20140822Hymas Direct.pdf

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BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE
APPLICATION OF ROCKY
MOUNTAIN POWER FOR
AUTHORITY TO CAI\CEL
ELECTRIC SERVICE SCHEDULES
tts,t2s,AND 155 AND REPLACE
WITH NEW SCHEDULE 140 WITH
CHAI\IGES.
CASE NO. PAC-E.14.08
Testimony of Kathryn C. Hymas
ROCKY MOUNTAIN POWER
CASE NO. PAC-E-14-08
August 2014
I Introduction
2 Q. Please state your name and business address.
3 A. My name is Kathryn C. Hymas, and my business address is 201 South Main,
4 Suite 2400, Salt Lake City, Utah 841 1 l.
5 Q. By whom are you employed and in what position?
6 A. I am currently employed as the Vice President of Rocky Mountain Power Finance
7 and Demand-Side Management ("DSM") for PacifiCorp dba Rocky Mountain
8 Power ("the Company").
9 Q. Please describe the responsibilities of your current position.
l0 A. I am responsible for demand-side management for Rocky Mountain Power and
I I for Pacific Power. This includes, the planning, development, design, approval and
12 implementation of programs designed to reduce energy consumption through
13 energy efficiency and behavioral changes and to reduce consumption during peak
14 periods of usage through load control. I am also responsible for finance functions
15 for Rocky Mountain Power.
l6 Qualifications
17 a. Please describe your background.
l8 A. I received a Master of Accountancy from Brigham Young University in 1979 and
19 a Bachelor of Science degree in Accounting from Brigham Young University in
20 1978. In addition to my formal education, I have also attended various
2l educational, professional, and electric industry-related seminars.
22 a. What is the purpose of your testimony?
23 A. The purpose of my testimony is to describe the proposed changes to the
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Company's energy efficiency programs for business customers and explain why
the Company is proposing these changes.
What is the purpose of the current programs and who is eligible to
participate?
Currently there are three programs for business customers: FinAnswer Express
(Schedule I l5), Energy FinAnswer (Schedule 125) and Irrigation Energy Savers
(Schedule 155). The programs are intended to maximize the efficient utilization of
the electricity requirements of new and existing loads in nonresidential facilities
through the installation of energy efficiency measures. Schedule l0 customers are
eligible for Irrigation Energy Savers (Schedule 155). Commercial and industrial
customers on Schedules 6, 6,4, 7, 7 A, 9, 12, 19, 23, 23A, 24,35, 35A and dairy
barns served under the Company's residential rate schedules are eligible for
Energy FinAnswer' lschedule 125) and FinAnswer Express (Schedule 115).
Overview of Business Customer Energy Efficiency Program Changes
a. Please provide a high level overview of the changes that you are proposing to
the business customer's energy efficiency programs.
A. The Company proposes that the following changes be made to the tariffs: (l)
consolidate the three non-residential energy efficiency programs into one new
program called wattsmart Business2 with changes and with a tariff similar to
Schedule ll5; (2) update incentive levels; (3) expand the program to include
energy management services and incentives; (4) update and expand the
prescriptive incentive offer; and (5) include a new offer for small businesses.
I Subject to a 20,000 minimum square footage requirement for existing commercial facilities.
' Schedule 140 is titled Non-Residential Energy Efficiency; the program name is wattsmart
Business.
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Please explain why the changes are proposed.
The changes are proposed to increase program participation; streamline program
delivery for the customer and the Company; increase the comprehensiveness of
the program to reach beyond a capital equipment focus; update the program to
align with current codes, standards, third party specifications and market data; and
increase small business customer participation.
These programs have been operating successfully for many years. As part
of continuous improvement, the Company has identified the following
improvement areas:
o Streamline the program for customers - Under the current structure,
customer projects may move from Energy FinAnswer to FinAnswer
Express (or vice versa) based on changes in project scope, timelines and/or
economics. This creates complexity for the customer that can impede
participation. By consolidating the programs into one program, there is no
need for the customer to sign new program paperwork in the event the
project scope evolves during the course of the project. Schedule l0
irrigation customers would be eligible for incentives listed in the
prescriptive incentive tables (e.g. green motor rewind measure). Also, by
consolidating the programs, customers with both irrigation and
commercial/industrial accounts would have a single energy efficiency
program for all oftheir non-residential accounts.
. Update incentives Updating incentives is expected to increase
participation whi le maintaining program cost-effectiveness.
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I o Expand the program to include energy management - The Company's
2 current program offerings in Idaho focus on capital based projects.
3 Expanding the program to include energy management, savings from
4 improved operations, maintenance and management practices would allow
5 customers lacking capital to participate.
6 o Update and expand the prescriptive incentives - The Company's current
7 program (FinAnswer Express) includes prescriptive offers where
8 incentives are paid for typical/common energy efficiency upgrades based
9 on unit counts such as $/lamp or $/horsepower. Prescriptive programs of
l0 this nature periodically require updates to maintain alignment with energy
I I code, standards, third party specifications and market data which change
12 over time. They also expanded periodically to include new measures ready
13 for a prescriptive/ streamlined approach. This filing in addition to
l4 consolidating the Company's current prescriptive program within the
l5 wattsmart business program will make those required changes.
16 o Add an offer specific to small business - The Company's current program
17 offerings can be improved to be more attractive to small business
l8 customers and increase participation by this hard-to-reach segment by
19 expanding program services and incentives specifically targeting these
20 customers.
2l Program consolidation
22 a. Please provide detail on the program consolidation changes.
23 A. The changes include several updates to the program structures and incentive
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levels in order to increase the acquisition of energy efficiency savings and to
streamline participation for customers. The proposed changes to the current
program structure and incentive levels are provided in Table l.
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able I - Summarv of C
Current program Proposed for
Schedule 140
Comments
Schedule 125 -
Energy
FinAnswer
Incentive:
$0.12lkWh +
$s0/kw
Incentive:
$0.15/kwh
Simplifu incentive for
customers. Increases total
incentive by an estimated
ZlYo and forecasted savings
by 7% when combined with
adjustment of project cost
caD-
Incentives capped at
50% of eligible
project costs
Increase cap to
70% of eligible
project costs
Customer pays for
commissioning
Program funds
Savings
Verification
Decreases customer
complexity and improves
controls related to
performance verifi cation.
Commercialand
Industrial have
different program
elieibilitv
Commercialand
Industrialhave
same program
elisibilitv
Simplify offer and expand
eligibility to increase
participation.
New Construction
Design Assistance
Discontinue
unique incentive
Low participation and offer
not moving the market.
Design Honorarium Discontinue
incentive
Low participation and offer
not moving the market.
Design Incentive Discontinue
incentive
Low participation and offer
not movins the market.
Minimum 20,000
SF of existing
commercial space to
be elisible
Remove
minimum space
requirement
Hard to quantify, removing
will simplifu delivery and
increase participation.
Custom incentives
available for listed
measures
Listed measures
paid at listed
amounts.
Simplify process so that the
incentive listed is always the
incentive paid. Allow
prescriptive and custom
measures to be included in
sinsle oroiect.
Schedule 115 -
FinAnswer
Express
Incentives capped at
50% of eligible
project costs for
lighting retrofits and
custom measures
Increase cap to
70% of eligible
project costs
Increases incentives for
participation.
Schedule 155 -
Irrigation
Energy Savers
Incentive:
$0.I2lkWh +
$s0/kw
Incentive:
$0.1s/kwh
Simpli! incentive for
customers. Increases
total incentive by an
estimated 27o/o and
forecasted savings by
TYowhen combined
with adjustment of
proiect cost caD.
Incentives capped at
50% of eligible
project costs
Increase captoT0Yo
of eligible project
costs
Schedule 140 -
New Offerings
in consolidated
tariff
nla Add energy project
manager co-funding.
$0.025/kWh of
program savings
See "energy project
manager" discussion
below
nla Expand offering to
include integration of
energy management
into business
practices. Incentive
of $0.02lkWh annual
enerqy savinqs.
Increases savings and
utilizes monitoring to
identify savings. See
"energy management'o
discussion below.
nla Use modification
procedure approved
in Order 32594 for
information
contained in Exhibit
No. 1 - Idaho
Incentive Tables and
Information
See "Flexible tariff'
discussion below.
I Energy Project Manager Co-funding
2 Q. What is energy project manager co-funding?
3 A. Energy Project Manager co-funding is designed to help customers pursue energy
4 opportunities more consistently and create a culture of energy efficiency at their
5 facilities by providing co-funding for a staff or contractor position to identify and
6 manage energy projects. Co-funding will be performance based and is contingent
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upon a customer's identification of and planning to meet a specific energy savings
goal3 over a prescribed timeframe; typically l2-18 months.
What savings count toward the customer's energy savings goal?
Only savings reported through Schedule 140 will count toward achieving the kWh
savings goal. If the customer meets these verified goals as outlined in a savings
plan, co-funding continues. If milestones and savings goals are missed, co-
funding will be suspended and/or terminated and repayment of unearned co-
funding will be required.
What is the anticipated role of the energy project manager?
The Energy Project Manager is to serve as the primary contact for implementation
of energy efficiency projects at a customer site. The Energy Project Manager will
be an employee or direct contractor of the customer and not an employee or
contractor of Rocky Mountain Power. The Energy Project Manager must be a
specific person and not a pool of labor without an individual role.
How is the energy project manager salary determined?
Subject to approval by the Company, it is the customer's choice regarding the
compensation paid to the Energy Project Manager and the co-funding cannot
exceed the lesser of(l) the pay and overhead for the assigned individual or (2) the
amount listed in Table I for completed projects. Documentation of pay and
overhead costs are required as part of the co-funding agreement. The Energy
Project Manager co-funding is based solely on electrical energy efficiency or
energy management savings.
t The Company will post the minimum energy savings goal on its website. The minimum may be
revised ifneeded.
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How are energy savings from projects receiving energy project manager co-
funding accounted for?
The Company assumed no additional savings would be directly attributable to the
addition of energy project manager co-funding in the analysis in Exhibit No. 2,
only the cost of the addition of co-funding was added. While the Company
believes the availability of co-funding will increase project activity and add to
program savings over time, the Company utilized the most conservative
assumption in this analysis to eliminate the possibility of double counting energy
savings.
Energy management
a. What is energy management?
A. Energy Management is a system of practices that creates reliable and persistent
electric energy savings through improved operations and maintenance, and
management practices at customer sites. Unlike typical energy efficiency projects,
energy management projects may require little to no capital investment by
customers to achieve sustainable savings at their facilities.
What is the Energy Management offering?
The Energy Management offering is designed to complement program offerings
for capital improvements and the new Energy Project Manager co-funding.
Designed with the customer in mind, Energy Management will offer multiple
levels of engagement: Strategic Energy Management, Persistent Commissioning,
Industrial Re-commissioning, and Re-commissioning. The level of engagement
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will be in direct response to the customer's specific needs and their commitment
to a process that can extend from 12-24 months.
The Energy Management offering provides a systematic approach to integrating
energy management into an organizations business practices. Monitoring of
building systems and industrial process controls is used to identify and quantifu
energy savings.
What is the estimated savings per customer through energy management?
The Company has identified an average potential of three percent energy savings
per customer site (with usage of at least 500,000 kWh) through improved energy
management practices. Measurement of savings is site and process specific,
generally consisting of the establishment of an operational baseline and savings
measurements through either continuous monitoring of operational data, or at
specific intervals during the Company's energy management engagement with the
customer.
What is the assumed measure life for energy management?
The incentive level and program design was modeled with a savings persistence
of three years in recognition of the nature of how the savings are derived i.e. from
changes in operational, maintenance, and management practices as opposed to
less variable capital improvements.
How did the Company ensure energy management savings were
differentiated from capital project savings?
The energy management savings assumption included in this application is based
on a third party assessment of energy management opportunities for each state
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where the Company is responsible for delivering programs. The assessment
specifically separated energy management savings from capital equipment project
savings to ensure savings are not double within the Company's projections and
economic assessment provided as Exhibit No. 2.
Flexible tariff
a.
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What is the structure for the proposed Schedule 140 program and tariff?
Schedule 140 will utilize the modification procedure established with the approval
of Case No. PAC-E-12-09 by the Idaho Public Utilities Commission for Schedule
r 15.
How did the Company describe the program change process in Case No.
PAC-E-12-094?
The Company stated:
"future changes to Program detailss will be managed as follows:o Similar to the filing process, the Company will provide information on
any proposed changes to Program details to Commission staff and
allow for a reasonable period of time for staff to comment on the
proposed changes.o Once Commission staff comments, if any, are resolved the final set of
changes will be clearly posted on the website with at least 45 days
advance notice.o After the 45 day noticing period the changes would then be in effect."
What are the components of Schedule 140?
If approved, Schedule 140 will consist of the tariff (Exhibit No. 4) that contains
general information on the program with more detailed program specifics such as
qualifying equipment and incentives posted to the Company website. The
information proposed to be posted to the website is provided in Exhibit No. l:
o The flow chart documenting the process is provided as Exhibit No. 3 to this application.t Program details are provided in Exhibit No. I to this application.
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1 Idaho Incentive Tables and Information. Subsequent changes to this information
2 will follow the program change process described above.
3 Update and Expand the Prescriptive Incentive Offer
4 a. What is the purpose of the updates to the prescriptive offer?
5 A. The changes are intended to align the program with changes to codes, standards,
6 third party specifications and new market data and increase the
7 comprehensiveness of the program while maintaining or improving cost
8 effectiveness.
9 Q. What is the scope of the updates to the prescriptive offer?
l0 A. The proposed changes include updates for existing measures currently in
ll FinAnswer Express (Schedule ll5) incentive tables as well as to add new
12 measures. Further details on the proposed changes to the prescriptive offer are
13 included as Exhibit No. 5 to this filing.
14 a. How were the changes identified?
15 A. The changes were informed by a review of applicable codes and standards, third
16 party specifications such as Consortium for Energy Efficiency ("CEE") and
17 ENERGY STAR, past program participation, and vendor feedback. This type of
18 review is completed on a periodic basis to keep existing program measures
19 current and to add new measures as appropriate in order to maintain program
20 relevancy and overall comprehensiveness. The last comprehensive review
2l informed program changes to Schedule I 15 (FinAnswer Express) that were
22 approved effective July 14,2012.
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Impact of Codes and Standards
a. When did the Company adjust the baseline for linear fluorescent lighting
retrofits?
On January 1,2014, the Company adjusted the baseline for fluorescent lighting
retrofits from an energy saving T12 lamp and energy efficient magnetic ballast
configuration to a 32W T8 lamp and electronic ballast configuration.
Why was the lighting baseline change made and was it included in the cost-
effectiveness analysis?
The lighting baseline change was made to maintain alignment with changes in
federal lighting equipment efficacy standards. These types of baseline adjustments
help ensure the Company does not pay more than is necessary when helping
facilitate customer lighting improvements. The lighting baseline change does not
remove incentives for lighting system retrofits, but does change the baseline usage
assumption from which program savings and incentives are calculated. The
change is incorporated into the cost-effectiveness analysis provided in Exhibit No.
2 as an increase in the utility cost of savings acquisition when compared to prior
years.
New Offer for Small Businesses
a. What is the small business offer?
A. The small business offer is aligned with a best-practice approach used by many
other utilities (listed in Table 2, below) utilizing a pool of Company-approved and
managed contractors to work directly with small/medium business customers to
identify energy-efficiency upgrades, estimate savings and incentives, and install
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high-efficiency equipment. Participating customers utilizing an approved
contractor will be eligible for an enhanced incentive offer targeted at 80 percent
of the project cost. To reduce the customer's out-of-pocket expenses and
minimize cash flow impacts, the customer can assign the incentive to the
contractor who will then apply it as an up-front reduction to the overall project
invoice/cost. Participating contractors will complete and submit the required
incentive application and documentation to the Company for payment of the
incentive amount that was assigned to them by the customer. Further details on
the small business offer are included as Exhibit 6 to this filing.
Table 2 - Similar Offers from Other Utilities
MEH,.Right Lights Small and Mid-Sized
Business
O+Express Solutions Demand < 100 kW +
schools
-islEaoJIF Business Solutions Small
Business Program
< 145,000 kwh/yr
H
Snison
Small Business Direct lnstall
Lighting Program
< 350 kW
Direct lnstall Small and Mid-Sized
Business
!mro Complete Energy Solutions Up to 299 kW / mo
nationalgridDIFEdB{r\'
Small Business Services
program
s300kW / month
3rm Small Business Energy
Advantage
Avg peak demand l0
kw - 200 kw
e xri-Small Business Energy
Solutions
< 200 kW / month
ffi Smart Energy Savers <60 kW / mo
@ xaenugy Small Business Lighting < 400 Kw
What customers are eligible for the small business offer?
Customers receiving electric service in Idaho on Rate Schedule 23 &23A.
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I Q. Are there other eligibility criteria for the small business offer?
2 A. Additional eligibility criteria may be added (e.g. square footage, operating hours,
3 kwh usage) to align with savings targets, incentive budgets, and cost
4 effectiveness requirements and will be posted on the Company website.
5 Q. What measures will be included in the offer initially?
6 A. Initially, the measure list will be focused on high-efficacy fluorescent lighting
7 technologies, occupancy controls, and LED recessed downlights and exit signs.
8 These measures are most frequently found in small/medium businesses, as shown
9 in Table 3 in Exhibit No. 6. Measures not included in the small business customer
l0 incentive table will be incentivized at the standard incentive rates offered for
l1 those measures in the wattsmart business program.
12 a. How much are the incentives be determined and controlled?
13 A. The Company is proposing to define the incentives for this offer on a measure-
14 specific basis targeted to cover 80 percent of the customer cost. Incentives will be
l5 capped at 80 percent to ensure a minimum customer "co-pay" of 20 percent.
