon Load
Change. Adjustment Rate ("LCAR") to be applied in the Company's PCA, the Signing
Parties agree to use Idaho Power's filed class cost-of-service methodology to determine
the generation-related Idaho jurisdictional revenue requirement that has been classifed as
energy-related. The resulting LCAR of $18.16 per megawatt-hour was developed using
2011 normalized system-wide firm loads in the amount of 14,822,063 megawatt-hours as
proposed by the Company in this case. Exhibit No. 4 to the Stipulation details the
derivation of the agreed upon LCAR that is to become effective on the date that the
Company's new base rates become effective.
10. Separate Proceedings. To faciltate further investigation and participation,
the Signing Parties agree that Idaho Power will initiate separate, subsequent proceedings
related to:
(a) Increasing overhead amounts paid by persons or entities requesting
servces under the Company's Rule H line extension tariff; and
(b) Whether the FCA pilot program should be made permanent. The
Signing Parties agree, however, that the. FCA case should be processed to allow a final
Qrderto be issued no later than March 30, 2012. To allow for the timely processing of the
FCA case, the Signing Parties request that the Commission decide at Its earliest
convenience (after a 14-day response period per RP 256) whether to process the FCA
case as a separate docket. The Signing Parties further agree that if the Commission
approves or extends the FCA program beyond 2011, no Signing Part will object to
STIPULATION - 6 Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 6of53
retroactively applying the subsequently determined fixed costs per customer ("FCC") and
fixed costs per energy ("FCE") inputs to January 1, 2012.
11. Unresolved Issues. The Signing Parties were not able to reach consensus on
the following issues, which wil proceed to hearing under the schedule established in Order
No. 32316:
(a) The level of the Energy Effciency Rider;
(b) Low-income Weatherization Assistance for Qualified Customer
program funding; and
(c) The facilty charge rate determination methodology used to develop
facilties charges assessed to Schedule 19 customers and issues relating to the ownership
of facilities subject to facilities charges. However, the Signing Parties agree that any
revenue requirement impacts resulting from changes to the facilty charge methodology or
changes in propert ownership shall be directly assigned to Schedule 19 customers in the
form of a base rate increase or reduction so that no other customer classes shall be
impacted by any resulting change.
12. Rate Effecive Date. The Signing Partes encourage the Commission to issue
Its Order approving the agreed-upon rates contained in this Stipulation to become effecive
on January 1, 2012.
13. The Signing Parties agree that this Stipulation represents a compromise of
the positions of the Signing Parties in this case. As provided in RP272, other than any
testimony filed in support of the approval of this Stipulation, and except to the extent
necessary for a Signing Part to explain before the Commission its own statements and
positions with respect to the Stipulation, all statements made and positions taken in
STIPULATION.; 7 Exhibit No. 101
Case No. IPC-E-1l-8
R. Lobb, Staff
10/07/11 Page 7 of 53
negotiations relating to this Stipulation shall be confidential and will not be admissible in
evidence in this or any other proceeding.
14. The Signing Parties submit this Stipulation to the Commission and
recommend approval in its entirety pursuant to RP 274. The Signing Parties shall support
this Stipulation before the Commission, and shall not appeal a Commission Order
approving the Stipulation or an issue resolved by the Stipulation. If this Stipulation is
challenged by anyone who is not a Signing Part, the Signing Parties reserve the right to
file testimony, cross-examine witnesses, and put on such case as they deem appropriate to
respond fully to the issues presented. including the right to raise issues that are
incorporated in the settlements embodied in this Stipulation. Notwithstanding this
reservation of rights, the Signing Parties agree that they wil continue to support the
Commission's adoption of the terms of this Stipulation.
15. If the Commission rejects any part or all of this Stipulation, or imposes any
additional material conditions on approval of this Stipulation, each Signing Part reserves
the right, upon wrtten notice to the Commission and the other Signing Parties to this
proceeding, within fourteen (14) days of the date of such aption by the Commission, to
withdraw from this Stipulation. In such case, no Signing Part shall be bound or prejudice
by the terms of this Stipulation, and each Signing Part shall be entitled to seek
reconsideration of the Commission's Order, file testimony as it chooses, cross-examine
witnesses, and do all other things necessary to put on such case as it deems appropriate.
