20100316Supplement 1.pdf

An IDACORP Boise, Idaho
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Idaho Power Company Supplement 1: Cost-Effectiveness
TABLE OF CONTENTS
Table of Contents............................................ ....................................................................................... 1
Supplement 1: Cost-Effectiveness .......................................................................................................... 1
Cost-Effectiveness ........................................................................................................................... 1
Northwest Power and Conservation Council's 6th Power Plan ..........................................................3
Cost Effectiveness Tables by Program. ........ ....... ............... ............ .... ... ..... .......... .... ......... ......... ............ 5
NC Cool Credit ............................................................................................................................... 5
FlexPeak Management............. ..... .......... ...... ........ ... ....... ................... ....... ........... ............ ........ ........ 7
Irrigation Peak Rewards................................................................................................................... 9
Ductless Heat Pump Pilot.............................................................................................................. .11
Energy Efficient Lighting.... ..... .... .... ...... ......... .... ... ............ .... ... .... ... ..................... ........ ......... ..... ....13
Energy House Calls........................................................................................................................ .15
ENERGY STARiIHomes Northwest...............................................................................................21
Heating & Cooling Effciency Program...........................................................................................23
Home Improvement Program. .............. ........ .... ........ ..... ..... ..... ................. .... ........... .... ........ ......... ...27
Home Products Program.. ................... ......... ........ .... ..... ........... .............. ....... .............. ................... .29
Rebate Advantage ........ ... ........... .... ..... ..... ... ......... ..... ........ ..... ......... ....... ...... ............ ... ....... ............ .31
See Ya Later Refrigerator.................................................................................................................35
Weatherization Assistance for Qualified Customers ........................................................................37
Weatherization Solutions for Eligible Customers ............................................................................39
Building Efficiency......... .......... ..... ....... ........ ....... ........ ............ ... .... ........ ........ ... ......... ....................41
Custom Effciency...........................................................................................................................43
Easy Upgrades.... .......... '" ... ....... ... .......... ...... ..... .......... ... .................... ....... ........ ......... ........ ............45
Holiday Lighting .............................................................................................................................57
Irrigation Effciency......... ..... ..... .... ......... ...... ..... ... ...... .................... ..... .............. ............ ...... .... .......59
Demand-Side Management 2009 Annual Report Pagei
Idaho Power Company Supplement 1: Cost-Effectiveness
SUPPLEMENT 1: CosT..E ESS
Cost..Effectiveness
Idaho Power considers cost-effectiveness of primary importance in the design, implementation,
and tracking of energy effciency and demand response programs. In the past, most ofIdaho Power's
energy efficiency and demand response programs were preliminarily identified through the Integrated
Resource Plan (IRP) process. Because ofIdaho Power's diversified portfolio of programs, in the
2009 IRP most ofthe new potential for energy effciency in Idaho Power's service area is based on
additional measures rather than new programs. The process in the IRP remains the same for determining
if measures should be adopted as it was for program inclusion. Specific programs or potential energy
savings measures are screened by sector to determine if the levelized cost of these programs or measures
is less than supply-side resource alterntives. If they are shown to be less costly than supply-side
resources from a levelized cost perspective, the hourly shaped energy savings is subsequently included
in the IRP as a resource.
Prior to the actual implementation of energy efficiency or demand response programs, Idaho Power
performs a cost-effectiveness analysis to assess whether a specific potential program design will be
cost-effective from the perspective of Idaho Power and its customers. Incorporated into these models are
inputs from various sources in order to use the most current and reliable information available.
When possible, Idaho Power leverages the experiences of other companies in the region, or throughout
the country, to help identify specific program parameters. This is typically accomplished through
discussions with other utilities' program managers and researchers. Idaho Power also uses electric
industry research organizations, such as E Source, Edison Electrical Institute (EEl), Consortium for
Energy Efficiency (CEE), American Council for an Energy Effcient Economy (ACEEE), Advanced
Load Control Alliance (ALCA), Association of Energy Service Professionals (AESP), Energy Insights,
and others, to identify similar programs and their results.
For other assumptions, including estimated costs, savings, and net-to-gross (NT G) ratio estimates,
Idaho Power relies on sources such as the Northwest Power and Conservation Council (NPCC),
Regional Technical Forum (RTF), Northwest Energy Effciency Allance (NEEA), the Database for
Energy Effciency Resources (DEER), the Energy Trust of Oregon (ETO), the Bonnevile Power
Administration (BPA), third-party consultants, and other regional utilities. The remaining inputs used in
the cost-effectiveness models are obtained from the IRP process. The Technical Appendix of
Idaho Power's most recent IRP is the source for the financial assumptions, including the discount rate
and inflation rate. The IRP is also the source of the demand-side management (DSM) alternative costs,
which is the value of energy savings and demand reduction resulting from the DSM programs.