16 a. How will the incentives be set?
17 A. Incentives will initially be determined relative to market costs collected from the
l8 contractor application process used to select and approve contractors and will not
l9 exceed the maximum incentive values in Schedule 140. The incentive table will
20 be posted on the Company's website.
21 Transition from Current Programs to Wattsmart Business
22 a. How will the Company transition projects currently in progress?
23 A. In the event the Commission approves the Company's request, customers with
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I Incentive Agreements issued between the date of this filing and the effective date
2 approved by the Commission will receive final project incentive(s) under the new
3 tariff unless their project would have received a higher incentive amount under
4 the existing version of the program. Customers with Incentive Agreements in
5 place priorto this filing will receive incentives consistent with the version of the
6 program at the time the agreement was issued.
7 Q. Are there any other changes proposed?
8 A. In addition to the changes I have outlined, the Company is proposing other minor
9 administrative changes to language.
l0 Cost-Effectiveness
I I O. How was cost effectiveness assessed?
l2 A. The Company utilized the five standard tests for economic analysis of demand
13 side management measure /programs. These tests are the same ones used by the
14 Company in prior program filings and annual performance reporting. Using the
15 standard tests, the impacts of the proposed changes were assessed in a series of
16 steps described below. The first step was to develop a forecast of expected
17 participation, savings, and costs absent any program changes from all three ofthe
18 current business programs. This same look is provided in the Company's annual
19 reports as the Commercial and Industrial Portfolio and forms the "business-as-
20 usual" case. The business-as-usual case covers three years: 2015-2017 and
21 utilizes net-to-gross, realization rates, and measure life values utilized in or
22 derived from the values used in the 2013 Idaho annual report. The next step was
23 to assess the cost-effectiveness of each of the proposed program changes or new
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measures in cases where the changes or additions were likely to have a material
impact on program cost-effectiveness. Inputs for measure costs, measure life,
realization rates, and net-to-gross ratio are specific to each of the measures. The
impacts of changes or new measures were also assessed over three years to align
with the business-as-usual case. The final step in the assessment was to add the
benefits and costs of each change to the benefits and costs of the business-as-
usual case. This provides a before and after comparison of the aggregate impact of
the changes as well as illustrating the likely contribution from each of the
changes. Results are provided by individual year and for all three years combined
in Exhibit No. 2.
What discount rates did the company use for the cost effectiveness analysis?
The Company utilized the Weighted Average Cost of Capital ("WACC") as the
discount rate for the five standard tests. This approach is consistent with prior
Company reporting and the Company understands it is consistent with Avista
Corporation's approach in ldaho. The Company understands this is slightly
different than Idaho Power which derives a different rate for the Participant Cost
Test ("PCT"). The Company also reviewed Appendix N of the 6th Power Plan
which documents underlying derivations used to arrive at the 6th Power Plan
discount rate. While Appendix N uses October 2009 data it did provide a useful
context and data source to compare to the Company's rate. The Capital Asset
Pricing Model used in Department of Energy calculations is considered a good
proxy for business customer investment decisions and the rate ranges from 7.3
percent to 7.5 percent. Since this application assesses the economics of changes to
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a business customer program and the Department of Energy ("DOE") rate is close
to the Company's WACC rate of 6.88 percent, the Company chose to utilize the
WACC rate for alltests for this application.
Are all the new measures or additions costs effective?
Ten of the thirteen new measures or changes are cost effective from the
PacifiCorp Total Resource Cost ("PTRC"), Total Resource Costs ("TRC") and
Utility Cost Test ("UCT") perspectives on a standalone basis. Two of the
changes; both tied to increasing incentives, do not pass the UCT on a standalone
basis. These results are more indicative of the challenges in modeling the cost
effectiveness of those changes rather than their possible contribution to program
performance. Increasing the incentive is forecasted to generate additional savings,
however, the increased incentives has to be paid to all participants, not just the
ones who generate added savings. Since the increased incentives is available to all
participants, the utility costs of this measure include incentives paid to
participants whose savings are already reflected in the business-as-usual case. As
a consequence, the increased incentive costs for this measure are
disproportionately higher than the incremental savings and results in a UCT less
than 1.0. The Energy Management offer passes the UCT, but not the PTRC or
TRC. These results are driven primarily by some uncertainty surrounding
customer costs for implementation. Individual results for each change or measure
are provided in Exhibit No. 2.
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Is the new program, (the combination of business as usual case and all the
changes) cost-effective?
Yes, see the cost-effectiveness analysis in Exhibit No. 2 supporting my testimony.
The cost effectiveness of the new program includes the impacts of adding the
three non-cost effective measures, ten measures that are cost effective on a stand-
alone basis and the additional program portfolio costs for energy project manager
co-funding.
Does this conclude your testimony?
Yes.
a.
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Case No. PAC-E-14-08
Exhibit No. I
Witness: Kathryn C. Hymas
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Testimony of Kathryn C. Hymas
Idaho Incentive Tables with Changes Marked
August 2014
Rocky Mountain Power
Exhibit No. 1 Page 1 of 30
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Exhibit I
ldaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Rocky Mountain Power
Exhibit No. 1 Page 2 of 30
Case No. PAC-E-14-08
\Mtness: Kathryn C. Hymas
Idaho @on-Residential Enerw Efficiencv
This document includes the following three sections:o Definitions of terms used in Schedule ll*l,p and other program documentso Incentives - General Informationo Incentive tables
DEFINITIONS:
Customer: Any party who has applied for, been accepted and receives service at the real
property, or is the electricity user at the real property.
Energy Efficiency Incentive: Payments of money made by Company to Owner or Customer forinstallationofanEnergyEfficiencyMeasurepursuanttoan@Energy
Efficiency Incentive @or approved Energy Efficiency Incentive
Application.
Energy Efficiency Incentive : An trgfe€m€nt
@ Company and acknowledged by Owner or Customer and4ennpanye+a
eemparyprovidingforCompanytofurnishEnergyEfficiencyIncentives@
.
Incentive Application: An application submiffed by Owner or Customer to Compan), for
Energv Efliciencv or Enerpy Management Incentives.
Energy Efficiency Measure (EEM): A permanently installed measure which can improve the
efficiency of the Customer's electric energy use.
Energy Efficiency Measure (EEM) Cost:
New Construction/Major Renovation: EEM Cost is the total installed cost of energy efficiency
equipment or system minus the cost of the code compliance/common practice equipment or
system.
Retrofit: EEM Cost is the total installed cost of the energy efficiency equipment or modification.
In the case of New Construction, Major Renovation and Retrofits, EEM Costs shall mean the
Owner or Customer's reasonable costs incurred (net of any discounts, rebates or incentives other
than Energy Efficiency Incentives from the Company, or other consideration that reduces the
final actual EEM Cost incurred by the Owner or Customer) to purchase and install EEMs at the
Owner's or Customer's facility. If the owner or customer installs the EEM then the cost of
installation shall be equal to the Owner's or Customer's actual labor costs for such installation.
ldaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page 2 o1
Rocky Mountain Power
Exhibit No. 1 Page 3 of 30
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Energy Efficiency Project: One or more EEM(s) at a Non-residential Facilityr with similar one
year payback limitations (below) covered by one Energy Efficiency Incentive lgreementOffef
Letter.
Energy Efficiency Project Cost: The sum of EEM Costs for one or more EEM(s) with similar
one year payback limitations (see below) covered by one Energy Efficiency Incentive
@.
Energ.y Manaeement Offer Letter: An offer made by Comoany and acknowledeed bv Owner
or Customer and Company oroviding for Company to furnish Energy Management Incentives for
an Energy Management Project.
Eners.v Manaeement Incentive: Pavments of money made by Company to Owner or Customer
for implementation of an Enerq.v Management Measure oursuant to an executed Energlv
Management Offer Letter.
Enerw Manasement Measure (EMM): an operational imorovement which. when
implemented in an eligible facilitv. result in electric savings compared to current operations as
determined b), Company.
Enerqv Manasement Proiect: One or more EMM(s) at a Non-residential FaciliW covered by
one Enersv Manasement Offer Letter.
Enerqv Proiect Manaser: an emplovee or direct contractor of the Customer who will manage
electrical eners.v efficiency projgcts that deliver savings toward the Customer/Owner's enerry
savings goal.
Enerqv Proiect Manaser Co-fundins: funding towards the Enerev Proiect Manaeer asreed
upon full value salary that is solely attributable to electrical energy efficiency work.
iF+
Major Renovation: A change in facility use type or where the existing system will not meet
Owner/Customer projected requirements within existing facility square footage.
Mixed Use: Buildings served by a residential rate schedule and a rate schedule listed under
ApplicableinIdahoSchedulel40shallbeeligibleforservicesunder@
provided the Energy Efficiency Project meets the definition of New Construction or where the
Company adjusts the baseline energy consumption and costs.
New construction: A newly constructed facility or newly constructed square footage added to
an existing facility.
I Measures at multiole Non-residential Facilities mav be included in one Offer Letter for convenience: however.
oroject incentive caps (if any) are applied per individual Non-residential Faciliw.
Idaho wattsmart Business (Schedule I 40) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page 3 o1
Rocky Mountain Power
Exhibit No. 'l Page 4 of 30
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Owner: The person who has both legal and beneficial title to the real property, and is the
mortgager under a duly recorded mortgage of real property, the trustor under a duly recorded
deed of trust.
Retrofit: Changes, modifications or additions to systems or equipment in existing facility square
footage.
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page 4 o1
Rocky Mountain Power
Exhibit No. 1 Page 5 of 30
Case No. PAC-E-14-08
\Mtness: Kathryn C. Hymas
INCENTIVES - GENERAL INFORMATION
Incentives for Measures Listed in the Incentive Tables
Per unit incentives are listed in the program incentives tables for specific Energy Efficiency
Measures (EEMs) and are subject to the incentive caps below. Incentives are subject to change
and current incentives can be found on the ldaho energy efficiency program section of the
Company website.
Custom Incentives
EEMs not listed in the prescriotive incentive tables (tvpical upgrades) may be eligible for a
eus+emAstom Energy Efficiency Incentive. The Company will complete an analysis of the
EEM Cost and electric energy savings and determine whether to offer a custom Energy
EfficiencyIncentiveandtheEnergyEfficiencyIncentiveamount.@
en€rgy+a+i
etectrlc savinss res
an gnersv Efficiencv
Enerw management incentives
Non-Capital. improvements to operations and maintenance within a qualiffing facility may be
eligible for an Energy Management Incentive. Company will partner with Customer to complete
an analysis of the electric enerKv savings of potential energy management measures and
determine whether to offer an Energ.v Management Incentive and the incentive amount.
Enersv proiect manaser co-funding
The Company ma), fund an additional $0.025 per kWh of verified wattsmart Business annual
energy savinss. up to 100 percent of the Energy Project Manaeer's salarv. Salary is based on a
letter from the Customer/Owner's human resources or accounting department stating the base
annual salary and an aopropriate overhead percentage. and subject to approval by Company.
Baseline adjustments
fhe basetine wattaqe
thelesserof
a) Wattaqe of existins
b) Wattase of deemed ba
available on the ldah
Comoanv mav aOiust
use and eouipment iug
energv efficiencv mea
enersv cnde rlnes nnt annlv
ldaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective luly 14,2012
Page 5 o1
Rocky Mountain Power
Exhibit No. 1 Page 6 of 30
Case No. PAC-E-I4-08
Vvitness: Kathryn C. Hymas
2 The Customer or Owner may receive onl), one financial incentive from Company per measure. Financial incentives
include energy efficiency incentive payments and enersy manasement payments. Enersy Project Manaser Co-
atordper-
s The I year simple payback cap means incentives will not be available to reduce the simple pavback of a project
below one year. If reouired. individual measure incentives will be adjusted downward pro-rata so the proiect has a
simple payback after incentives of one year.
6 Project Cost and l-Year Simple Payback Caps do not appl), to New Construction and Major Renovation proiects
that are subject to state energy code.
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective luly 14,2012
Incentive +ereemmOffer. Al ing-an
enersv Efficiencv lnc
,d\pplication. Compa
INCENTIVES:2.3
Catesorv Incentive Percent Proiect
Cost Caoa
l-Year Simple
Powlronlr (-on fn
Other
Limitations
Proiects
Prescriotive
Incentives
(Typical
Upgrades)
Lishtine - Retrofit
See incentive lists
70o/o Yes
See incentive lists
Liehtine -
New Construction/
Maior Renovation
None No
Motors None No
HVAC None No
Buildine Envelooe None No
Food Service None No
Apoliances None No
Office None No
Farm and Dairy 70o/o Yes
Compressed Air 70%Yes
Wastewater and other
Refriseration
70o/o Yes
Enhanced Incentives for Small
Businesses
Determined by
Compan), with not-
to-exceed amounts
as shown in Table
t2
80o/o No Available to all
Schedule 23 and
23A customers
meetine small
business criteria
on Company
website.
Oualiftine
.nrrinment mrrcl hr
installed b), an
approved
:ontractor/vendor
Custom Non-Lishtine Incentives for
oualiftine measures not on the
orescriotive list-6
$0.15 per annual
kWh savinss
70o/o Yes N/A
Enersv Manasement $0.02 per kWh N/A No N/A
Rocky Mountain Power
Exhibit No. 1 Page 7 of 30
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
I The I year simple paybask eep means EnergfEffieieney Ineentives rvill net be available te reduee the simple
iy€s
rvill be ^4iusteC dewnrvarC pre rata se the Energy Bffieieney Prqieet has a simplepayboek after ineen+ives ef ene
)€af€f-mefe:
;en
M
ffi
ives
fteetrie sni'inB
@il'le=
ire
7 Customers mav aggregate accounts to achieve minimum requirements.
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective luly 14,2012
neeasu+eea*ego+y
@W
ee:o
@@
Proi€€ts+
tiehtiae#t w Yos
j€+
Renravatiea
N€flo Ne
Moters None Alo
HVAE AI6ao Lb
B'rii.ldinp.Er+rr€]€ne II€ne Lle
Fee*Seryiee Llene Ab
Asolianees ll€no Ne
effiee}AIes€Llo
aoelisn€€e Llene lle
E)airv/Ferm Eeuinment N€ne Ne
€emprxsed-{i+Lbne Ne
@ivinft
eus+em{neen+ir*e
None No
Ineen+ive
5M Y€s
Page 7 o1
Rocky Mountain Power
Exhibit No. 1 Page 8 of 30
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
@
is
the.lcs€€{.€f
c)
d)
m€rl+eqpi
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
ncentives for retrofits
Measure Catesorv Elisibilitv Requirements Incentive
T8 Fluorescent
Premium CEE
T8
4' CEE Oualified Hieh Performanc€ Lamp and CEE
Oualified Ballast included on qualified list4:€EE
list
$73/Lamp
4' CEE Oualified Reduced Wattase Lamo and CEE
Oualified Ballas included on oualified list $5/Lamo
Premium
Delamp
4' CEE Qualified Reduced Wattage or High Performance
Lamp and CEE Qualified Ballast. Must remove one or
more lamps. To delamp en*gn existing fixture, the lamp
and all corresponding sockets must be permanently
disabled.
$2|ll-amp Removed
Relamp Lamp wattage reduction > 3 Wafts, No ballast retrofit $&35!Lamp
High Bay
Fixture with less than six (6) lamps:
4'CEE Oualified Hieh Perfonnanc.e Lamp.
Must rcplac€ Tl2HOny'HO. Incandesc€nt or HID.4'€E
Iaeaadeseex*+#D
$2elE/Lamp
Fixture with six (6) or more lamps:
4'CEE Oualified Hieh Performance Lamp.
Must reolace TI2HO/VHO- Incandescent or HID
$12ll-amo
Continuous
Operation
4' CEE Qualified Reduced Wattage or High Performance
Lamp and CEE Qualified Ballast included on qualified
bdlas#list installed in a continuous operation application
$2OlLamp
T5 Fluorescent
Standard 4' Nominal Lamp < 28 Watts, Ballast Factor < 1.0 $5/Lamp
Relamp Lamp waffage reduction > 3 Watts, No ballast retrofit $0*51/Lamo
High Bay
Fixture with less than six (6) lamos: 4' T5HO Lamo.
Must reolace TI2HOAy'HO. Incandescent or HID.4
Nmiml High OrrtnrtLnm
$2elE/Lamp
Fixture with six (6) or more lamps: 4' T5HO Lamp.
Must renlace Tt 2HOlVt{O- Incandescent or fIIfF.$12ll-amo
Continuous
Operation
4'Nominal High Output Lamp installed in a continuous
operation application $2OlLamp
Cold Cathode Screw-in Lamp All wattages $5/Lamp
Compact
Fluorescent
Lamp (CFL)
Sere*in-l,amp +Urra*ag€s{S€€+l€+e+)$2+ame
Hardwired
Fixture All wattages $5/Fixture
Ceramic Metal
Halide (CMH)CMH Fixture All wattageg $35/Fixture
Pulse Start
Metal Halide
(PSMH)
PSMH Fixture Wattases > 500W $60/Fixture
Electronic
Ballast Must be used in place of or replace a magnetic ballasl $20lBallast
lnduction Induction
Fixture All wattages, New fixtures only $l?575lFixture
LED
Integral Screw-
in Lamo LED must be listed on qualified equipment list $10/Lamp
Recessed
Downlisht LED must be listed on qualified equipment list $10/Fixture
eu*CeerArea
ond
*soa*ayOtnet
LED
LED must be listed on qualified equipment list
$0.15/kWh annual
enerqY
savines$100,1kr€
Rocky Mountain Power
Exhibit No. 1 Page I of 30
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page 9 o1
Rocky Mountain Power
Exhibit No. 1 Page 10 of 30
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Pa*ing€arage $+00lFixure
+tigh{adJ,erv
Esr.$JeelFi*erre
Lichting Custom Not listed above $0.15&Wh annual
energv savinss
Notes for lighting retrofit incentives:
l. To be eligible for the incentives listed, the new lighting system must use less energy than the
existing lighting system replaced or the baseline lighting system as determined by the Company.L2. Incentives are capped
available to reduce the Energy Efliciency Project simple payback below one year. Enerey
Efficiency Project Costs are subject to Comoany approval
.