In such case, the Signing Parties immediately wil request the prompt reconvening of a
prehearing conference for purposes of establishing a procedural schedule for the
completion of the case. The Signing Parties agree to cooperate in development of a
STIPULATION - 8 Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10107111 Page 8 of 53
..
schedule that concludes the proceeding on the eariiest possible date, taking into accunt
the nees of the Signing Parties in participating in hearings and preparing briefs.
16. The Signing Parties agree that this Stipulation is in the public interest and that
,
all of its terms and conditions are fair, just, and reasonable.
17. No Signing Part shall be bound, benefited, or prejudiced by any position
asserted in the negotiation of this Stipulation, except to the extent expressly stated herein,
nor shall this Stipulation be construed as a waiver of rights unless such rights are expressly
waived herein. Except as otherwise expressly provided for herein, execution of this
Stipulation shall not be deemed to constitute an acknowledgment by any Signing Part of
the validity or invalidity of any particular method, theory, or principle of regulation or cost
recovery. No Signing Part shall be deemed to have agreed that any method, theory, or
principle of reulation or cost recovery employed in arrving at this Stipulation is appropriate
for resolving any issues in any other proceeding in the Mure. No findings of fact or
conclusions of law other than those stated herein shall be deemed to be implicit in this
Stipulation.
18. The obligations of the Signing Partes are subject to the Commission's
approval of this Stipulation in accrdance with its terms and conditons and upon such
approval being upheld on appeal, if any, by a court of competent jurisdiction.
19. This Stipulation may be executed in counterparts and each signed
counterpart shall constitute an original document.
/I
/I
/I
STIPULATION - 9
Exhibit No. 101
Case No. IPC-E-1l-8
R. Lobb, Staff
10/07/11 Page 9 of 53
L" -tDATED this dO day of September 2011.
Idaho Power Company
By~fliHw
Lisa D. NordSt
Attorney for Ida 0 Power Company
Idaho Irrgation Pumpers Association, Inc.
By
Eric L. Olsen
Attorney for Idaho Irrgation Pumpers
Association, Inc.
Micron Technology, Inc.
By
Thorvald Nelson
Attorney for Micron Technology, Inc.
The Kroger Co.
By
Kurt J. Boehm
Attorney for The Kroger Co.
Hoku Materials, Inc.
By
Dean J. Miler
Attorney for Hoku Materials, Inc.
Snake River Allance
By
Ken Miler
Clean Energy Program Director for
Snake River Aflance
STIPULATION -10
Idaho Public Utilities Commission Staff
By
Donald H. Howell, "
Attorney for Commission Staff
Industrial Customers of Idaho Power
By
Peter J. Richardson
Attorney for Industrial Customers
of Idaho Power
U.S. Department of Energy
By
Arthur Perr Bruder
Attorney for U.S. Department of
Energy
Idaho Conservation League
By
Benjamin J. Otto
Attorney for Idaho Conservation League
NW Energy Coalition
By
Nancy Hirsh
Policy Director for NW Energy Coalition
Exhibit No. 101
Case No. IPC-E-1l-8
R. Lobb, Staff
10/07/11 Page 10 of 53
day of September 2011.
Idaho Public Utilties Commission StaffB~cÍ~
Donald H. Howell, II
Attorney for Commission Staff
Industrial Customers of Idaho Power
DATED this
Idaho Power Company
By
Lisa D. Nordstrom
Attorney for Idaho Power Company
Idaho Irrgation Pumpers Association, Inc.
By
Eric L. Olsen
Attorney for Idaho Irrgation Pumpers
Assciation, Inc.
Micron Technology, Inc.
By
Thorvald Nelson
Attorney for Micron Technology, Inc.
The Kroger Co.
By
Kurt J. Boehm
Attorney for The Kroger Co.
Hoku Materials, Inc.
By
Dean J. Miler
Attorney for Hoku Materials, Inc.