These DSM alternative costs vary by season and time of day. The DSM alternative energy costs are
based on either projected fuel costs of a peaking unit or forward electricity prices as determined by
Idaho Power's power supply model, AURORAxmpiI Electric Market ModeL. The avoided capital cost of
capacity is based on a gas fired simple cycle turbine.
For its cost-effectiveness methodology, Idaho Power relies on the Electric Power Research Institute End
Use Technical Assessment Guide (TAG), the California Standard Practice Manual and its subsequent
addendum, and the National Action Plan for Energy Effciency's (NAPEE) Understanding
Cost-Effectiveness of Energy Effciency Programs: Best Practices, Technical Methods, and Emerging
Issues for Policy-Makers. Traditionally, Idaho Power has primarily used the Total Resource Cost (TRC)
test and the Utility Cost (UC) test to develop benefit/cost (B/C) ratios to determine the cost-effectiveness
Demand-Side Management 2009 Annual Report Page 1
Supplement 1: Cost-Effectiveness Idaho Power Company
ofDSM programs. These tests are stil used because, as defied in the TAG and California Standard
Practice Manual, they are the most similar to supply-side tests and provide a useful basis to compare
demand-side and supply-side resources.
Idaho Power determines cost-effectiveness on a measure basis, where relevant, and program basis.
As part ofthe Demand-Side Management 2009 Annual Report Supplement 1: Cost-Effectiveness and
where applicable, Idaho Power has begun publishing the cost-effectiveness by measure, calculating the
paricipant cost test (PCT) at the program level, listing the assumptions associated with
cost-effectiveness, and citing sources and dates of metrics used in the cost-effectiveness calculation.
In future demand-side management annual reports, Idaho Power wil also include the Rate Payer Impact
(RIM) test as specified in the memorandum of understanding (MOU) included in Supplement 2:
Evaluation. Within the MOU, the IPUC staffhas agreed to provide reasonable and necessary leeway for
the implementation of the guidelines described in the MOU for the Demand-Side Management 2009
Annual Report.
The B/C ratio from the participant cost perspective is not calculated for the demand response programs,
Weatherization Assistance for Qualified Customers, Weatherization Solutions for Eligible Customers,
See Ya Later Refrigerator, and Energy House Calls. These programs have few or no customer costs.
The Irrigation Peak Rewards program does have some direct costs for paricipants with small
horsepower (hp) pumps where a fee is charged to intall program equipment at the enrolled service
location. Idaho Power markets the Irrigation Peak Rewards program to all irigation customers.
For those customers who have at least one pump of greater than 30 hp, Idaho Power sends them an
estimate of incentives and indicates if a fee for participating in the program might apply for each of their
service locations. This estimate gives the potential participant information necessary to determine if the
program could be beneficial to them while letting the customer include their own unique expenses,
such as additional labor.
Idaho Power's goal is to have all mature programs have B/C ratios greater than 1.0 for the TRC, UC,
and PCT tests at the program level and the measure level where appropriate. An exception to this is
when there is interaction between measures. Idaho Power may choose to launch a pilot or a program to
evaluate estimates or assumptions in the cost-effectiveness analysis. Following implementation of a
program, cost-effectiveness analyses are reviewed as new inputs from actual program activity become
available, such as actual program expenses, savings, or paricipation levels. If measures or programs are
determined to be not cost-effective after implementation, the program or measures are reexamined
including input provided from the company's energy effciency advisory group.
The Demand-Side Management 2009 Annual Report contains program UC and TRC B/C ratios using
actual cost information over the life of the program through 2009. Supplement 1: Cost-Effectiveness
contains annual cost-effectiveness metrics for each program using actual information from 2009,
includes results of the PCT, and includes application ofa NTG factor where appropriate. Curent
customer energy rates were used in the calculation of the B/C ratios from a PCT perspective.
Rate increases were not forecast or escalated. Where applicable, the cost-effectiveness results ofthe
demand response programs include historical expenses. To be consistent with the IRP, and since demand
response programs are inherently different from energy efficiency programs, the B/C ratios for
NC Cool Credit and Irrigation Peak Rewards are calculated over a 20-year program life, while the B/C
ratios for FlexPeak Management are calculated over 10 years.