.
4. Incentives for T8 Premium Delamps may not be combined with other linear fluorescent
or fixture incentives. Complete fixture removals are not eligible.5. Incentives for T8 and T5 Fluorescent Relamps may not be combined with other
fluorescent lamp or fixture incentives and will only be paid once per facility.
6. Qualified equipment lists referenced in the table are posted on the ldaho energy efficiency
program section of the Company's website.
7, The ineentive fer Serc
BF : Ballast Factor
CEE: Consortium for Energy Efficiency
CFL: Compact Fluorescent Lamp
CMH: Ceramic Metal Halide
HID: High Intensity Discharge (e.9. Mercury Vapor, High Pressure Sodium, Metal Halide)
HO = High Output
LED = Light-Emitting Diode
PSMH = Pulse-Start Metal Halide
VHO = Very High Output
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
lamp
linear
Page 10 r
Measure Category Elipibilifv Reouirements Incentive
Lighting
Control
Occupancy Control PIR, Dual Tech, or Integral Sensor
$-0.30/Watt
conholledT5lSense
f
Daylighting Control
Must contol interior fxtures with Continuous. Steooed or
Bi-level ballast or automated control that dims 50%o or
mor€ of the fixtuE in rcsponse to daylight.Iffi
thet dirne 509'o er mele ef the fxere in respense te
de+tigh*
$0.3,UWatt
controlledT5lSense
f
Advanced Daylighting
Control
Must incorporate both an occupancy sensor and daylighting
sensor operating as part ofthe same control sequence in the
same interior space.
$O38/Watt
controlled*50
Simfiing+ollas*ing
€ontref
$+#Bellast
Non-General
Illuminance
Exit Sign LED or photoluminescent replacing incandescent or
fluorescent $ I 5/Sien
LED Message Center
Sign LED replacing existing incandescent signage
$S/Lamo
LED Channel Letter
Sign LED replacing existing neon or fluorescent signage
$5/Linear Foot
LED Marquee/Cabinet
Sisn LED replacing existing fluorescent signage $5/Linear Foot
Liqhtins Custom Not listed above $0.15/kWh annual
enerov savings
Rocky Mountain Power
Exhibit No. 1 Page 1'l of 30
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Incentives for lighting controls and non-general illuminance (retrofit only)
Notes for retrofit lighting controls and non-general illuminance incentives
l. To be eligible for the incentives listed, the new lighting system must use less energy than the existing
lighting system replaced or the baseline lighting system as determined by the Company.
2. Incentives axe capped at S$ppercent of Energy Efficiency Project Costs and incentives will not be
available to reduce the Energy Efficiency Project simple payback below one year._E3gIgy-Effic.ien9y
Project Costs are subject to Company approval.
3. Incentives for Advanced Daylighting Controls may not be combined with other occupancy control or
daylighting control incentives.
4. Watt controlled refers to the total wattaee of liCfiting fixtures down circuit from the control.
PIR: Passive Infrared
Dual Tech : Sensors combining ultrasonic and passive infrared
LED : Light-emitting Diode
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the cunent FinAnswer Express program which was effective July 14,2012
Page ll r
lncentives for new construction/ma ior renovation
Measure Category Elisibilitv Reouirements Incentive
lnterior Lighting Lighting and Lighting
Control
l. The total connected interior lighting power for New
Constructior/Major Renovation projects must be at
least l0% lower than the interior lighting power
allowance calculated under the applicable version of
the state energy code. For New Construction/Major
Renovation projects not included in the state energy
code, the total connected lighting power must be I 0olo
lower than common practice as determined by the
Company.
2. Energy savings is subject to approval by the
Comoanv.
$0.08/kwh
annual energy
savings
Exterior Lighting
Induction Fixture All Wattages, New Fixtures Only $Jl5Effixture
LED Outdoor
Pole/Roadway.
decorativel,E]OntCeer
A*ee*nd*oadrva+
<75W: LED must be listed on qualified fi*firre
equipment list $Je0Effixture
A'.+,I^ar Dala/Dnazl
S200W: LED must be listed on oualified eouioment list $100/fixture
>200W: LED must be listed on oualified eouioment list $400/fixture
LED Canopv/Soffit LED must be listed on qualified equioment list $125/fixture
LED Wall Packs
<50 Watts: LED must be listed on oualified eouioment
list $50/fxtwe
>50 Watts: LED must be listed on qualified equioment
list $75lfixture
LED Flood Liehts
<luu watts: LEL, must be llsted on oualllled
earrinment lisf $75lfxture
2100 Watts: LED must be listed on oualified
eouioment list $150/fxture
CFL Wall Pack All Wattages, Hardwire Fixtures Only $3O/Fixture
Lighting Control
Occupancv control which must conhol a linear
fluorescent. induction. or LED lxturelategrd
fluereseenE hrduetien; er tED fxture, Seneor must be
ffi
$O3OAUafi
controlled
75ls€i{€r
Custom Not listed above
s0.08/kwh
annual energy
savinss
Rocky Mountain Power
Exhibit No. 1 Page 12 of 30
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
CFL = Compact Fluorescent Lamp
LED = LightEmitting Diode
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective JuJy 14,2012
Page 12 r
Incentives for Motors
Eouinment TYoe Size Categorv Sub-Category
Minimum Efficiency
Reouirement
Customer
Incentive
Electronically
Commutated Motor < I horsepower
Refrigeration
aoolication $0.50/watt
HVAC aoolication $50/horsepower
Variable-Frequency
Drives
(HVAC fans and
oumos)
< 100 horsepower HVAC fans and
pumps See Note 2 $65/horsepower
Green Motor Rewinds > l5 and < 5,000 hp Must meet GMPG
Standards
$ l/horsepower
Refer to Note 3
Rocky Mountain Power
Exhibit No. 1 Page 13 of 30
Case No. PAC-E-14-08
Vvilness: Kathryn C. Hymas
Notes for motor incentives:
l. Equipment that meets or exceeds the efficiency requirements listed for the equipment
category in the above table may qualiry for the listed incentive.
2. Throttling or bypass devices, such as inlet vanes, bypass dampers, three-way valves, or
throttling valves must be removed or perrnanently disabled to qualify for HVAC fan or pump
VFD incentives. VFDs required by or used to comply with the applicable version of the Idaho
energy code are not eligible for incentives. Savings will only be realized for installations where
a variable load is present.
3. For Green Motor Rewinds, the participating electric motor service center is paid
$2/horsepower for eligible Green Motor Rewinds. A minimum of $llhorsepower is paid by the
service center to the Customer as a credit on the motor rewind invoice. The balance is retained
by the service center. Green Motor Rewind motors that are installed or placed in inventory may
qualifu for an incentive.
l, Ineentives are net evaileble ferNetienel Eleetrieel Menufaeturers rtsseeietien (NEMr\)
ECM = Electronically Commutated Motor
GMPG: Green Motors Practices Group
HVAC : Heating, Ventilation and Air-Conditioning
lftrtktn
VFD = Variable-Frequency Drive
ldaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page 13 r
Rocky Mountain Power
Exhibit No. 1 Page 14 of 30
Case No. PAC-E-14-08
Vvilness: Kathryn C. Hymas
Incentives for HVAC equipment
Minimum Efficiency Requirement & Customer
fncenliwe
Eouioment Tvne Size Catcsorv Sub-Catesorv $25/ton $50/ton $75/ton
Unitary Commercial
Air Conditioners, Air-
Cooled (€eeling*4ede)
< 65,000 Btu/hr
(single phase)
Split system and
single package
CEE Tier I CEE Tier 2All equipment sizes
(three phase)
Split system and
single package
Unitary Commercial
Air Conditioners, Water
and Evaporatively'
Cooled
All equipment sizes Split system and
single package CEE Tier I
Packaged Terminal Air
Conditioners (PTAC)(I@€€oting
[4ode)
S 8,000 Btu/-hr Single package I2.2 EER
> 8,000 Btu/hr and
< 10,500 Btu/hr Single package I I.9 EER
> 10,500 Bhr/k and
< 13,500 Btu/hr Single package IO.7 EER
> 13,500 Bhr/hr Single package 9.9 EER
Packaged Terminal
Heat Pumps
(PTHP)
(Heating & Cooling
Mode)
< 8,000 Btu/hr Single package 12.2 EER and
3.4 COP
> 8,000 Btu/hr and
< I0,500 Btu/hr Single package I 1.5 EER and
3.3 COP
Z 10,500 Btu/hr and
< 13,500 Btu/hr Single package 10.7 EER and
3.r coP
> 13,500 Btr/hr Single package 9.8 EER and
3.0 coP
Heat Pumps, Air-
Cooled
(Cooling Mode)
< 65,000 Btulhr
(single & three
nhase)
Split system and
single package CEE Tier I CEE Tier 2
> 65,000 Btr:/hr
(three phase)
Split system and
single package CEE Tier I
Heat Pumps, Air-
Cooled
(Heating Mode) - See
Note 3
< 65,000 Bh:/hr
(single & three
nhase)
Split system and
single package
CEE Tier I
CEE Tier 2
> 65,000 Btu/hr
(three phase)
47'F db/43'F wb
outdoor air
I 7"F db/l 5'F wb
outdoor air
Heat Pumps, Water-
Source
(Cooling Mode)
< 135,000 Btr/hr 86oF Entering
Water CEE Tier I
Heat Pumps, Water-
Source
(Heating Mode) - See
Note 3
< 135,000 Btu/hr 68oF Entering
Water CEE Tier I
VRF Air-Cooled Heat
Pumps
(Cooline Mode)
All Equipment Sizes
Multisplit System
or Multisplit
Svstem with Heat
Recoverv
CEE Tier I
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page 14 r
Rocky Mountain Power
Exhibit No. 'l Page 15 of 30
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
VRF Air-Cooled Heat
Pumos
(Heatine Mode)
See Note 3
All Eouioment Sizes
Multisolit Svstem
or Multisolit
Svstem with Heat
Recovery
(See note 3)
CEE Tier I
VRF Warcr-Cooled
Heat Pumns
(Coolinc Mode)
< 135.000 Btu/hr
Multisplit System
or Multisolit
System with Heat
Recoverv
CEE Tier I
VRF Water-Cooled
Heat Pumos
(Heating Mode)
See Note 3
< 135.000 Btu/hr
Multisplit System
or Multisplit
System with Heat
Recoverv
/See noie 1\
CEE Tier I
Heat Pumps, Ground-
Source or Groundwater-
Source
(Heating & Cooling
Mode) - See Note 3
All sizes 77"F Entering
Water
ENERGY
STAR
Qualified
Ground-Source or
Groundwater-Source
Heat Pump Loop
All sizes $25lton
Notes for HVAC incentives:l. Equipment that meets or exceeds the efficiency requirements listed for the size category in the
above table may qualify for the listed incentive. Equipment must meet all listed efficiency
requirements to qualify for the listed incentives.
2. PTHPs can replace electric resistive heating, which must be removed.
3. Incentives for heat pumps are available per ton of cooling capacity ONLY. No incentives are
paid per ton of heating capacity. Heat pumps must meet both the cooling mode and heating
mode efficiency requirements to qualifu for per ton cooling efficiency incentives.
4. Equipment size categories are specified in terms of net cooling capacity at AHRI standard
conditions as determined by AHRI Standard 2101240 for units <65,000 Btu/hr, AHRI Standard
3401360 for units >65,000 Btu/hr, an+AHRI Standard 310/380 for PTAC and PTHP units. and
AHRI Standard 1230 for VRF systems.
5. Ground and Water Source Heat Pumps must meet or exceed listed efficiency requirements
when rated in accordance with ISO-13256-l to qualify for the listed incentive.
6. Units rated only with an IPLV may qualit/ for the listed incentives if the value meets or
exceeds the minimum IPLV established as part of the Consortium for Energy Efficiency
Commercial Unitary Air-Conditioning and Heat Pump specification effective January 16,2009.
7. Efficiency requirements align with the Unitary Air-Conditioning and Heat Pump
Specification maintained by the Consortium for Energy Efficiency for equipment with heating
sections other than electric resistance. CEE minimum efficiency requirements are listed on the
Company website.
AHRI : Air-Conditioning, Heating and Refrigeration Institute
CEE: Consortium for Energy Efficiency
COP: Coefficient of Performance
EER: Energy Efficiency Ratio
HSPF: Heating Seasonal Performance Factor
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective luly 14,2012
Rocky Mountain Power
Exhibit No. 1 Page 16 of 30
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
HVAC : Heating, Ventilation and Air-Conditioning
IEER: Integrated Energy Efficiency Ratio
IPLV: Integrated Part Load Value
PTAC : Packaged Terminal Air Conditioner
PTHP: Packaged Terminal Heat Pump
SEER: Seasonal Energy Efficiency Ratio
VRF = Variable Refrigerant Flow
tives for other HVAC UI
Notes for other HVAC equipment incentives:
1. Equipment that meets or exceeds the efficiency requirements listed for the equipment
category in the above table may qualify for the listed incentive.
2'Incentivesarepaidat$0.{3]!kWhannualenergysavings@
. IDEC energy and{eman*savings are subject to approval by the Company.
3.Incentivespaidat$0.*2]!kWhannualenergysavings
ss,yin€s. Chiller energy andiemen*savings are subject to approval by the Company.
ldaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
ncen r
Equipment Type Size Category lub-Category Minimum
Efficiency Requirement
Customer Incentive
Evaoorative Coolins All )irect or Indirect EO.O6/ISR CFM
Indirect-Direct Evaporative
Cooling (IDEC)
All sizes Applicable system
components must exceed
minimum efficiencies
required by energy code
[0.15/kwh annual
zlglgv
syi4-s$el}kWh
mfl*fenergy-so+ings
|t50&W (See note 2)
lhillers All except chillers
intended for backup
service only
ie#e+S9rvi!&pri mari ly occupant
:omfort cooling loads (no more than
l0%o for process cooling loads)
Must exceed minimum
efficiencies required
energy code.
tU.l5/kwh annual
]nerg.v
;avines$'+.-[}kl#h
$seAdv
See Note 3
Room Air Conditioner Residential (used in a
business)
iee Home Energy Savings program See Home Energy
Savings program
See Note 5
)651366 Day Programmablt
rr Occuoancy-based
Ihermostat
All sizes in portable
classrooms with
mechanical coolins
Musl be installed in portable
:lassroom unoccupied during
;ummer months
165 1366 day thermostatic
rr occupancy-based
rethack cnnnhilitv
ll5O/thermostat
)ccupancy Based
PTHP/PTAC control
All sizes with no prior
occupancy based
control
See note 5!150/controller
Evaporative Pre-cooler ior sinele air-cooled packaeed
'ooftoo or matched split svstem
Minimum performance
:fficiency of 75%o.
[7Slron of atfncher
lRetrofit Onlv):ooline capacitv
;ondensers onlv.Must have enthalpv
:ontrols to control pre-
;ooler ooeration. Water
;upplv must have
:hemical or mechanical
water treatment.
Rocky Mountain Power
Exhibit No. 1 Page 17 of 30
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
4. Controller units must include an occupancy-s€f,sor:basec! conllrol and include the capability to
set back the zone temperature during extended unoccupied periods and set up the temperature
once the zone is occupied.
5. Refer to Company's Home Energy Savings program for efficiency requirements and
incentives for listed residential appliances used in a business.
CFM = Cubic Feet per Minute
HVAC : Heating, Ventilating and Air-Conditioning
IDEC : Indirect-Direct Evaporative Cooling
PTAC = Packaged Terminal Air Conditioner
PTHP: Packaged Terminal Heat Pump
ldaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page l7 r
Rocky Mountain Power
Exhibit No. 1 Page 18 of 30
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Incentives for building envelope (Retrofit)
Equioment Tvpe Category Minimum E{Iiciencv Reouirement
Customer
Innenlive
Cool Roof ENERGY STAR Qualified $0. I 0/square
foot
Roof/Attic Insulation Minimum increment of R- l0 insulation added $0.09/square
foot
Wall Insulation Minimum increment of R-10 insulation added $0.07/square
foot
Windows
(See notes 3, 4)
site-builr U-Factor < 0.30 and SHGC S 0.33
(glazing only rating)
$0.35/square
foot
Assembly U-Factor < 0.30 and SHGC < 0.33
(entire window assembly rating)
$0.35/square
foot
Window Film Existing windows See Note 5
su.l)/t(wh
annual energv
savinss
(See Note 5)
Notes for building envelope incentives (retrofit):l. Equipment that meets or exceeds the efficiency requirements listed for the equipment category in the above table
may qualifu for the listed incentive.
2. Building must be conditioned with mechanical cooling to be eligible for envelope incentives.
3. Energy performance of window assemblies and glazing products must be rated in accordance with NFRC. Site-
built metal window systems must include a thermal break within the frame or other appropriate NFRC certification
to qualift for incentives. Skylights are not eligible to receive incentives.
4. Window square footage is determined by the dimensions of the entire window assembly, not just the window
glass.
5. Incentives for window film are calculated based on film specifications and window orientation at $0.{+.!l/kwh
annual energy savings. Energy savings subject to approval by the Company.