Snake River Allance
By
Ken Miler
Clean Energy Program Director for
Snake River Allance
STIPULATION -10
By
Peter J. Richardson
Attorney for Industrial Customers
of Idaho Power
U.S. Department of Energy
By
Arthur Perr Bruder
Attorney for U.S. Department of
Energy
Idaho Conservation League
By
Benjamin J. Oto
Attorney for Idaho Conservation League
NW Energy Coalition
By
Nancy Hirsh
Policy Director for NW Energy Coalition
Exhibit No. 10 1
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 11 of 53
OATEO thI$ _ day of September2011.
Idaho Power Company
By.
Lisa O. Nordsom
Attorney for Idaho Power Company
(;. sen
Attorney for Idaho Irrigation Pumpers
Association, Inc.
Micron Technology, Inc.
By
Thorvld Nelsn
Attrney før Micron Technolog, Inc.
The Kroger Co.
By
Kurt J. Boehm
Attofny for The Kroger co.
Hoku Materials, Inc.
By
Dean J. Miler
Attmey fur Hoku Materials, Inc.
Snake RIVer Allance
By
Ken Miller
Clean Enegy Program Dlretor for
Snake River Amance
STlPUl. TlN - 10
Idaho Public Utlits Commission Sta
By
Donald H. Howell, II
Attmey for Commfsion Staf
Industrial CU$tomersof Idaho Powr
By
Peter J. Richardson
Attomeyfor IndUSril Customers
of Idaho Power
U.S. Departnt of Energ
By
Artur Perry Bruder
Attrney for U.S. Department ofEnerg
Idaho Conservation Leaue
By
Benjamin J. oto
Attrney for Idaho Consatin League
NW Energ Coalitio
By
Nancy Hirsh' . '. .
policy Direcor for NW EnergyCoaliton
Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 12 of 53
lJ
DATED this 2! day of September 2011.
Idaho Power Company
By
Lisa D. Nordstrom
Attorney for Idaho Power Company
Idaho Irrgation Pumpers Assoation, Inc.
By
Eric L. Olsen
Attorney for Idaho Irrigation Pumpers
Association, Inc.
Micron Technology, Inc.
By
Thorvald Nelson
Attorney for Micron Technology, Inc.
The Kroger Co.
By
Kurt J. Boehm
Attorney for The Kroger Co.
Hoku Materials, Inc.
By
Dean J. Miller
Attomey for Hoku Materials, Inc.
Snake River Allance
By
Ken Miler
Clean Energy Program Director for
Snake River Allance
STIPULATION -10
Idaho Public Utilities Commission Staff
By
Donald H. Howell, II
Attomey for Commission Staff
Industrial Customers of Idaho PowerByD.kl~ardson
Attomey for Industrial Customers
of Idaho Power
U.S. Departent of Energy
,¿
By
Arthur Perr Bruder
Attorney for U.S. Department of
Energy
Idaho Conservation League
By
Benjamin J. Oto
Attorney for Idaho Conservation league
NW Energy Coalition
By
Nancy Hirsh
Policy Director for NW Energy Coalition
Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 13 of 53
../ Á
DATED thiS",)O -'day of September 2011.
Idaho Power Company
1":;' i CA),.Bye( \ '44. IV. I" â 1 l--;f ¡(J')..
Lisa D. NOrdst~m
Attomey for Idaho Power Company
Idaho Irrigation Pumpers Association, Inc.
By
Eric L. Olsen
Attorney for Idaho Irrigation Pumpers
Association, Inc.
Micron Technology, Inc.
BYP¿~~~
TR61'1e1 ~~eIB6t' ~S:"'_"'''''''''-t
Attorney for Micron Technology, Inc.
The Kroger Co.
By
Kurt J. Boehm
Attorney for The Kroger Co.
Hoku Materials, Inc.
By
Dean J. Miler
Attorney for Hoku Materials, Inc.
Snake River Alliance
By
Ken Miller
Clean Energy Program Director for
Snake River Allance
STIPULATION - 10
Idaho Public Utilties Commission Staff
By
Donald H. Howell, II
Attorney for Commission Staff
Industrial Customers of Idaho Power
By
Peter J. Richardson
Attorney for Industrial Customers
of Idaho Power
U.S. Department of Energy
By
Arthur Perr Bruder
Attorney for U.S. Department of
Energy
Idaho Conservation League
By
Benjamin J. Otto
Attorney for Idaho Conservation League
NW Energy Coalition
By
Nancy Hirsh
Policy Director for NW Energy Coalition
Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 14 of 53
.'