Page 2 Demand-Side Management 2009 Annual Report
Idaho Power Company Supplement 1: Cost-Effectiveness
Following the annual program cost-effectiveness results are tables that include measure level
cost-effectiveness. Exceptions to the measure level tables are the demand response programs which do
not provide incentives for installed end-use measures. Other programs that are not analyzed at the
measure level include Custom Efficiency, the Custom Option ofIrrigation Efficiency Rewards,
and Weatherization Assistance for Qualified Customers where projects include multiple interactive
measures that are analyzed at the project leveL.
The measure level cost-effectiveness includes inputs of measure life, energy savings, demand reduction,
incremental cost, NTG factors, incentive, program administration cost, and net benefit. Program
administration costs include all non-incentive costs: labor, marketing, training, education, purchased
services, and evaluation. NTG ratios are used in the calculation of the B/C ratios of most programs.
For some programs including Energy Effcient Lighting and See Ya Later Refrigerator the unit
incremental savings are net realized energy savings from third pary sources. The energy savings for the
Menu Option ofIrrigation Effciency Rewards also includes a NTG adjustment in the unit incremental
savings. For the Custom Effciency program a NTG adjustment is not used in the B/C ratio calculations
because each project is analyzed independently and Idaho Power believes that there is considerable
spilover from this program. A sensitivity analysis was performed for this program which indicated that
even with a NTG adjustment of 30 percent the program would stil be cost-effective from a
TRC perspective.
Northwest and Conservation Council's 6th Power Plan
On February 10,2010 members of the NPCC, also known as the council, adopted the NPCC's
6th regional power plan, the Sixth Power Plan. The plan identifies a five-year regional energy saving
target of 1,200 average megawatts (aMW and calls for 5,900 aMW of cost-effective effciencies by
2030. Idaho Power along with the BPA, NEEA, other Northwest power delivery companies,
and interested stakeholders participated in workshops and meetings to help determine what would be
included in the plan. Although the council specifically does not calculate energy effciency targets for
specific utilities, the regional savings forecasts are typically allocated by share of regional
electricity load.
Idaho Power supplied comments to the council regarding the Draft 6th Plan in July 2009. In these
comments, Idaho Power stated that the proposed targets in the plan exceed the potential for achievable
energy savings in Idaho Power's service area and recommended a regional energy savings target that has
a higher likelihood of being attained be adopted.
On July 13, after discussions with the NPCC staff, Idaho Power agreed that a range of achievable energy
savings exists and that 1,100 aMW would be a reasonable lower threshold with an expected case of
1,200 aMW. Idaho Power also agreed that the Sixth Power Plan Action should include a "regional
check-in" with appropriate target adjustments after two years due to the uncertainty surrounding the
achievability of energy savings potential as laid out in the plan.
In November, Idaho Power submitted comments on the NPCC's Sixth Power Plan. Idaho Power's
comments included supporting the level of uncertainty that the Council included in its planning,
the inclusion of wind integration and transmission in the plan, and reinforced the comments of the
Pacific Northwest Utilities Conference Committee (PNUCC) regarding the depiction of future power
costs in the plan. Regarding energy effciency, Idaho Power commended the NPCC and its staff on
promoting aggressive steps toward energy effciency in the region and described Idaho Power's methods
Demand-Side Management 2009 Annual Report Page 3
Supplement 1 : Cost-Effectiveness Idaho Power Company
of encouraging energy efficiency and accounting for savings. The company expressed its concern that
some measures used to develop the regional potential might not be marketable or market ready in
Idaho Power's service area and that the plan includes energy savings based on behavioral attributes,
code changes, and market transformation in its energy savings targets. Idaho Power also pointed out the
uniqueness of each utility including Idaho Power in regards to their energy effciency methods and
alternative avoided cost of energy as compared to the NPCC.
Idaho Power specifically supports this section ofthe Sixth Power Plan Action Plan:
For this reason, the Council developed a range oflikely conservation savings over the first years
of 1,100 to 1,400 average megawatts. The Council wil monitor the actual conservation savings
acquired by the region by conducting reviews ofthe region's progress each year during the initial
five-year planning horizon ofthe Sixth Power Plan. More specifically, CONS 16, calls for a
midterm review of regional progress towards the regional conservation target. This wil permit
the Council to consider adjustments to its regional conservation target for the remainder of the
period covered by the Action Plan. In addition, the midterm review will assess the impact ofthe
region's progress on the acquisition of other resource development actions.
Idaho Power has a stated commitment to pursue all cost-effective energy effciency, even though
Idaho Powers methods of achieving its energy effciency targets may differ from those proposed by
the NPCC.
Page 4 Demand-Side Management 2009 Annual Report
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