NFRC : National Fenestration Rating Council
SHGC : Solar Heat Gain Coefficient
Idaho wattsmart Business (Schedule 140) - Filed August 2014 Page 18 r
Proposed changes are marked relative to the current FinAnswer Express program which was effective luly 14,2012
Rocky Mountain Power
Exhibit No. 1 Page 19 of 30
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Incentives for bu ild in g envelope (New Construction/lVlajor Renovation)
Eouinment Tvne Catesory Minimum Efficiencv Reouirement
Customer
Incentive
Cool Roof ENERGY STAR Qualified $0. I 0/square
foot
Roof/Attic Insulation Minimum increment of R-5 insulation above
code (See Note 5)
$0.09/square
foot
Wall Insulation Minimum increment of R-3.7 continuous
insulation above code (See Note 5)
$0.07lsquare
foot
Windows
(See Notes 3, 4)
Site-built U-Factor S 0.30 and SHGC S 0.33
(glazing only rating)
S0.35/square
foot
Assembly U-Factor < 0.30 and SHGC S 0.33
(entire window assembly rating)
$0.35/square
foot
Notes for building envelope incentives for New Construction/lVlajor Renovation projects:
l. Equipment that meets or exceeds the efficiency requirements listed for the equipment category in the above table
may qualifu for the listed incentive.
2. Building must be conditioned with mechanical cooling to be eligible for envelope incentives.
3. Energy performance of window assemblies and glazing products must be rated in accordance with NFRC. Site-
built metal window systems must include a thermal break within the frame or other appropriate NFRC certification
to qualifo for incentives. Skylights are not eligible to receive incentives.
4. Window square footage is determined by the dimensions of the entire window assembly, not just the window
glass.
5. Compliance with the minimum efficiency requirements of roof/attic and wall Insulation measures may be
demonstrated with equivalent U-factors and are subject Company approval.
NFRC: National Fenestration Rating Council
SHGC: Solar Heat Gain Coefficient
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page 19 r
Rocky Mountain Power
Exhibit No. 1 Page 20 of 30
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
lncentives for food service equipment
Eouioment Tvoe Eouinment Cateporv
Minimum Efliciency
Reouirement
Customer
Incentive/f Tnit
{Jsed js+*usinese See+eme+nergrSa+ings
Pmm See+{ete4
Undercounter
ENERGY STAR Qualified
s50sl00
(@
Temlrrature models
ilelectric boosters Only )(k-3)
Stationary rack, single
tank, door type $+00et00
Single tank conveyor $rr5001.000
Multiple tank conveyor $e'000500
Volume > 28 cu. ft.
ENERGY STAR Qualified
$60+400
tslecrtc lnsulateo tlololng
Cabinet l3 < Volume < 28 cu. ft.$5ee300
Volume < 13 cu. ft.$4e+200
Electric Steam Cooker
3-, 4-, 5- and 6-pan or
larger sizes - Tier I ENERGY STAR Qualified $?5S!30
3-, 4-, 5- and 6-pan or
larger sizes - Tier 2
ENERGY STAR Oualified il
Heary Load Efficiency >@Yq@
LJereJ)
$84+300
Electric Convection Oven ENERGY STAII Oualifi e#70%
ffi $350
Electric Griddle
+ier+FNER€+€++RJioFI
Oueti$ed $2se
+i€*4 ENERCY STAR Tier 2
Qualified $5e150
Electric Combination Oven
6-15 pans-
ENERGY STAR Oualifiedl{earfr
@@
4)
$ r,000
l6 - 20 oans ENERGY STAR Oualified $27s
Electric Commercial Fryer
Tier I ENERGY STAR Qualified $200
Tier 2
ENERGY STAR Oualified
WCooking Efficiency >
8@%,Idle Energy Rate <??3
860 Watts (Seellete-{)
$300
Ice Machines
(Air-Cooled Only)
Tier l:
Harvest rate < 500 lbs/day
ENERGY STAR Qualified
s6+125
Tier l:
Harvest rate > 500 lbs/day $r++150
Tier 2:
Harvest rate < 500 lbs/day
CEE Tier 2 Qualihed
$-13+210
Tier 2:
Harvest rate > 500 lbs/day $265{0q
Residential Refrigerator Used in a business See Home Energy Savings
Prooram See Note 2
Residential Refrieerator/
Freezer Recvclins Used in a business See residential refri gerator/
freezer rccvclino nrosram See Note 3
Commercial Glass
Transoarent Door
Refrigerator
0 < Volume < 15 cu. ft.
ENERGY STAR Qualified
$]{)02t
15 < Volume < 30 cu. ft.$s50
30 < Volume < 50 cu. ft.${5e25
ldaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective Ju'ly 14,2012
Page 20 r
Rocky Mountain Power
Exhibit No. 1 Page 21 of 30
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Volume >50 cu. ft.$r+5125
Chest configuration $?s50
Commercial Glasa
Transparent Door Freezer
0 < Volume < 15 cu. ft.
ENERGY STAR Qualified
$25$eo
l5 < Volume < 30 cu. ft.$Lo$325
30 < Volume < 50 cu. ft.E:Se+s
Volume >50 cu. ft.$100r$800
Chest configuration $100
€emmereid{eliCDeor
*e*ig€ra*er
0<-Ifu{um€<*5+u*
glER€Y€+ RqmHfiod
$5e
l+<{Ielum€-<3M $?5
30=-lldum€<{e+u*${{0
Velumo+S0+u*${+s
€hes+eenf,gura+ien $+s
€emmercialSeli&Deer
Freezer
0 < Velume < 15 eu, ft,
EIIERCY€Td.RAuefif,od
${59
+++tlelume4e+u'+$H
30+lfulume<-50+u'+$200
l*elsms+soerr.*$e0
ehest+eafiguration $J50
LED Case Lighting (Retrofit
Only)
LED replacing fluorescent lamp
in refriserated cases.
$1O/linear loot
Refrigerated Case Occupancy
Sensor (Rehofit Only)
Installed in existing refrigerated
case with LED liehtine $l/linear fool
Demand Controlled
Kitchen Ventilation
Exhaust Hood
(Retrofit Onlv)
Must be installed on
commercial kitchen
exhaust system.
Variable speed motors must
be controlled to vary fan
sDeed deDendins uDon kitchen
$0.1s/kwh
annual enerey
savings
(See note 4)demand. as indicated bv
connected sensors.
Anti-Sweat Heater
Controls
Retrofit Onl),)
Low-Temo (Freezine)
Cases
Technologies that reduce
enerey consumption of anti-
sweat heaters based on
sensinq humiditv.
$20llinear foot
(case length)
Med-Temo (Refrigerated)
Cases (case length)
Notes for food service equipment incentives:l. Equipment that meets or exceeds the efficiency requirements listed for the equipment category in the above table
may qualify for the listed incentive.
2. Refer to Company's Home Energy Savings program for efficiency requirements and incentives for listed
residential appliances used in a business.
iffi.
1, Te meet the Minimum Effieieney Requirement(s) listed; valuevmust be based en testirg in eeeerdenee with *re
3. Refer to the Compan)r's residential refriserator and freezer recycline proeram (See )ra later. refriqerator@) for
requirements and incentives for listed appliance recvcline measures for residential appliances used in a business.
4. Incentives are paid at $0.15/kWh annual eners.v savinss. Demand controlled kitchen ventilation exhaust hood
enersv savines subject to approval bv Company.
CEE : Consortium for Energy Efficiency
MDEC = Maximum Dailv Enerey Consumption
V = Association of Home Anpliance Manufacturers (AHAM) Volume (cubic feet)
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page2l r
Rocky Mountain Power
Exhibit No. 1 Page 22 of 30
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Incentives for oflice equipment
Eouinment Tvoe Minimum Efliciencv Reouirements
Customer
Incentive
Network PC Power Managemenl
Software
l. Installed software must automatically control the
power settings of networked personal computers
(PC) at the server level
2. The software must manage power consumption
for each individual PC
3. The software must include the capability to
report energy savings results
4. lncentives are for desltop comouters only.
Controlled laotop comouters are not eligible for
incentives-
$An per controlled
PC
(ur{o-+Og++*
E r€rgFEtr€i€n€f
Ueasure+ests)
Smart Plug Strip
l. Incentive applies to any plug strip that eliminates
idle or stand-by power consumption ofconnected
plug-load appliance through the use ofan
occupancy sensor, electric load sensor, or timer.
2. Applies only to electric plug-load applications
(e.g. computer monitors, desk lamps, etc.)
$15/qualifoing unit
Notes for office equipment incentives:l. Equipment that meets or exceeds the efficiency requirements listed for the equipment category in the above table
may qualify for the listed incentive.
PC : Personal Computer
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page2? t
Rocky Mountain Power
Exhibit No. 1 Page 23 of 30
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Incentives for applianees
Eouinment Tvne Equioment Catesorv Minimum Elliciencv Reouirement
Customer
Incentive
High-Effi ciency Clothes Washer
Residential
(used in a business)See Home Energy Savings program See Note 3
Commercial
(must have electric
water heating)
ENERGY STAR Qualified ${5tr!00
egE+;e+lauamee $r0e
Electric Water Heater Residential
(used in a business)See Home Energy Savings program See Note 3
Notes for appliance incentives:
l. Equipment that meets or exceeds the efficiency requirements listed for the equipment
category in the above table may qualify for the listed incentive.
2. Equipment must meet the efficiency rating standard that is in effect on the date of purchase.
3. Refer to Company's Home Energy Savings program for efficiency requirements and
incentives for listed residential appliances used in a business.
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page 23 r
Rocky Mountain Power
Exhibit No. 1 Page 24 of 30
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
I ncentives for Incentives{epFa rm a nd Da irv daiq#fr+m+Eq u i pm en t
Eouinment Tvne Eouioment Catesorv Minimum Elliciencv Reouirements
Customer
Incentive
Automatic Milker Takeoffs
(Retrofit qenly)
Equipment must be able to sense milk
flow and remove milker when flow
reaches a pre-set level. The vacuum
pump serving the affected milking
units must be equipped with a VFD.+o
@ffi
Incentive is available for adding
automatic milker takeoffs to existine
milkine svstems. not for takeoffS on a
brand new system where there was
none before. retrcStentr.
Replacement of existing automatic
milker takeoffs is not eligible for this
listed incentive. but may oualit for a
Custom Enerev Efficiencv
Incentive.ineentiveq-exeeplrvheetle
@
$235 each
Agricultural Engine Block
Heater Timers
Timer must be a Ul-listed device and
rated for a minimum of l5 amps
continuous duty.
$10 each
Hieh Efficiencv Circulating
Fans
(See note 2)
l2-23" Diameter Fans must achieve an efficiency level
of I I cftrwattl#€fi $25lfan
24-35" Diameter Fans must achieve an efficiency level
of l8 cfm/wattr#a*$35/fan
36-47" Diarneter Fans must achieve an efficiency level
of l8 cfm/watt*aft $50/fan
>48" Diameter Fans must achieve an efficiency level
of 25 cfm/wa$#aft ST5lfan
Heat RecoveryReeleimers
Heat rceleimerfqgevgry_Uni! must use
rvas{e-heat reiected from milk cooline
refrigeration systemeempresser to heat
water. Customer must use electricity
for water heatinsffir.
$220henCenser
kw$o.tgkwh
annual energy
savinss
High-effi ciency t!ivestock
{y'yaterers
Must have two inches or more of
insulation surrounding the inside ofthe
waterer and an electric heating
element. These-l@_with a
heating element greater than 250 watts
must have an adjustable thermostat.
Non-electric waterers do not qualifr.
$165 each
High-_e!ffi ciency Ventilation
EAqsystens
(See note 2)
l2-23" Diameter Fans must achieve an efficiency level
of I I cfm/wrrllatt $45/fan
24-35" Diameter Fans must achieve an efficiency level
of l3 cfm/Yr#att $75lfan
36-47" Diameter Fans must achieve an efficiency level
of l7 cfm/wr#att $ I 25lfan
>48" Diameter Fans must achieve an eflciency level
of 19.5 cfm/w:rllatt $ I 50/fan
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page24 t
Rocky Mountain Power
Exhibit No. 1 Page 25 of 30
Case No. PAC-E-14-08
Vvilness: Kathryn C. Hymas
Milk Pre-coolers
The equipment must cool milk with
well_-water before it reaches the bulk
cooling tank.
$0.15&wh
annual energy
savings
{SeeAIa+e-3)
Programmable Ventilation
Controllers
The controllerequipment must conhol
ventilation fans based on temperature
or other applicable factors such as
humidity, odor concentration, etc.
$20lfan
controlled
Variable Frequency Drives for
Dairy Vacuum Pumps
(Retrofit only)
]ffD$e+qpipffi€nt must vary t$e
motor speed based on target vacuumlevel.ffi
@ncentive
available for retrofit only (i.e. new
construction and reolacement of
existine VFD not elisible.)fersystems
withorrt on exiating VFD.
$165/hp
Potato or onion storaee fan
VFD
Add variable freouency drive to
existing or new fan in potato or onion
storase.
$0.r5/kwh
annual energy
savinqs
Notes for Farm and Dairv dairyhrm-equipment incentives:
l.Equipmentthatmeetsorexceedstheefficiencyrequirementsabovetable
may qualiry for the listed incentive.
2. Fan performance must be rated by an independent testing body in accordance with the appropriate ANSI/AMCA
standards.
3.
available to reduce the Energy Efficiencv Project simple payback below one year. Enerqv savines and Enerey
Efficiency Project Costs are subject to Company approval.
4. Except where noted, all equipment listed in the table lgrvitl-be eligible for incentives in both 4New €gonstruction
and gRetrofit projects.
AMCA : Air Movement and Control Association International, Inc.
ANSI = American National Standards Institute
VFD : Variable_Frequency Drive
cfrn = cubic feet per minute
w = watt
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page 25 r
Equipment
(-nleonru Renlace with Limitations Unit
Customer
Incentive
Low-Pressure
Drop Filters
Standard
coalescing
filter
Rated low_-pressure drop filter
where:
L Pressure loss at rated flow is <l
psi when new and <3 psi at elemenl
change.
2. Particulate filtration is 1007o at
>3.0 microns and99.98o/o at 0.1 to
3.0 microns, with < 5ppm liquid
carryover:
3. Filter is deep-bed "mist
eliminator" style, with element life
> 5 years.
4. Rated capacity of filter is < 500
scfm-
l. {ompressor system
must be > 25 hp and <
75 hp.
2. Comoressor discharse
Dressure setpoint must
be reduced by 2 psi or
more after installation of
low pressure drop filter.
scfm $&8eflscfm
Receiver
Capacity
Addition
Limited or no
receiver
capacity
(< 2 gallons
per scfm of
trim
compressor
capacity)
Total tanlt-receiver capacity after
addition must be > 2 gallons per
scfm oftrim compressor capacity
l. Compressor system
size < 75 hplE!
countins backup
comoressor(s)..
2. Trim compressor
must use load/unload
control. notsr*ithr*t
inlet modulation or
on/offcontrol.
3. Systems with *VFD
g!)!!!pEi!s!)! or using
variable displacement
comoressor as trimcompressor..#
trir*eenrpresser are not
elisible.
gal
$*35e/gallon
above 2 gallong
pgllscfm
Cvcline
Refrigerated
€yeling-Dryers
Non-cycling
refrigerated
dryer
Cycling refrigerated dryer
l. Compressor system
size < 75 hp.
2. Rated dryer capacity
must be < 500 scfm.
3. Dryer must operate
exclusively in cycling
mode and cannot be
equipped with the ability
to select between
cycling and non-cycling
mode.
4. Refrigeration
compressor must cycle
offduring periods of
reduced demand.
scfm $2L50lscfm
VFD
Controlled
Compressor
eempressor
75+p-er
sm*lerEircd
speed
comDtessor
S75 hp VFD controlled oil-iniected
screw compressor operatine in
system with total compressor
caDacitv S75 hp. not countine
backup compressor capacitv!4S*p*@@
l. -_IS!aL_S9!0pEtsor
capacitv in uperaded
svstem is S75 hp. not
countins backup
compressor.Singl,e
eper€sifl€-€empr€ssor<
15+f-.
2. {ompressor must
adjust speed as primary
means of capacity
control.
he
$0.r5lkwh
annual energy
savings
(See-aete-9
Rocky Mountain Power
Exhibit No. 1 Page 26 of 30
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Incentives for Ceompressed aAir Eq-Uipmen!
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page 26 r
3=-eompresser-ffist-no{
use-i*lermedul*ien
rvhen{emandis$elorv
minimm-seeea
thresh€+d-€4+h€-\lFD
eospfes's€t
Zero Loss
Condensate
Drains
Fixe4+.[imer
drain
Zero loss condensate drain
(See note 4)
Drain is designed to
function without release
of compressed air into
the atmosphere.:!ny
size svstem is elieible -
there is no restriction on
compressor size.-(ell
€cmarcss+4i?ec)=
each $9!00 each
Outside Air
Intake
Compressor
drawine
intake
drerviag=air
from
compressor
room
Permanent ductwork between
compressor air intake and
o utdoorsS-75*p+empresser-rvhere
@
l. Compressor system
size S 75 hp.
2. Ductwork must meet
manufacfurer's
specifications, which
may include: (a) <
0.25" W.C. pressure loss
at rated flow, and (b)
allow use of compressor
room air during
extremely cold outside
air conditions.
hp $G30ftrp
Compressed air
end use
reduction
Inapprooriate
or ineflicient Functionallv eouivalent altematives
Any size svstem is
elieible - there is no $0.r5/kwh
annual enerqy
savingscompressed
air end use
or isolation valves restriction on
compressor size.
Rocky Mountain Power
Exhibit No. 1 Page 27 of 30
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Notes for Qeompressed cdir incentives:
l.- gquipment that meet
te eustemers with eempressed air sy"tem(s) eentaining eempressers with a tetal sy"tem herseperver less than er
egqsl+e+5+PiFsize.