.'
. 1J . .
DATE th.: dad 8ebw ~011.
!.iI
. 1d'Po CG. . . .~~""'. .~.W . PøCøriJd ~ Pu~ Inc. ... fBY. ,iò l.~ Ql . .~ 'l'ki:lt ~1'~anc.' ,, '~çn~~ in.'
)BY ."1'rvNØJ ,~MlT~~.
li .Krrt?. ..'
'SY,
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Ho ~ i,. .~. .~".Ui .A' fo Ha Ma. Ik
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'~4:?4+ ., a.~~~fo8n~
. .$~-tØ
lda PU tJ.~ st . .
BY J"~ H. HG,II~ to'Ocn.S
Ind Cu d ld. P. ., . ,
8y'',==l(~:.ofid 'P, .'. UA~d~.', " \
"". "~.£i cl~ J. ., Arb~Si " ..~'JQO.s. OØl8Ul.Øf.. ,En .,k,ah Cøn ,i.ue .
, I
By , ,~J,Ot . ,~.fo~~;Lea
:~~=~1oNw'~1f
I..-.I .,._I_"~U-""\, .
. ., '
. '. .
Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 15 of 53
Micro Tecnolog, Inc.
By
Thrvald Neln ,
Attmey for Micr Technolog, Inc.
The Krer Co.
BYU~"iJ.Bohm
Attomey fo The Krer Co.
Hoku Materials, Inc.
By
Den J. Milter
Attrny for Hoku Materals, Inc.
Snake River Alliance
By
Ken MIer
Clean Energ Proram Direr for Snake
Riv Alliance
STPULATION -12
U.S. Departt of Energ
ByArur Pen Bner
At for U.S. Dertent ofEnerg
Idaho Conservtion League
By
Benjamin J. Ot
Attme for Idaho Conservtion
League
NW Ener Coanton
By
Nancy Hirs
Policy Directr for NW EnerColitin
~
Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/0711 1 Page 16 of 53
/
I
DATE" zi __I...20i."Po~ ..NIU..s.C..,. Sl...
-u¡ tr¡¡AI.. told Pø.~
ld ....... AI.Da..1n
-&iLdiAlon'" fa ic ln J I., PuAn..ln..T...1n
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-õïJ...
At fa.. M,'1 rC.... In
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tc eol.i '11...By~~
AI..... eo'.FUIi. Li q .
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Exhibit No. 101
Case No. IPC-E-1l-8
R. Lobb, Staff
10/07111 Page 17 of 53
'\/\ '1
DATED this ~ day of Septembe 2011.
Idaho Pow COmpany
B~.D~Wn
Ã:~:;:~~ Power Company
IdahO Irration Pumpe Assatn, Inc
By
Eric L. Olsen
Attmey for ldaho Irrgatin Pumpe
Msociatlon, Inc.
Mk:n Teçhnolo, Inc.
By .
Thorvld Nelson
Attrney for Micrn Technoloy, Inc.
The Krr Co.
I3Y
Kurt.J.80ehm
Attméy for The Krr Co.
~
Attrney for Hoku Materials, Inc.
Snake Rier Alliance
By
Ken Miller
Clean Energy Proram Direr for
SnakeRlvr Allianc
STIPULATION - 10
Idaho PubiC UtIIt COmmission Staff
l3y
Donald H. Holl, U
Attomeyfor COmml8lon Staff
Indusril Custom_ of Idaho Pøwer
By Peer J. RichrdsonAttrny for Indu$lal Custrs
ofldahO Por
U.S. Départnt of Ene
By Arhur Per Bruer
Atttneyfor U.S. Departnt of
Energy
Idaho COnseMln League
By'
Benjamin J. Ot
Attrney for IdahO COnsn Leaue
NW EnColltn
By'
Nanc HirshPoli Directr forNW Ene Colitn
Exhibit No. 101
Case No. IPC-E-l 1-8
R. Lobb, Staff
10/0711 1 Page 18 of 53
"
, 1: ' ,DATED th ~o day ,~f September ?O.11,
,
I
ii
iii'i
,
'ldahe' Powr COn'ai. .ii~ tribh .