2.--gxcept for tne zero to
to compressed air svstems with total comoressor caoaciB of 75 hp or less. not includinq backuo compressor capacitv that does
not normallv run.
ive
3.- Incentives are caooed at 70 percent ofEnerev Efliciencv Project Costs. and incentives will not be available to reduce Enersv
Efficiency Proiect simole payback below one vear. Enerev savines and Enerqv Efficiencv Proiect Costs are subiect to Comoanv
approval.
fer VFD eertrelled eempressers are ealeuleted based en eempresser size enC ether system parameters at $0,15/kWh
4.- Zero loss condensate drains purchased as an integral part of another measure are elieible for the incentive shown above. l.ess
ineen+ives,
hp: horsepower
ppm : parts per million
ldaho wattsmart Business (Schedule 140) - Filed August 20 l4
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Page27 t
Rocky Mountain Power
Exhibit No. 1 Page 28 of 30
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
psi : pounds per square inch
scfm : g€ubic Ffeet of air per l*nqinute at standard conditions (14.5 psia, 68oF, and 0%o relative humidity)
VFD : Vvariable_-Ffrequency Dglrive
Incentives for Wastewater and Other Refrieeration Enersv Efficiencv Measures
Notes for other enerw efliciencv measures incentives tablel. Equioment that meets or exceeds the efliciencv reouirements above may qualifu for the listed incentive.
2. Incentives are capoed at 70 percent ofEnersy Efliciency Proiect Costs and incentives will not b€ available to reduce the
Enerev Elliciencv Proiect simole pavback below one vear. Enerqv savinss and Enerev Efliciency Proiect Costs are subiect to
Companv aoproval.
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective July 14,2012
Equinment Tvpe Rcplrse with Customer Inccntive
Adaptive refrigeration
control
Conventional controls (defrost
timeclock. snace thermostal
evaporator fan control. ifanv.
thermal expansion valve in
some instances)
Adaptive refriseration controller
and. in some instances. electric
exoansion valve
$0.15/kWh annual
enerqv savings
Fast actins door
Manually operated door.
automatic door with lone cycle
time. strio curtain. or entrvway
with no door in
refriserated/conditioned soace
Fast actine door $0.15/kWh annual
enersy savinss
Wastewater - low nower
mixer Excess aeration caoacifu Extended ranse circulator $0.15/kWh annual
energv savings
Rocky Mountain Power
Exhibit No. 1 Page 29 of 30
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Enhanced Incentives for Small Businesses (Retrofit onlv)t
T8 Fluorescent
Retrofit
Oamo/Ballast)
4' CEE Oualified ReducBd Wattase Lamp and CEE
Oualified Ballast included on oualified ballest list Sl40/Fixture
Delamp
4' CEE Oualified Reduced Wattaee or Hich
Performanc€ Lamo and CEE Oualifred Ballast. Must
$120/Fixtureremove one or more lamos. To delamp an existinc
fxture. the lamo and all corresoondins sockets must
be oermanentlv disabled-
Tl2 Conversion
(Kit/Lamo/Ballas)
8' Tl2 to (2) 4' CEE Oualified Reduced Wattase or
Hish Performance T8 Lamos and CEE Ouslified
Bnllnst
$150/Fixturc
Relamp Lamp wattage reduction > 3 Watts. No ballast retrofit $15/Lamp
Installed
Replacement -
Hieh Bay
ffixture/LamplBallas0
Fixture with less than six (6) lamos: 4' CEE
Oualified Hich Performance Lamo. Must reolace
TI2HO/VHO Incnndesenl nr lilf)$300/Fixture
Fixture with six (6) or more lamos: 4' CEE Oualified
Hish Performance Lamo, Must replace
Tl2HOnfHO- Incandescent or HID
$35Offixture
T5 Fluorescent
Replacement - T5
Standard
Gixture/Lamo/Ballast)
4' Nominal Lamo < 28 Watts. Ballast Factor S 1.0 $250/Fixture
Relamo Lamp wattase reduction > 3 Watts. No ballast retrofit 322tLamp
Installed
Reolacement -
Hieh Bav
Gixture/Lamo/Ballas0
Fixture with less than six (6) lamos: Must replace
TI2HO/VHO. Incandescent or HID $37s/Fixturc
Fixture with six (6) or mor€ lamps: Must lEplace
TI2HO/VHO. Incandescent or HID $45OlFixture
LED
ReolacemenURetrolit -
Recessed Downlicht
Gixture or Kit)
Must replace existine incandescent or fluor€scenl
LED must be listed on oualified eouipment list $150/Fixture
Reolacement - Exit
Siens Must reolace incandescent or fluorescent $100/Siqn
Liehtine
Control
Wall Occupancy
Sensor Retrofit PIR Dual Tech $100/Sensor
Ceiline Occuoancy
Sensor Retrofit PIR. Dual Tech $220lSensor
Notes for enhanced incentives for small business customers:l. To be eligible for the incentives listed. the new lishtine system must use less enerey than the
existine liehtine system replaced or the baseline lishtine system as determined by the Comoanv.
2. Incentives are capoed at 80 percent of Enerey Efficiency hoject Costs. Enerey Efficiency
Project Costs are subject to Company approval.
3. Incentives for T8 Fluorescent Premium Delamps may not be combined with other linear
fluorescent lamp or fixture incentives. Complete fixture removals are not eligible.
4. Incentives for T8 and T5 Fluorescent Relamps may not be combined with other linear fluorescent
lamo or fixture incentives and will only be paid once per facilitv.
8 Incentives for measures in this table are available onlv to Small Business customers as defined in the incentives
table on oase 2.
e Actual incentives are subiect to chanee and will be determined bv Companv on a component level basis on no lesst ait;.
Idaho wattsmart Business (Schedule 140) - Filed August 2014
Proposed changes are marked relative to the current FinAnswer Express program which was effective luly 14,2012
Rocky Mountain Pou/er
Exhibit No. 1 Page 30 of 30
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
5. Oualified equioment lists referenced in the above table are posted on the Idaho enerey efficiency
prosrarn section of the Company's website.
BF = Ballast Factor
CEE = Consortium for Enerey Efficiency
CFL = Compact Fluorescent Lamp
CMH = Ceramic Metal Halide
HID: Hish Intensitv Discharge (e.g. Mercury Vapor. High hessure Sodium. Metal Halide)
HO = High Output
LED = Lisht-Emittine Diode
PSMH = Pulse-Start Metal Halide
VHO: Verv Hish Ou(put
Idaho wattsmart Business (Schedule 140) - Filed August 2014 Page 30 r
Proposed changes are marked relative to the current FinAnswer Express program which was effective JuIy 14,2012
Case No. PAC-E-14-08
Exhibit No. 2
Witness: Kathryn C. Hymas
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Testimony of Kathryn C. Hymas
Idaho Three-Year Business Plan Cost Effectiveness
August 2014
Rocky Mountain Power
Exhibit No. 2 Page 1 of 31
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
To:
From:
Subject:
Date:
MEMORANDUM
Don Jones, Jr.
Brian Hedman and Byron Boyle
ldaho Three-Year Business PIan Cost-Effectiveness
August 8,2014
The tables below present the cost-effectiveness findings of the ldaho Three-Year Business Plan based on
costs and savings estimates provided by PacifiCorp in a spreadsheet entitled "Copy of CE inputs for lD
WSB filing 051914+ updates 061614+ REV 052514.xlsx"and in an email from Don Jones, Jr. on June 26,
2014. The utility discount rate is from the 2013 PacifiCorp lntegrated Resource Plan.
Three-year cost-effectiveness inputs and results for the business-as-usual program, increased incentives,
energy management, paying for commissioning, two commercial measure categories, six industrial
measure categories, and the portfolio combined are presented in this memo. Business-as-usual includes
the impacts of energy codes and lighting baseline adjustments. The Business Plan Portfolio includes the
impacts of Energy Project Manager Co-funding.
1. Business Plan Portfolio 2O\5-20L7: Numbers 2 - 15 combined (Table 15)
2. Business-as-Usual 20L5-2017 (Table 19)
3.
4.
5.
6.
7.
8.
9.
10.
11.
lncrease EF 2015-2017 (Table 23)
lncrease Agriculture System Re-design 2Ot5-20L7 (Table 27)
Energy Management Offer 2Ot5-2077 (Table 31)
Pay for Commissioning 2015-2017 (Table 35)
Commercial Food Service 2OL5-2077 (Table 39)
Commercial HVAC 2015-2017 (Table 43)
lndustrial Compressed Air 2015-2017 (Table 47)
lndustrial Potato Storage Fan VFD 20L5-2077 (Table 51)
I nd u st ria I Ada ptive Ref rige ratio n Cont rol 2OL5-2077 (Ta ble 5 5)
Industrial Fast Acting Door 2015-2017 (Table 59)
lndustrial End Use Compressed Air Reduction2Ot5-20L7 (Table 53)
lndustrial Wastewater Mixing - Grid Bee 2015-2017 (Table 67)
Small Business 2015-2017 (Table 71)
72.
13.
14.
15.
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
An Employee-Owned Company
www.cadmusgroup.com
Corporate Headquarters:
I 00 5th Avenue, Suite I 00
Waltham, MA 02451
Voice: 617-673.7000
Fax:[phone]
Rocky Mountain Povrrer
Exhibit No. 2 Page 2 ot 31
Case No. PAC-E-14-08
\Mness: Kaihryn C. Hymas
For alf measures, cost-effectiveness was tested using the 2013 IRP 70% load factor east system
decrements. Table l lists modeling inputs.
lnflatlon Ratel
Future rates determined using a t.9% annual escalator.
Table 2,
Table 3,
Table 5,
Table 4, and Table 5 list the costs and incentives and Table 7,
720 5W Washington Street
Suite 4oo
Portland,OR 97205
Voice:503.467.7100
Fax [phone]
Rocky Mountain Power
Exhibit No. 2 Page 3 of 31
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Table 8, Table 9, and
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 4 of 3'l
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Table 10 list the annual energy savings for each measure group. The following tables present the cost
effectiveness results. Table 11 presents the three year summary of the benefit cost ratios for
each of the categories. Tables L2-7L present the individual cost benefit analysis for each
category by year and in total. Allvalues in Tables L2-7L are shown in 2015 dollars.
Table 11 provides a comparative summary of the benefit/cost ratios from the individual measure
category, program, and portfolio results, from allfive test perspectives. Table 12 to Table 71 show the
complete cost-effectiveness results by measure category, program, and portfolio.
The combined three-year portfolio is cost-effective from alltest perspectives except the RlM. The
energy management offer is the only measure not cost-effective from both the PTRC and TRC
perspectives.
Table 1. !D Three-Year Business Plan: Financial lnputs
Future rates determined using a 1.9% annual escalator.
lrrisation Energy Rate (S/kWh) - 2013 base rate
Commercial Energy Rate (S/kWh) - 2013 base rate
lndustrial (no lrrigation) Energy Rate (S/kWh)- 2013 base rate
lndustrial (with lrrigation) Enersy Rate (S/kWh) - 2013 base rate
Table 2. lD Three-Year Business Plan: Business-as-Usua! Program Costs
BAU Commercial
1 s85,479 s204,256 s289,735 s604,841
2 s85,479 s204,256 s289,735 s604,841
3 s8s.479 $204,256 S289,73s s604,841
BAU lndustrial
L s243,287 ss81,344 s824,632 st,72L,470
2 $243,287 s581,344 5824,632 SL,zL,47o
3 s243,287 s581,344 5824,532 sL,72L,47O
lncrease EF Commercial
1 St,ttz s17,33s s18,s08 54,629
2 51,L72 s17,335 s18,508 $4,629
3 5L,L72 s17,33s s18,508 54,629
lncrease EF lndustrial
1 s3,336 S49,339 s52,676 sL3,L74
2 S3,336 S49,339 s52,676 5t3,174
3 s3,335 s49,339 s52,676 Sr:.,nq
lncrease Agriculture 1 s7.9s4 s68,711 576,704 S44,116
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.71 00
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 5 of 31
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
System Re-design
Agricultural
2 s7,994 Sog,zu 576,704 s44,115
3 57,e94 s68,711 576,704 544,LL6
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mounlain Power
Exhibit No. 2 Page 6 of 31
Case No. PAC-E-14-08
VMlness: Kathryn C. Hymas
Energy Management
Offer Commercial
L s4,876 s718 s5,594 s2,581
2 Su,687 s1,588 5t3,z7s 5s,441
3 523,755 s3,071 s25,836 s10,255
Energy Management
Offer lndustrial
1 S13,878 52,044 5t5,922 57,34s
2 533,262 S4,s19 537,782 s15,485
3 567,640 s8,74L s76,381 s29,188
Pay for Commissioning
Commercial
1 52,134 s4,753 s6,887 StL,2o4
2 $2,134 Sq,zsg Se,ssz $LL,2o4
3 $2,L34 s4,7s3 s5,887 Sr:,zoq
Pay for Commissioning
lndustrial
1 $6,O74 5L3,s27 S19,5oo s31,887
2 $6,O74 s13,527 s19,500 S31,887
3 s6,074 S13,s27 S19,600 s31,887
Table 3. tD Three-Year Business Plan: Commercia! Program Costs
Food Service
L s3,015 (S2,055)Sg+g (s4,178)
2 Se,osz (S2,oo9)Sr,o+s (S3,953)
3 s3,682 (s471)s3,211 $6,278
HVAC
1 s2,L48 s4,595 s6,843 s19,302
2 52,253 Ss,060 S7,313 52O,258
3 Sz,ztt Ss,so3 S7,880 s21,398
720 SW Washington Street
suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2Page7 ol31
Case No. PAC-E-14-08
Wlness: Kathryn C. Hymas
Table 4. lD Three-Year Business Plan: lndustrial Program Costs
Compressed Air
7 s1,800 s3.000 s4,800 57,220
2 S1,8oo S3,ooo 54,8oo 57,220
3 $1,800 s3,ooo 54,8oo 57,220
Potato Storage Fan VFD
1 s2,790 s4,6s0 57,440 s9,900
2 s2,790 S4,6so 57,44o Sg,goo
3 52,790 S4,5so $7,440 Ss,soo
Adaptive Refrigeration
Control
1 52,52O s3,9oo 56,42O s9,400
2 S3,ooo Ss,7oo Ss,3oo s15,800
3 s4,140 S6,600 Sro,zao S19,ooo
Fast Acting Door
1 S2,880 54,8oo s7,680 s18,000
2 s2,880 s4,8oo s7,580 s18,000
3 s2,880 s4,800 s7,680 s18,000
End Use Compressed Air
Reduction
1 Ssoo s1,500 s2,400 s2,so0
2 Ssoo s1,500 s2,400 s2,500
3 Sgoo S1,soo s2,4oo s2,s00
Wastewater Mixing -
Grid Bee
1 57,2OO S12,ooo S19,2oo s35,ooo
2 57,2OO s12,000 s19,200 s35,000
3 57,2oo 512,000 s19,2oo S3s,ooo
Table 5. lD Three-Year Business Plan: Smal! Business Costs
Small Business
Table 6. lD Three-Year Business Plan: Portfolio Costs
720 SW Washington Street
suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax:[phone]
Energy Project Manager
Co-Funding
Rocky Mountain Power
='[3lJ,i;iLi3t:,Xl3l
Vvitness: Kathryn C. Hymas
Table 7. lD Three-Year Business Plan:
Annualsavings by Measure Type for Business-as-Usual Measures
BAU Commercial
t L,7t4,569 97o/o L,67O,892 78%t,3LL,674 11
2 L,7L4,569 97%t,670,892 78%L,3tL,6L4 11
3 L,7L4,569 97%t,670,892 78%L,3Lt,6L4 11
BAU lndustrial
1 4,979,927 97%4,755,615 78o/o 3,733,054 L7
2 4,879,927 97%4,755,6L5 78%3,733,054 11
3 4,879,927 97%4,755,6L5 78%3,733,054 11
lncrease EF
Commercial
1 2L,726 83%18,033 89%16,049 15
2 2L,726 83%18,033 89Yo L6,049 15
3 2L,726 83%18,033 89%16,049 15
lncrease EF
lndustrial
1 51,836 83%5L,323 89%45,678 15
2 61,836 83o/o 51,323 89%45,678 15
3 51,835 83Yo 51,323 89%45,678 15
lncrease
Agriculture System
Re-design
1 L33,437 L00%L33,43L 93%L24,091 7
2 133,431 L00%L33,43t 93%L24,097 7
3 133,431 LOO%133,431 93%L24,O97 7
Energy
Management Offer
Commercial
L 3s,900 LOO%35,900 90%32,336 3
2 77,912 tN%77,9t2 90o/o 70,L78 3
3 L47,878 ro0%L47,878 90%133,198 3
Energy
Management Offer
lndustrial
1 L02,L77 to0%L02,L77 90%92,034 3
2 22L,749 LOO%22t,749 90%199,735 3
3 420,883 L00o/o 420,883 90%379,103 3
Pay for
Commissioning
Commercial
7 46,LL6 83%38,276 89To 34,066 15
2 46,LL6 83%38,276 89%34,055 15
3 46,LL6 83%38,276 89%34,066 15
Pay for
Commissioning
lndustrial
1 t3L,254 83o/o 108,940 89%96,957 15
2 13L,254 83%108,940 89%96,957 15
3 13L,254 83%108,940 89%96,957 15
720 5W Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 9 of 31
Case No. PAC-E-14-08
\Mtness: Kathryn C. Hymas
Table 8. lD Three-Year Business Plan:
Annualsavings by Measure Type for Commercial Measures
Food Service
1 50,247 toL%50,749 67%34,002 L2
2 50,853 tot%5L,372 67%34,4L9 L2
3 61,368 t0L%61,982 67%4L,528 t2
HVAC
L 35,802 toL%35,150 67%24,227 L2
2 37,554 LOL%37,929 67%25,413 L2
3 39,622 LOL%40,018 67%26,8L2 L2
Table 9. lD Three-Year Business Plan: AnnualSavings by lndustrial Measure Category
Compressed Air
1 20,000 83%15,600 89%L4,774 15
2 20,000 83Y"16,600 89%L4,774 15
3 20,000 83%16,600 89o/o L4,774 15
Potato Storage Fan
VFD
L 31,000 83%25,730 89%22,900 15
2 31,000 83%25,730 89%22,900 15
3 31,000 83%25,730 89%22,900 15
Adaptive
Refrigeration
Control
1 28,000 83%23,240 89%20,684 15
2 40,000 83%33,200 89%29,548 15
3 46,000 83Yo 38,180 89%33,980 15
Fast Acting Door
1 32,000 83%26,560 890/,23,638 15
2 32,000 83%26,560 89%23,638 15
3 32,000 83%26,560 89%23,638 15
End Use
Compressed Air
Reduction
1 10,000 83%8,300 89%7,387 10
2 10,000 83o/o 8,300 89%7,387 10
3 10,000 83%8,300 89%7,387 10
Wastewater Mixing
- Grid Bee
1 80,000 83%66,400 89%s9,096 15
2 80,000 83%66,400 89%59,096 15
3 80,000 83Y"66,400 89%s9,096 15
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 10 of 31
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
The following tables present the cost effectiveness results. Table 11 presents the three year summary of
the benefit cost ratios for each of the categories. Tables 12-71 present the individual cost benefit
analysis for each category by year and in total. All values in Tables L2-7L are shown in 2015 dollars.
t PacifiCorp is proposing increased incentives and outreach costs forthe Increase EF and Agriculture System Re-
design programs. The increased incentive applies to all participants, including those whose savings is reflected in the
Business-as-Usual scenario. As a consequence, the increased incentive and outreach costs are disproportionately
higher than the utility specific savings on an incremental basis. This results in a UCT less than 1.0. This result is not
indicative of the cost effectiveness of the programs in their entirety.
2 See footnote I
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Table 10. lD Three-Year Business Plan: AnnualSavings by Small Business
Table 11. !D Three-Year Business PIan: Benefit/Cost Ratios by Measure Category
Business-as-Usual 1.69 L.54 2.97 0.73 2.27
lncrease EFl 2.78 2.53 0.72 0.43 6.76
Agriculture System Re-designz 1.41 t.28 0.82 0.43 3.27
Energy Management Offer 0.89 0.81 1.01 0.49 3.2L
Pay for Commissioning 2.58 2.35 4.13 0.85 3.07
Commercial Food Service 10.83 9.85 15.50 o.79 0.00
Commercial HVAC r.27 1.15 2.s0 0.63 1.86
lndustrial Compressed Air L.64 L.49 2.55 0.81 2.0t
lndustrial Potato Storage Fan VFD 1.80 1.63 2.55 0.81 2.27
lndustrial Adaptive Refrigeration Control 1.56 L-42 2.6s 0.83 1.85
lndustrial Fast Acting Door t.t4 1.04 2.55 0.81 L.29
lndustrial End Use Compressed Air Reduction 1.55 t.4L 1.83 0.71 2.3t
lndustrial Wastewater Mixing - Grid Bee 1.40 L.28 2.55 0.81 1.55
Small Business t.24 1.13 L.23 0.s0 2.55
Business Plan Portfolio 1.61 1.46 2.37 0.69 2.?t
Rocky Mountain Power
Exhibit No. 2 Page 11 of 31
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Table L2.aD Three-Year Business Plan: Portfolio Cost-Effectiveness 2015
Total Resource CostTest (PTRC)
+ Conservation Adder So.oso S2,520,935 54,022,318 S1,501,383 1.60
Total Resource CostTest (TRC)
No Adder So.oso s2,520,935 S3,G50,G53 s1,135,718 1.45
Utility Cost Test (UCT)s0.o2e 5L,475,377 s3,6s6,6s3 s2,L81,276 2.48
Rate lmpact Test (RlM)5s,3zz,L7B S3,656,6s3 (s1,665,525)0.59
Participant Cost Test (PCT)s2,605,057 S5,867,669 53,262,6LL 2.25
Discounted Participant Payback
(years)3.00
Lifecycle Revenue lmpact
(s/KWh)s0.00004791
Table 13. lD Three-Year Business Plan: Portfolio Cost-Effectiveness 2016
Total Resource CostTest (PTRC)
+ Conservation Adder So.osz S2,665,094 54,2G9,380 S1,G04,286 1.60
Total Resource CostTest (TRC)
No Adder So.osz s2,655,094 S3,881,255 s1,215,151 L.46
Utility Cost Test (UCT)So.032 S1,G55,340 S3,881,2ss 52,225,9L5 2.34
Rate lmpact Test (RlM)S5,G91,625 s3,881,255 (s1,810,370)0.68
Participant Cost Test (PCT)S2,668,565 s6,162,495 S3,493,930 2.3L
Discounted Participant Payback
(years)3.77
Lifecycle Revenue lmpact
(s/KWh)s0.0000s009
Table 14. lD Three-Year Business Plan: Portfolio Cost-Effectiveness 2017
Total Resource Cost Test (PTRC)
+ Conservation Adder So.os3 $2,743,863 s4,48s,8ss 5L,142,036 1.63
Total Resource CostTest (TRC)
No Adder So.oss 52,743,863 s4,078,090 5L,334,221 L.49
Utility Cost Test (UCT)So.osq St,7G6,zo5 54,078,090 S2,311,885 2.3L
Rate lmpact Test (RlM)ss,932,859 54,078,090 (51,8s4,769)0.59
Participant Cost Test (PCT)52,692,444 s6,3s2,309 s3,659,855 2.36
Discounted Participant Payback
(years)4.58
Lifecycle Revenue lmpact
(s/KWh)s0.000049s3
720 SW
Suite 400
Portland, OR 97205
Voice: 503.467.71 00
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2Page 12 oI31
Case No. PAC-E-14-08
VMtness: Kathryn C. Hymas
Table 15. lD Three-Year Business Plan: Portfolio Cost-Effectiveness 20t5-20t7
Total Resource CostTest (PTRC)
+ Conservation Adder So.os1 57,929,992 5L2,177,597 54,847,705 1.61
Total Resource CostTest (TRC)
No Adder So.osr 57,929,892 S11,615,997 S3,686,10s L.46
Utility Cost Test (Ufi)So.osz 54,896,922 S11,G15,997 56,7L9,07s 2.37
Rate lmpact Test (RlM)5L6,945,562 s11,61s,997 (s5,330,665)0.69
Participant Cost Test (PCT)57,966,067 5L8,382,473 s10,416,406 2.37
Discounted Participant Payback
(years)3.82
Lifecycle Revenue lmpact
(s/KWh)s0.0001423s
Table 16. lD Three-Year Business Plan: Business-as-Usua! Cost-Effectiveness 2015
Total Resource Cost Test (PTRC)
+ Conservation Adder so.04s 52,Ls4,87o 53,49s,3L2 sL,340,443 L.52
Total Resource Cost Test (TRC)
No Adder s0.049 52,Ls4,870 53,L77,557 $L,O22,687 7.47
Utility Cost Test (UCT)So.02s $L,L14,3G7 53,L77,557 S2,063,190 2.85
Rate lmpact Test (RlM)s4,459,805 53,L17,ss7 .sL,292,2491 o.77
Participant Cost Test (PCT)52,325,3Lt Ss,060,153 S2,733,8s3 2.18
Discounted Participant Payback
(years)3.37
Lifecycle Revenue lmpact
(s/KWh)s0.00004297
Table 17. tD Three-Year Business Plan: Business-as-UsualCost-Effectiveness 2015
Total Resource CostTest (PTRC)
+ Conservation Adder So.oas S2,016,120 s3,409,603 S1,393,483 1.69
Total Resource CostTest (TRC)
No Adder So.o+s 52,oL6,t2o s3,099,639 S1,083,s19 L.54
Utility Cost Test (UCl')So.02s 5L,o42,6L4 s3,099,539 s2,0s7,ozs 2.97
Rate lmpact Test (RlM)54,24t,649 s3,099,639 (s1,142,010)0.73
Participant Cost Test (PCT)52,L76,522 s4,810,333 S2,633,811 2.2L
Discounted Participant Payback
(years)4.30
Lifecycle Revenue lmpact
(s/KWh)s0.00003s99
720 SW Washington Street
suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone] L2
Rocky Mountain Power
Exhibit No. 2 Page 13 of 31
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Table 18. lD Three-Year Business Plan: Business-as-Usual Cost-Effectiveness 2017
Total Resource CostTest (PTRC)
+ Conservation Adder s0.049 s1,886,305 53,346,069 s1,459,765 L.7'1
Total Resource CostTest (TRC)
No Adder So.o49 s1,996,305 s3,041,891 S1,155,576 1.61
Utility Cost Test (Ufi)So.02s s97s,482 s3,041,881 s2,066,400 3.L2
Rate lmpact Test (RlM)$4,025,402 s3,041,981 (s983,521)o.76
Participant Cost Test (PCT)52,036,379 s4,s73,047 s2,s35,668 2.25
Discounted Participant Payback
(years)s.23
Lifecycle Revenue lmpact
(s/KWh)s0.000029s4
Table 19. tD Three-Year Business Plan: Business-as-Usual Cost-Effectiveness 2OL5-2OL7
Total Resource Cost Test (PTRC)
+ Conservation Adder
50.049 S6,057,295 s10,250,985 s4,193,690 1.69
Total Resource Cost Test (TRC)
No Adder
So.oas S6,0s7,29s 59,319,077 53,26L,782 1.54
Utility Cost Test (Ufi)s0.02s S3,132,463 $9,319,077 s5,186,614 2.97
Rate lmpact Test (RlM)SLz,73G,8sl 59,319,077 1s3,4L7,780)o.73
Participant Cost Test (PCT)56,539,212 514,443,s44 s7,904,332 2.27
Discounted Participant Payback
(years)4.28
Lifecycle Revenue lmpact
(s/KWh)So.ooo1o26s
Table 20. lD lncrease EF Cost-Effectiveness 2015
Total Resource CostTest (PTRC)
+ Conservation Adder So.031 s20,353 ss4,806 s34,453 2.59
Total Resource CostTest (TRC)
No Adder So.oar s20,353 549,824 s29,47].?.45
Utility Cost Test (UCT)So.rog s71,183 549,824 (s21,359)0.70
Rate lmpact Test (RlM)S118,102 549,824 (s68,278)o.42
Participant Cost Test (PCT)S17,803 S119,393 S101,s89 6.77
Discounted Participant Payback
(years)0.2s
Lifecycle Revenue lmpact
(s/KWh)50.00000195
720 SW Washington Street
suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax:[phone]
Rocky Mountain Power
Exhibit No. 2Page 14 o13'l
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Table 21..aD lngease EF Cost-Effectiveness 2016
Total Resource Cost Test (PTRC)
+ Conservation Adder s0.031 s19,043 552,976 S33,933 2.78
Total Resource Cost Test (TRC)
No Adder So.osr s19,043 S48,160 s29,tL7 2.53
Utility Cost Test (UCT)So.rog s65,600 S48,160 (Sra,a+01 o.72
Rate lmpact Test (RlM)s111,331 s48,160 (s63,172)0.43
Participant Cost Test (PCT)s16,657 s1t2,542 s95,985 6.76
Discounted Participant Payback
(years)t.25
Lifecycle Revenue lmpact
(s/KWh)s0.0000017s
Table 22.|D lncrease EF Cost-Effectiveness 2017
Total Resource CostTest (PTRC)
+ Conservation Adder so.o31 sL7,8t5 SsL,432 S33,615 2.89
Total Resource CostTest (TRC)
No Adder So.osr s17,816 546,757 s28,940 2.62
Utility Cost Test (UCT)So.rog s62,3t2 s46,757 (s15,555)o.75
Rate lmpact Test (RlM)s104,9s8 546,7s7 (ss8,202)0.45
Participant Cost Test (PCT)s15,584 S106,283 Sgo,ogs 6.82
Discounted Participant Payback
(years)2.25
Lifecycle Revenue lmpact
(s/KWh)s0.000001ss
Table 23. lD Increase EF Cost-Effectiveness 2OL5-20t7
Total Resource CostTest (PTRC)
+ Conservation Adder So.osr 557,2L2 SLsg,2t4 s1o2,oo2 2.78
Total Resource CostTest (TRC)
No Adder so.031 5s7,zLz 5L44,740 s87,528 2.s3
Utility Cost Test (Ufi)So.rog s2oo,095 S:+q,tqo (S55,354)o.72
Rate lmpact Test (RlM)s334,392 sL44,740 (s189,651)0.43
Participant Cost Test (PCT)S5o,o44 s338,317 s288,273 6.76
Discounted Participant Payback
(years)0.25
Lifecycle Revenue lmpact
(s/KWh)s0.00000s06
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone] L4
Rocky Mounlain Power
Exhibit No. 2 Page 15 of 31
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Table 24.1D lncrease Agriculture System Re-design Cost-Effectiveness 2015
Total Resource CostTest (PTRC)
+ Conservation Adder So.oor s49,021 s65,248 5L6,227 1.33
Total Resource Cost Test (TRC)
No Adder So.051 S49,021 s59,317 s10,295 t.zt
Utility Cost Test (UCT)s0.096 s76,704 ssg,gtz (s17,388)o.77
Rate lmpact Test (RlM)S145,899 s59,317 (Sae,sss1 0.41
Participant Cost Test (PCT)s44,116 st43,LL4 s98,998 3.24
Discounted Participant Payback
(years)0.55
Lifecycle Revenue lmpact
(s/KWh)s0.00000430
Table 25. lD lncrease Agriculture System Re-design Cost-Effectiveness 2016
Total Resource CostTest (PTRC)
+ Conservation Adder So.oor 545,865 564,769 s18,904 t.4L
Total Resource CostTest (TRC)
No Adder so.051 s45,855 Ss8,881 S13,o1G L.28
Utility Cost Test (UCI)s0.0s6 571,765 Ss8,881 (s12,88s)0.82
Rate lmpact Test (RlM)s137,735 s58,881 (s78,854)0.43
Participant Cost Test (PCT)S4L,27s sL35,222 s93,945 3.28
Discounted Participant Payback
(years)1.54
Liferycle Revenue lmpact
(s/KWh)s0.000003s3
Table 26.|D lncrease Agriculture System Re-design Cost-Effectiveness 2017
Total Resource CostTest (PTRC)
+ Conservation Adder s0.061 54z,9Lz s63,998 s21,086 L.49
Total Resource Cost Test (TRC)
No Adder s0.061 542,9L2 s58,180 s15,258 1.36
Utility Cost Test (UCl')s0.096 567,L44 ss8,180 (S8,965)0.87
Rate lmpact Test (RlM)S130,039 s58,180 (s71,859)0.45
Participant Cost Test (PCT)s38,618 5L27,776 S89,1s8 3.31
Discounted Participant Payback
(years)2.54
Lifecycle Revenue lmpact
(s/KWh)s0.00000294
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 16 of 31
Case No. PAC-E-14-08
\Mtness: Kathryn C. Hymas
Table 27.lD lncrease Agriculture System Re-design Cost-Effectiveness 2OL5-20L7
Total Resource CostTest (PTRC)
+ Conservation Adder So.oor 5t37,798 S194,01s Ss6,216 L.4L
Total Resource CostTest (TRC)
No Adder So.osr sL37,798 s176,377 s38,s79 L.28
Utility Cost Test (UCT)so.0e5 s215,614 s176,377 (S39,237)0.82
Rate lmpact Test (RlM)s4t3,673 sL76,377 (s237,2951 0.43
Participant Cost Test (PCT)S124,ooe s406,111 5282,L02 3.27
Discounted Participant Payback
(years)0.55
Lifecycle Revenue lmpact
(s/KWh)s0.00000970
Table 28. lD Energy Management Offer Cost-Effectiveness 2015
Total Resource Cost Test (PTRC)
+ Conservation Adder So.ozs s27,694 525,794 (s1,900)0.93
Total Resource CostTest (TRC)
No Adder s0.073 527,694 523,449 (54,24s)0.8s
Utility Cost Test (UCT)so.os7 s21,s16 s23,449 s1,933 1.09
Rate lmpact Test (RlM)s46,184 523,449 lSzz,tl+1 0.51
Participant Cost Test (PCT)Sg,szs S30,148 s20,223 3.04
Discounted Participant Payback
(years)0.80
Lifecycle Revenue lmpact
(s/KWh)s0.00000149
Table 29. lD Energy Management Offer Cost-Effectiveness 2015
Total Resource CostTest (PTRC)
+ Conservation Adder So.o78 s59,690 ss3,644 (So,oao1 0.90
Total Resource CostTest (TRC)
No Adder So.o78 s59,590 s48,767 (s10,923)0.82
Utility Cost Test (UCT)So.062 547,769 $48,767 Sggg L.O2
Rate lmpact Test (RlM)s98,809 s48,767 (Sso,041)0.49
Participant Cost Test (PCT)s19,579 s62,37s s42,8oo 3.19
Discounted Participant Payback
(years)L.77
Lifecycle Revenue lmpact
(s/KWh)So.ooooo399
720 SW Washington Street
Suite 4oo
Portland, OR 97205
Voice: 503.467.7100
Fax:[phone]
Rocky Mountain Power
Exhibit No. 2 Page 17 ot 31
Case No. PAC-E-14-08
VMtness: Kathryn C. Hymas
Table 30. lD Energy Management Offer Cost-Effectiveness 2017
Total Resource CostTest (PTRC)
+ Conservation Adder So.oar s111,114 s98,209 (s12,905)0.88
Total Resource CostTest (TRC)
No Adder So.osr S111,114 S89,281 (s21,833)0.80
Utility Cost Test (UCI)So.066 s90,353 s89,281 (S1,072)0.99
Rate lmpact Test (RlM)5L8z,7Lz s89,281 (s93,432)0.49
Participant Cost Test (PCT)s34,s28 Su2,878 s78,350 3.27
Discounted Pa rticipant Payback
(years)2.75
Lifecycle Revenue lmpact
(s/KWh)s0.00000614
Table 31. lD Energy Management Offer Cost-Effectiveness 2OL5-20L7
Total Resource CostTest (PTRC)
+ Conservation Adder So.ozg S198,498 5177,647 (S20,851)0.89
Total Resource Cost Test (TRC)
No Adder s0.079 s198,498 5L6L,497 (S37,001)0.81
Utility Cost Test (UCT)s0.053 s159,538 s16L,497 S1,860 1.01
Rate lmpact Test (RlM)s327,705 sL6L,497 (s166,207)0.49
Participant Cost Test (PCT)s64,032 s20s,40s 5L41,373 3.27
Discounted Participant Payback
(years)0.80
Lifecycle Revenue lmpact
($/KWh)s0,00001093
Table 32. lD Pay for Commissioning Cost-Effectiveness 2015
Total Resource CostTest (PTRC)
+ Conservation Adder So.oss 546,ss8 Su6,333 559,774 2.s0
Total Resource CostTest (TRC)
No Adder s0.033 s46,ss8 s10s,7s7 s59,199 2.27
UtiliW Cost Test (UCT)s0.019 526,487 S1os,7s7 s79,27O 3.99
Rate lmpact Test (RlM)5L26,O77 s105,757 (s20,320)0.84
Participant Cost Test (PCT)s43,091 s130,179 s87,088 3.02
Discounted Participant Payback
(years)2.53