Usa D. tiør ., .'. , Ät$f.fó Ida: . Po'.COmpny
Jdabo IrFat Pum¡;er ASstör.i', 100.. (
By' '
fò -L.. Q1sen .Atey -wr Idaho :1n:gstiØl PUrn~lolnc. .
~cr :reç.Q~lo.. lno,'
)By ,
'ThorvJdNelsri , . . ¡
Ati'fdr MlQln TechAO ifAö.
J
Th,~r1?.
SY,
, Kurt..J. Boehm "
" .Atl1yfor næ ~er Co.
Ho ~ri~, lr.
By i
Den J. 'MlIèrA1rn fo Hak Maáls, InC.
". --_._._-&h RlJí . '.
, Bv ,k 'Y¡g ,KetiMir 'Qln EnR('Proia ~TfOTSnae Ri A1ai
$'r1P,1''N -1'0
Idáho Public Utlit' Comisr. st
By, oJ'
Dold -H. Hawel, IIAttrney for'Ooml'sln Stff
(ri1 êustôrs of ldah POWr. '
By'Petr J.RJar
.At~forlnd,i¡aJ Çwmø ,,of ld'Por.
~.s. ;~rt~ EnefØ
BX ', Aitur'Ps,I ~rtr
Atlt)ftì~.fpr-o;S. Derbl1entøf,, .En
IdafiCol'nleagtl
,
By BeajInJ.Ot ' .Att.for.Ld Oòl'n. Lea
..:~~'Nana¡Hr ' .
POllåY Direor fo NW'EnøGolln'. ,
(
, Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 19 of 53
'. I
"
BEFORE THE
IDAHO PUBLIC UTILITlES COMMISSION
CASE NO. IPC-E..11-08
IDAHO POWER COMPANY
EXHIBIT NO.1
Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 20 of 53
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IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-11-08
IDAHO POWER COMPANY
EXHIBIT NO.2
Exhibit No. 101
Case No. IPC-E-1l-8
R. Lobb, Staff
10/07/11 Page 22 of 53
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IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC.E.11.08
"
IDAHO POWER COMPANY
EXHIBIT NO. 3
Exhibit No. 101
Case No. IPC-E- 11-8
R. Lobb, Staff
10/07/11 Page 25 of 53
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Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 28 of 53
Exhibit No.3
Case No. IPCE-11-D
Setment Stipulation, IPC
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10/07/11 Page 39 of 53
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Exhibit No. 101
Case No. IPC-E-1 1-8
R. Lobb, Staff
10/07/11 Page 42 of 53
Exibit NO.3
Case NO.IPC-E-11..
Settlement Stilation, IPC
Page 17 of 24
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R. Lobb, Staff
10/07/11 Page 46 of 53
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R. Lobb, Staff
10/07/11 Page 47 of 53
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R. Lobb, Staff
10/07111 Page 48 of 53
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IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-11-08
IDAHO POWER COMPANY
EXHIBIT NO.4
Exhibit No. 101
Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 50 of 53
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Case No. IPC-E-11-8
R. Lobb, Staff
10/07111 Page 51 of 53
exhibit No. 4Case NO.IPC-11..