Lifecycle Revenue lmpact
(s/KWh)s0.000000s8
720 5W Washington Street
suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax:[phone]
Rocky Mountain Power
Exhibit No. 2 Page 18 of 31
Case No. PAC-E-14-08
\Mtness: Kathryn C. Hymas
Table 33. !D Pay for Commissioning Cost-Effectiveness 2016
Total Resource CostTest (PTRC)
+ Conservation Adder So.o33 S43,561 SLtz,448 s68,887 2.58
Total Resource Cost Test (TRC)
No Adder so.o33 s43,s61 5Lo2,zzs Ss8,65s 2.35
Utility Cost Test (Ufi)so.01s 524,781 5t02,225 577,444 4.L3
Rate lmpact Test (RlM)s119,730 5t02,225 (s17,504)0.8s
Participant Cost Test (PCT)s40,315 5123,786 s83,470 3.07
Discounted Participant Payback
(years)3.48
Lifecycle Revenue lmpact
(s/KWh)s0.00000048
Table 34. lD Pay for Commissioning Cost-Effectiveness2OtT
Total Resource CostTest (PTRC)
+ Conservation Adder s0.033 s40,7s6 s109,171 s68,415 2.68
Total Resource CostTest (TRC)
No Adder $o.ose s40,756 s99,245 ss8,491 2.44
Utility Cost Test (UCT)So.o19 s23,185 s99,246 s76,051 4.28
Rate lmpact Test (RlM)s113,708 599,246 (S14,462)0.87
Participant Cost Test (PCT)s37,720 5tL7,712 s79,992 3.12
Discounted Participant Payback
(years)4.43
Lifecycle Revenue lmpact
(s/KWh)s0.00000039
Table 35. !D Pay for Commissioning Cost-Effectiveness2OLS-2OL7
Total Resource Cost Test (PTRC)
+ Conservation Adder so.o33 S130,87s s337,9s2 5207,077 2.58
Total Resource Cost Test (TRC)
No Adder s0.033 S130,87s 5307,229 s176,3s4 2.3s
Utility Cost Test (UCI)so.o1s 574,454 5307,229 5232,77s 4.13
Rate lmpact Test (RlM)s359,515 $3O7,229 .552,2871 0.85
Participant Cost Test (PCT)Stzt,tzt 537L,576 s250,549 3.07
Discounted Participant Payback
(years)3.46
Lifecycle Revenue lmpact
(s/KWh)s0.00000140
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 19 of 31
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Table 36. lD Commercial Food Service Cost-Effectiveness 2015
Total Resource CostTest (PTRC) +
Conservation Adder s0.001 s216 szs,746 s25,530 tLg.34
Total Resource CostTest (TRC) No
Adder So.oor Szre s23,405 S23,190 108.49
Utility Cost Test (UCT)so.oo3 Sg+g s23,405 s22,457 24.66
Rate lmpact Test (RlM)s29,635 s23,405 (56,229)o.79
Participant Cost Test (PCT)(S4,u8)s40,749 s44,927 0.00
Discounted Participant Payback
(years)N/A
Lifecycle Revenue lmpact
(s/KWh)s0.00000021
Table 37. lD Commercial Food Service Cost-Effectiveness 2016
Total Resource Cost Test (PTRC) +
Conservation Adder So.oo1 Sszs S2s,5oo 52s,222 67.8L
Total Resource Cost Test (TRC) No
Adder So.oor Sszs 523,272 522,8es 61.65
Utility Cost Test (UCf)So.oo3 Sszo 523,272 s22,296 23.85
Rate lmpact Test (RlM)s28,560 s23,272 (Ss,388)0.81
Participant Cost Test (PCT)(S3,698)s39,440 S43,138 0.00
Discounted Participant Payback
(years)N/A
Lifecycle Revenue lmpact
(s/KWh)s0.00000017
Table 38. !D Commercial Food Service Cost-Effectiveness 2017
Total Resource CostTest (PTRC) +
Conservation Adder So.ozo S6,sos s29,899 s22,994 4.33
Total Resource CostTest (TRC) No
Adder So.ozo S5,eos 527,!8L s20,275 3.94
Utility Cost Test (UCT)So.oo8 S2,8u s27,tgL s24,370 9.67
Rate lmpact Test (RlM)s34,555 527,L8t ls7,47sl 0.78
Participant Cost Test (PCT)S5,496 547,L17 s41,622 8.57
Discounted Participant Payback
(years)3.L7
Lifecycle Revenue lmpact
(s/KWh)s0.00000022
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 20 ot 3'l
Case No. PAC-E-'14-08
Vvitness: Kathryn C. Hymas
Table 39. lD Commercial Food Service Cost-Effectiveness 2OL5-2OL7
Total Resource CostTest (PTRC) +
Conservation Adder s0.008 s7,498 581,244 s73,746 10.83
Total Resource CostTest (TRC) No
Adder So.oos s7,498 S73,8ss s66,360 9.85
Utility Cost Test (UCT)So.oos 54,736 s73.8s9 s69,123 15.60
Rate lmpact Test (RlM)Se2,sso S73,8se (S19,092)o.79
Participant Cost Test (PCT)(s2,381)sL27,306 sL29,687 0.00
Discounted Participant Payback
(years)N/A
Lifecycle Revenue lmpact
(s/KWh)s0.000000s7
Table 40. lD Commercial HVAC Cost-Effectiveness 2015
Total Resource CostTest (PTRC) +
Conservation Adder So.oes s15,o8o S18,34s s3,264 L.22
Total Resource CostTest (TRC) No
Adder So.o66 s15,080 s16,677 s1,597 L.17
UtiliW Cost Test (UCT)So.o30 s6,843 s16,677 s9,834 2.44
Rate lmpact Test (RlM)527,282 516,677 (s10,605)0.51
Participant Cost Test (PCT)S1s,3o2 S3s,2o1 S1s,8ee t.82
Discounted Participant Payback
(years)4.9t
Lifecycle Revenue lmpact
(s/KWh)s0.0000003s
Table 41. lD Commercial HVAC Cost-Effectiveness 2016
Total Resource CostTest (PTRC) +
Conservation Adder So.ooo S14,807 s18,901 s4,094 L.28
Total Resource CostTest (TRC) No
Adder So.oeo Sra,soz s17,183 52,376 L.L6
Utility Cost Test (UCT)So.o30 S6,842 S17,183 s10,34o 2.57
Rate lmpact Test (RlM)527,282 S17,183 (s10,100)0.63
Participant Cost Test (PCT)S18,954 $35,242 s16,288 1.86
Discounted Participant Payback
(years)5.76
Lifecycle Revenue lmpact
(s/KWh)s0.00000032
720 5W Washington Street
Suite 4oo
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 21 ot 31
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Table 42.|D Commercial HVAC Cost-Effectiveness 2017
Total Resource CostTest (PTRC) +
Conservation Adder s0.066 S14,631 s19,304 54,573 1.32
Total Resource CostTest (TRC) No
Adder So.056 S14,631 Srz,s+g S2,918 7.20
Utility Cost Test (UCr)So.osr S6,8s8 5L7,s49 s10,5s1 2.54
Rate lmpact Test (RlM)s27,459 s17,549 (Ss,e10)0.54
Participant Cost Test (PCT)518,731 S3s,s04 sL6,773 1.90
Discounted Participant Payback
(years)6.62
Lifecycle Revenue lmpact
(s/KWh)s0.00000030
Table 43. lD Commercial HVAC Cost-Effectiveness 2OL5-2OL7
Total Resource CostTest (PTRC) +
Conservation Adder s0.066 s44,518 Ss6,sso S12,031 L.27
Total Resource Cost Test (TRC) No
Adder So.065 S44.s18 s51,409 s6,890 1.15
Utility Cost Test (UCT)So.o3o s20,s84 Ss1,4o9 s30,825 2.50
Rate lmpact Test (RlM)S82,023 Ss1,4o9 (S30,515)0.63
Participant Cost Test (PCT)s56,987 s105,947 s48,961 1.85
Discounted Participant Payback
(years)5.78
Lifecycle Revenue lmpact
(s/KWh)s0.00000092
Table 44. lD lndustrial Compressed Air Cost-Effectiveness 2015
Total Resource CostTest (PTRC) +
Conservation Adder so.0s3 s8,226 s13,016 54,790 1.58
Total Resource CostTest (TRC) No
Adder s0.0s3 58,226 s11,833 s3,507 L.44
UtiliW Cost Test (UCT)So.031 s4,800 S11,833 S7,033 2.47
Rate lmpact Test (RlM)s14,840 s11,833 (Se,ooa1 0.80
Participant Cost Test (PCT)St,zzo s14,281 s7,061 1.98
Discounted Participant Payback
(years)4.45
Lifecycle Revenue lmpact
(s/KWh)s0.00000009
720 SW Washington Street
Suite 4oo
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]t
Rocky Mountain Power
Exhibit No. 2 Page 22 ot 3'l
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Table 45. lD lndustria! Compressed Air Cost-Effectiveness 2016
Total Resource CostTest (PTRC) +
Conservation Adder So.os:s7,696 s12,s81 S4,885 1.63
Total Resource CostTest (TRC) No
Adder So.os3 57,696 s11,438 53,74L L.49
Utility Cost Test (UCf)So.031 s4,491 s11,438 56,947 2.55
Rate lmpact Test (RlM)s14,063 s11,438 (s2,6261 0.81
Participant Cost Test (PCT)s5,755 s13.s62 s5,807 2.0L
Discounted Participant Payback
(years)5.36
Lifecycle Revenue lmpact
(s/KWh)s0.00000007
Table 46. lD lndustria! Compressed Air Cost-Effectiveness2OLT
Total Resource CostTest (PTRC) +
Conservation Adder s0.0s3 s7,2O7 5L2,2t5 s5,014 L.70
Total Resource Cost Test (TRC) No
Adder so.os3 s7,zot s11,104 s3,904 1.54
Utility Cost Test (UCr)So.osr s4,202 s11,104 s5,902 2.64
Rate lmpact Test (RlM)s13,328 s11,104 (s2,2241 0.83
Participant Cost Test (PCT)S6,320 s12,880 So,soo 2.O4
Discounted Participant Payback
(years)6.27
Lifecycle Revenue lmpact
(s/KWh)s0.00000006
Table 47. aD lndustrial Compressed Air Cost-Effectiveness 2OL5-2OL7
Total Resource CostTest (PTRC) +
Conservation Adder s0.0s3 s23,L23 537,8t2 s14,689 L.64
Total Resource CostTest (TRC) No
Adder s0.0s3 $23,L23 534,37s iLL,252 L.49
Utility Cost Test (UCT)So.031 S13,493 s34,37s s20,882 2.55
Rate lmpact Test (RlM)s42,232 S34.37s (s7,8s7)0.81
Participant Cost Test (PCT)520,295 s4O,724 520,429 2.01
Discounted Participant Payback
(years)5.35
Lifecycle Revenue lmpact
(s/KWh)s0.00000021
720 SW
Suite 400
Portland, OR 97205
Voice: 503.467.71 00
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 23 o131
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Table 48. lD lndustrial Potato Storage Fan VFD Cost-Effectiveness 2015
Total Resource CostTest (PTRC) +
Conservation Adder So.oas s11.501 s20,175 S8,s74 L.74
Total Resource CostTest (TRC) No
Adder So.o48 s11,601 s18,341 s6,740 1.58
Utility Cost Test (UCT)so.031 s7,44O s18,341 s10,901 2.47
Rate lmpact Test (RlM)s23,003 s18,341 (54,662)0.80
Participant Cost Test (PCT)$9,900 522,L36 sLz,236 2.24
Discounted Participant Payback
(years)3.50
Lifecycle Revenue lmpact
(s/KWh)so.0oooo013
Table 49. lD lndustrial Potato Storage Fan VFD Cost-Effectiveness 2015
Total Resource CostTest (PTRC) +
Conservatlon Adder So.oqs s10,854 s19,501 s8,647 1.80
Total Resource CostTest (TRC) No
Adder So.oaa s10,854 sL7,728 56,874 1.63
Utility Cost Test (UCT)So.oar s5,961 sL7,728 iLO,767 2.55
Rate lmpact Test (RlM)52t,798 5L7,728 (S4,o7o)0.81
Participant Cost Test (PCT)s9,263 SzL,o22 s11,759 2.27
Discounted Participant Payback
(years)4.43
Lifecycle Revenue lmpact
(s/KWh)s0.00000011
Table 50. lD lndustrial Potato Storage Fan VFD Cost-Effectiveness 2017
Total Resource CostTest (PTRC) +
Conservation Adder So.oqa s10,155 s18,933 58,778 1.85
Total Resource CostTest (TRC) No
Adder So.oqs s10,155 SL7,zLz s7,056 1.69
Utility Cost Test (UCT)So.osr So,srs SL7,zLz s10,699 2.64
Rate lmpact Test (RlM)s20,558 5L7,2tz (.s3,4471 0.83
Participant Cost Test (PCT)s8,556 s19,964 s11,298 2.30
Discounted Participant Payback
(years)s.36
Lifecycle Revenue lmpact
(s/KWh)So.ooooooog
720 SW
Suite 400
Portland, OR 97205
Voice: 503.467.71 00
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 24 ol 31
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Table 51. lD lndustrial Potato Storage Fan VFD Cost-Effectiveness 2OL5-2OL7
Total Resource CostTest (PTRC) +
Conservation Adder So.oaa s32,510 Ss8,6oe s2s.998 1.80
Total Resource CostTest (TRC) No
Adder s0.048 S32,610 s53,281 s2O,67O 1.63
Utility Cost Test (Ufi)So.031 s20,914 s53,281 s32,367 2.55
Rate lmpact Test (RlM)s55,459 Ss3,281 l5L2,L79l 0.81
Participant Cost Test (PCT)s27,829 563,L22 535,293 2.27
Discounted Participant Payback
(years)4.4L
Lifecycle Revenue lmpact
(s/KWh)s0.00000033
Table 52. ID lndustrialAdaptive Refrigeration Control Cost-Effectiveness 2015
Total Resource CostTest (PTRC) +
Conservation Adder So.oso s10,885 sLB,222 s7,335 L.67
Total Resource CostTest (TRC) No
Adder So.oso s10,885 s16,555 s5,680 L.52
Utility Cost Test (UCT)So.029 s6,420 s16,555 s10,146 2.58
Rate lmpact Test (RlM)520,477 s16,555 (s3,911)0.81
Participant Cost Test (PCT)s9,400 S19,694 s10,294 2.r0
Discounted Participant Payback
(years)4.L7
Lifecycle Revenue lmpact
(s/KWh)s0.00000011
Table 53. lD lndustrialAdaptive Refrigeration Control Cost-Effectiveness 2016
Total Resource Cost Test (PTRC) +
Conservation Adder s0.0s7 s16,525 s25,153 s8,538 L.52
Total Resource Cost Test (TRC) No
Adder s0.0s7 s16,525 s22,875 S6,3so 1.38
UtiliW Cost Test (UCT)s0.030 s8,701 522,87s 5L4,174 2.63
Rate lmpact Test (RlM)527,846 s22,87s (S+,szr1 0.82
Participant Cost Test (PCT)5L4,783 525,844 s12,051 1.82
Discounted Participant Payback
(years)5.33
Lifecycle Revenue lmpact
(s/KWh)s0.00000014
720 SW
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax:[phone]
Rocky Mountain Power
Exhibit No. 2 Page 25 ol 31
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Table 54. lD lndustrialAdaptive Refrigeration Control Cost-Effectiveness 2017
Total Resource CostTest (PTRC) +
Conservation Adder So.os9 5L8,427 s28,094 s9,667 1.52
Total Resource CostTest (TRC) No
Adder So.osg S$,qzt s25,540 S7,113 1.39
Utility Cost Test (UCI)So.oso s9,401 s25,540 S16,138 2.72
Rate lmpact Test (RlM)S30,392 S2s,s40 (s4,852)0.84
Participant Cost Test (PCT)516,632 529,362 512,730 L.77
Discounted Participant Payback
(years)7.63
Lifecycle Revenue lmpact
(s/KWh)s0.00000013
Table 55. !D lndustrialAdaptive Refrigeration ControlCost-Effectiveness 2OL5-20L7
Total Resource CostTest (PTRC) +
Conservation Adder so.os6 s45,837 s7t,479 525,542 1.56
Total Resource Cost Test (TRC) No
Adder So.oso Sas,sgz S64,981 Srg,uq L.42
Utility Cost Test (UCT)s0.030 s24,523 s64,981 S4o.4s8 2.65
Rate lmpact Test (RlM)5ts,tu S54,981 (s13,733)0.83
Participant Cost Test (PCT)S40,81s s7s,900 s3s,08s 1.85
Discounted Participant Payback
(years)6.26
Lifecycle Revenue lmpact
(s/KWh)s0.00000037
Table 56. !D lndustrial Fast Acting Door Cost-Effectiveness 2015
Total Resource Cost Test (PTRC) +
Conservation Adder So.o76 S18,9oo 520,826 Sr,szo 1.10
Total Resource Cost Test (TRC) No
Adder so.o76 S18,soo S18,932 s32 1.00
Utility Cost Test (UCI)So.osr s7,580 s18,932 sl,t,252 2.47
Rate lmpact Test (RlM)523,745 s18,932 (54,812)0.80