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R. Lobb, Staff
10/07/11 Page 52 of 53
Exhibit NO.4
Case No. 1PC-11-0
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Case No. IPC-E-11-8
R. Lobb, Staff
10/07/11 Page 53 of 53
Exhibit No. 4
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Exhibit No. 102
Case No. IPC-E- 11-8
R. Lobb, Staff
10/07/11 Page 2 of2
CERTIFICATE OF SERVICE
I HEREBY CERTIFY THAT I HAVE THIS 7TH DAY OF OCTOBER 2011,
SERVED THE FOREGOING DIRECT TESTIMONY OF RANDY LOBB IN SUPPORT
OF THE STIPULATION AND SETTLEMENT, IN CASE NO. IPC-E-I1-08, BY
E-MAILING AND MAILING A COpy THEREOF, POSTAGE PREPAID, TO THE
FOLLOWING:
LISA D NORDSTROM
DONOV AN E WALKER
JASON B WILLIAMS
IDAHO POWER COMPANY
PO BOX 70
BOISE ID 83707-0070
E-MAIL: Inordstrom(fidahopower.com
dwalker(fidahopower.com
jwiliams(fidahopower .com
PETER J RICHARDSON
GREGORY MADAMS
RICHARDSON & O'LEARY
PO BOX 7218
BOISE ID 83702
E-MAIL: peter(frichardsonandoleary.com
greg(frichardsonandolear .com
ERIC L OLSEN
RACINE OLSON NYE ET AL
PO BOX 1391
POCATELLO ID 83204
E-MAIL: elo(fracinelaw.net
ARTHUR PERRY BRUDER
ATTORNEY -ADVISOR
US DEPT OF ENERGY
1000 INDEPENDENCE AVE SW
WASHINGTON DC 20585
E-MAIL: Arthur.bruder(fhq.doe.gov
GREGORY W SAID
VPREGULATORY AFFAIRS
IDAHO POWER COMPANY
PO BOX 70
BOISE ID 83707-0070
E-MAIL: gsaid(fidahopower.com
DR DON READING
6070 HILL ROAD
BOISE ID 83703
E-MAIL: dreading(fmindspring.com
ANTHONY Y ANKEL
29814 LAKE ROAD
BAY VILLAGE OH 44140
E-MAIL: tony(fyanel.net
DWIGHT ETHERIDGE
EXETER ASSOCIATES
10480 LITTLE PATUZENT PKWY
STE 300
COLUMBIA MD 21044
E-MAIL: detheridge(fexeterassociates.com
CERTIFICATE OF SERVICE
E-MAIL ONLY:
STEVE A PORTER
US DEPT OF ENERGY
E-MAIL: steven.porterCfhq.doe.gov
KURT JBOEHM
BOEHM KURTZ & LOWERY
36 E SEVENTH ST STE 1510
CINCINATI OH 45202
E-MAIL: kboehmCfbkllawfrm.com
E-MAIL ONLY:
RICHARD E MALMGREN
SR ASST GENERAL COUNSEL
MICRON TECHNOLOGY INC
E-MAIL: remalmgrenCfmicron.com
E-MAIL ONLY:
THORV ALD A NELSON
MARK A DAVIDSON
FRED SCHMIDT
HOLLAND & HART LLP
E-MAIL: tnelsonCfhollandhar.com
madavidsonCfhollandhar.com
fschmidtCfhollandhart.com
Inbuchanan(áhollandhart.com
BENJAMIN J OTTO
ID CONSERVATION LEAGUE
710N 6TH ST
BOISE ID 83702
E-MAIL: bottoCfidahoconservation.org
E-MAIL ONLY:
JOHN R HAMMOND JR
BATT FISHER PUSCH
& ALDERMAN LLP
E-MAIL: jrhCfbattfisher.com
KEVIN HIGGINS
ENERGY STRATEGIES
215 S. STATE ST SUITE 200
SALT LAKE CITY UT 84111
E-MAIL: khiggins(áenergystrat.com
ELECTRONICI CDI PAPER SERVICE
MARY V YORK
HOLLAND & HART LLP
101 S. CAPITAL BLVD., SUITE 1400
BOISE,ID 83702
E-MAIL: myorkCfhollandhar.com
BRAD MPURDY
ATTORNEY AT LAW
2019 N 17TH STREET
BOISE ID 83702
E-MAIL: bmpurdyCfhotmaiL.com
KEN MILLER
SNAKE RIVER ALLIANCE
BOX 1731
BOISE ID 83701
E-MAIL: kmilerCfsnakeriverallance.org
CERTIFICATE OF SERVICE
NANCY HIRSH
POLICY DIRECTOR
NW ENERGY COALITION
811 1 ST AVE., SUITE 305
SEATTLE WA 98104
E-MAIL: nancy(fnwenergy.org
SCOTT PAUL CEO
HOKU MATERIALS INC
ONE HOKU WAY
POCATELLO ID 83204
E-MAIL: spaul(fhokucorp.com
DEAN J MILLER
McDEVITT & MILLER LLP
PO BOX 2564
BOISE ID 83701
E-MAIL: joe(fmcdevitt-miler.com
heather(fmcdevitt-miler .com
~~.V~¿
SECRETARY
CERTIFICATE OF SERVICE