Participant Cost Test (PCT)S18,ooo s22,850 s4,8s0 7.27
Discounted Participant Payback
(years)9.81
Lifecycle Revenue lmpact
(S/KWh)s0.00000014
720 SW
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax:[phone]
Rocky Mountain Power
Exhibit No. 2 Page 26 of 31
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Table 57. !D lndustrial Fast Acting Door Cost-Effectiveness 2016
Total Resource CostTest (PTRC) +
Conservation Adder So.o75 s17,683 s20,130 52,447 L,L4
Total Resource CostTest (TRC) No
Adder So.076 s17,583 s18,3oo Ssrz 1.03
Utility Cost Test (UCr)So.031 s7,195 s18,300 s11,115 2.55
Rate lmpact Test (RlM)522,50L s18,3oo (s4,201)0.81
Participant Cost Test (PCT)s15,841 52L,70O s4,8s9 t.29
Discounted Participant Payback
(years)10.58
Lifecycle Revenue lmpact
(s/KWh)s0.00000012
Table 58. lD lndustrial Fast Acting Door Cost-Effectiveness?:OLT
Total Resource Cost Test (PTRC) +
Conservation Adder so.o75 s16,s44 S19,544 s2,999 1.18
Total Resource Cost Test (TRC) No
Adder s0.076 s16,544 5L7,767 sL,222 L.07
Utility Cost Test (UCr)s0.031 s6,723 5L7,767 s11,044 2.64
Rate lmpact Test (RlM)52L,325 5L7,757 (S3,558)0.83
Participant Cost Test (PCT)sLs,757 s20,608 s4,8s2 1.31
Discounted Participant Payback
(years)11.36
Lifecycle Revenue lmpact
(s/KWh)s0.00000010
Table 59. lD lndustrial Fast Acting Door Cost-Effectiveness2OLS-20L7
Total Resource CostTest (PTRC) +
Conservation Adder s0.075 Ssg,rzs s50,499 57,372 L.L4
Total Resource CostTest (TRC) No
Adder s0.075 ss3,128 ss4,999 5L,872 1.04
Utility Cost Test (UCT)s0.031 s21,588 s54,999 s33,411 2.s5
Rate lmpact Test (RlM)567,s71 Ss4,999 (s12,571)0.81
Participant Cost Test (PCT)s50,598 s65,158 s14,561 1.29
Discounted Participant Payback
(years)10.58
Lifecycle Revenue lmpact
(s/KWh)s0.00000034
720 SW
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 27 ot 31
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Table 60. lD Industrial End Use Compressed Air Reduction Cost-Effectiveness 2015
Total Resource CostTest (PTRC) +
Conservation Adder So.os2 S3,125 Sa,osz Sr.sgz 7.49
Total Resource Cost Test (TRC) No
Adder So.os2 s3,125 54,234 s1,109 1.35
Utility Cost Test (UCT)So.oqo s2,400 54,234 s1,834 L.76
Rate lmpact Test (RlM)s6,t27 s4,234 (s1,893)0.69
Participant Cost Test (PCT)S2,soo Ss,587 S3,187 2.27
Discounted Participant Payback
(years)1.99
Lifecycle Revenue lmpact
(s/KWh)s0.00000007
Table 51. lD lndustria! End Use Compressed Air Reduction Cost-Effectiveness 2016
Total Resource CostTest (PTRC) +
Conservation Adder So.os2 52,924 54,s23 Sr,sgs 1.55
Total Resource CostTest (TRC) No
Adder so.os2 s2,924 s4,tL2 s1,188 L.4t
Utility Cost Test (UCT)So.o+o s2,245 54,LL2 s1,856 1.83
Rate lmpact Test (RlM)S5,799 54,LLz (s1,687)0.71
Participant Cost Test (PCT)s2,339 Ss,396 Ss,osz 2.31
Discounted Participant Payback
(years)2.95
Lifecycle Revenue lmpact
(s/KWh)s0.00000006
Table 62. lD Industrial End Use Compressed Air Reduction Cost-Effectiveness 2017
Total Resource Cost Test (PTRC) +
Conservation Adder so.0s2 s2,736 s4,408 5L,672 1.61
Total Resource Cost Test (TRC) No
Adder So.os2 52,736 s4,007 5L,272 1.46
Utility Cost Test (UCI)So.o4o 52,101 s4,oo7 S1,s05 1.91
Rate lmpact Test (RlM)s5,488 s4,007 (s1,481)0.73
Participant Cost Test (PCT)s2,1gg S5,119 s2,931 2.34
Discounted Participant Payback
(years)3.92
Lifecycle Revenue lmpact
(s/KWh)s0.0000000s
720 SW
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax:[phone]
Rocky Mountain Power
Exhibit No. 2 Page 28 ot 31
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Table 63. lD lndustrial End Use Compressed Air Reduction Cost-EffectivenessZ,OLS-2OLT
Total Resource CostTest (PTRC) +
Conservation Adder s0.0s2 s8,784 s13,s88 s4,803 1.55
Total Resource CostTest (TRC) No
Adder so.os2 s8,784 S12,3s3 S3,s68 t.4L
Utility Cost Test (UCT)s0.040 Sa,tqa S12,3s3 Ss,ooo 1.83
Rate lmpact Test (RlM)SL7,4L4 s12,353 (S5,061)0.7L
Participant Cost Test (PCT)s7,027 st6,2O2 59,L75 2.3L
Discounted Participant Payback
(years)2.97
Lifecycle Revenue lmpact
(s/KWh)s0.00000017
Table 64. !D lndustrialWastewater Mixing Grid Bee Cost-Effectiveness 2015
Total Resource CostTest (PTRC) +
Conservation Adder so.o52 s38,3s0 s52,064 5t3,714 1.36
Total Resource CostTest (TRC) No
Adder so.o52 S38,3so s47,331 S8,s81 L.23
Utility Cost Test (UCT)s0.031 S19,2oo s47,331 S28,131 2.47
Rate lmpact Test (RlM)ss9,362 s47,331 (s12,031)0.80
Participant Cost Test (PCT)s3s,ooo Ss7,t2s s22,L25 1.53
Discounted Participant Payback
(years)6.33
Lifecycle Revenue lmpact
(s/KWh)s0.0000003s
Table 65. lD lndustrialWastewater Mixing Grid Bee Cost-Effectiveness 2016
Total Resource CostTest (PTRC) +
Conservation Adder So.062 s35,881 s50,325 5L4,445 L.40
Total Resource CostTest (TRC) No
Adder So.062 S3s,881 s45,750 s9,870 L.28
Utility Cost Test (UCT)So.031 s17,954 S4s,7so s27,787 2.55
Rate lmpact Test (RlM)s55,253 s4s,7s0 (Sro,soal 0.81
Participant Cost Test (PCT)532,746 5s4,249 s21,503 1.65
Discounted Participant Payback
(years)7.19
Lifecycle Revenue lmpact
(s/KWh)s0.00000029
720 5W
suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax:[phone]
Rocky Mountain Power
Exhibit No. 2 Page 29 ot 31
Case No. PAC-E-I4-08
Vvitness: Kathryn C. Hymas
Table 66. lD lndustrialWastewater Mixing Grid Bee Cost-Effectiveness 2017
Total Resource CostTest (PTRC) +
Conservation Adder s0.062 s33,570 s48,8s9 s1s,288 L.46
Total Resource CostTest (TRC) No
Adder So.ooz S33,s70 544,4L7 iLO,847 7.32
Utility Cost Test (UCI)So.osr s16,807 544,4L7 527,6LO 2.64
Rate lmpact Test (RlM)s53,312 s44,4L7 (S8,8ss)0.83
Participant Cost Test (PCT)s30,638 s51,521 s20,883 1.58
Discounted Participant Payback
(years)8.06
Lifecycle Revenue lmpact
(s/KWh)s0.00000024
Table 57. lD !ndustrialWastewater Mixing Grid Bee Cost-Effectiveness 2O15-20t7
Total Resource CostTest (PTRC) +
Conservation Adder s0.062 S107,801 s151,248 $43,447 1.40
Total Resource CostTest (TRC) No
Adder so.062 S107,801 S137,498 s29,697 7.28
Utility Cost Test (UCT)so.o31 Ssg,gzr s137,498 s83,527 2.55
Rate lmpact Test (RlM)sL68,927 s137,498 (S31,428)0.81
Participant Cost Test (PCT)ss8,384 s162,896 s64,511 1.66
Discounted Participant Payback
(years)7.18
Lifecycle Revenue lmpact
(s/KWh)s0.00000084
Table 68. !D Small Business Cost-Effectiveness 2015
Total Resource CostTest (PTRC) +
Conservation Adder so.o7s 591,os4 59L,774 Stzo 1.01
Total Resource CostTest (TRC) No
Adder So.07e s91,0s4 s83,431 (s7,523)0.92
Utility Cost Test (UCT)So.oz+S84,387 s83,431 (5ss7)0.99
Rate lmpact Test (RlM)S18G,o4o 583,431 (S103,209)0.45
Participant Cost Test (PCT)s56,668 s156,948 s100,280 2.so
Discounted Participant Payback
(years)1.10
Lifecycle Revenue lmpact
(s/KWh)s0.00000343
720 SW
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Rocky Mountain Power
Exhibit No. 2 Page 30 of 31
Case No. PAC-E-14-08
VMtness: Kathryn C. Hymas
Table 69. !D Small Business Cost-Effectiveness 2016
Total Resource CostTest (PTRC) +
Conservation Adder So.oos 5327,287 s399,215 571,929 1.22
Total Resource CostTest (TRC) No
Adder So.oos 5327,287 5362,924 s35,637 1.11
Utility Cost Test (UCl')So.oss 5299,664 s362,924 s63,260 t.2t
Rate lmpact Test (RlM)s731.388 5362,924 (s358,464)0.50
Participant Cost Test (PCT)5276,234 s700,680 ;424,446 2.54
Discounted Participant Payback
(years)2.08
Lifecycle Revenue lmpact
(s/KWh)s0.00001161
Table 70. lD Small Business Cost-Effectiveness 2017
Total Resource CostTest (PTRC) +
Conservation Adder So.osz S491,023 s635,765 5144,742 L.29
Total Resource CostTest (TRC) No
Adder So.osz s491.023 ss77,969 S86,94s 1.18
Utility Cost Test (UCT)So.osr s448.s04 5577,969 5L29,464 t.29
Rate lmpact Test (RlM)S1,125,653 s577,969 (s547,585)0.51
Participant Cost Test (PCT)s42s,L87 s1,092,537 s557,3s0 2.57
Discounted Participant Payback
(years)3.06
Lifecycle Revenue lmpact
(s/KWh)s0.0000164s
Table 71.1D Small Business Cost-Effectiveness 2OL5-2OL7
Total Resource CostTest (PTRC) +
Conservation Adder So.osg S909,364 5L,L26,756 s2t7,39L t.24
Total Resource CostTest (TRC) No
Adder s0.069 s909,364 sL,024,323 Su4,959 1.13
UtiliW Cost Test (UCT)So.oos s832,ss5 5L,O24,323 s191,768 1.23
Rate lmpact Test (RlM)s2,043,690 St,oz4,3z3 (s1,019,3s7)0,50
Participant Cost Test (PCT)S768,089 S1,9G0,165 $t,tg2,o7G 2.55
Discounted Participant Payback
(years)1.98
Lifecycle Revenue lmpact
(s/KWh)s0.00003052
720 SW
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax:[phone]
Rocky Mountain Power
Exhibit No. 2 Page 31 of 31
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
720 SW Washington Street
Suite 400
Portland, OR 97205
Voice: 503.467.7100
Fax: [phone]
Case No. PAC-E-14-08
Exhibit No. 3
Witness: Kathryn C. Hymas
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Testimony of Kathryn C. Hymas
Flexible Tariff Format - Change Process - Idaho
August 2014
Rocky Mountain Power
Exhibit No. 3 Page '1 of '1
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Exhibit 3
Rocky Mountain Power Flexible Tariff Format - Change Process - Idaho
This process applies to specific program details managed outside of the program tariffsuch as:o Incentive tables
. Program definitions
r General incentive information
Identify need for
change
. Incentive amounto Elieible eouioment
Prepare program change proposal
. Program details with marked changes
r Explanation for changes
o Cost effectiveness analysis (ifchanges impact cost
efTectiveness)
Provide proposal, supporting documents
and request comments
. Provide program change proposal
. Request comments fiom Commission staff
o Define comment period
Review proposal, provide
comments
Request a meeting/call to discuss the
proposal (if needed)
. Incorporate comments as appropriate, prepare final
program details and explanation for changes
o Provide response to comments to Commission staff (lf no
comments or all comments have been resolved the
Company will proceed with the proposed changes)
Post change notice on website
. Post change notice on website including final program
details with marked changes and explanation for changes
o Communicate changes to Commission staffand others
. Changes effective 45 days from posting date
o lmolement chanses
Receive final changes
e Lrnk to notice on the website
o Final program details with changes
marked and explanation for changes
. Response to any comments
o Eff'ective date for chanses
Case No. PAC-E-14-08
Exhibit No. 4
Witness: Kathryn C. Hymas
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Testimony of Kathryn C. Hymas
Electric Service Schedule 140 -Non-Residential Energy Efficiency
August 2014
-ROCKYMOUNTAINxcPol tER
\ ADlvTSloNOf mclHOOfiP
I.P.U.C. No. I
Rocky Mountain Power
Exhibit No. 4 Page 1 oI27
Case No. PAC-E-14-08
VMlness: Kathryn C. Hymas
Eleventh Revision of Sheet No. B.2
Canceling Tenth Revision of Sheet No. B.2
Schedule
No.
23
23A
24
3l
34
35
35A
36
70
71
73
94
117
118
ELECTRIC SERVICE SCHEDULES - Continued
Class of Service
General Service - Small Power
General Service - Small Power (Residential and Farm)
Interruptible Power Service
Partial Requirements Service - High Voltage
Pacific Northwest Electric Power Planning and Conservation Act -
Residential and Farm Kilowatt-Hour Credit
Optional Time-of-Day General Service - Distribution Voltage
Optional Time-of-Day General Service - Distribution Voltage (Farm)
Optional Time of Day Residential Service
Renewable Energy Rider - Optional
Energy Exchange Pilot Program
Renewable Energy Rider - Optional - Bulk Purchase Option
Energy Cost Adjustment
Residential Refrigerator Recycling Program
Home Energy Saver Incentive Program
(Continued)
Sheet
No.
23.1-23.3
234.1-234.4
24.1 - 24.s
31.r -3r.6
34.1 - 34.3
35.r - 35.3
35A.1 -35A.4
36.1 - 36.3
70.1 - 70.4
71.1 - 71.6
73.1-73.4
94.1
tt7.t - 117.2
il8.1 - 118.2
Submitted Under Case No. PAC-E-14-08
ISSUED: August 22,2014 EFFECTM: November 1, 201 4
I.P.U.C. No. I
ROCKY MOUNTAIN
POWER
A OMSIOT{ Of PAOTlcOnP
Rocky Mountain Power
Exhibit No. 4 Page 2 ol 27
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Fifth Revision of Sheet No. B.3
Canceling Fourth Revision of Sheet No. 8.3
Schedule
No.
ELECTRIC SERYICE SCHEDULES - Continued
Class of Service
Sheet
No.
135.1 - 135.3
140.1 - r40.3
l9l
300.1 - 300.4
400.1
401.1
135 Net Metering Service
140 Non-Residential Energr Efficiency
l9l Customer Efficiency Services Rate Adjustment
300 Regulation Charges
400 Special Contract
401 Special Contract
Schedule numbers not listed are not currently used.* These schedules are not available to new customers or premises.
Submitted Under Case No. PAC-E-14-08
ISSUED: August 22,2014 EFFECTM: November l, 2014
V,ROCKYMOUNTAINYPwyER\ A uvrsoil oF PActFEonP
I.P.U.C. No. I
Rocky Mountain Power
Exhibit No. 4 Page 3 ot 27
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Original Sheet No. 140.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 140
STATE OF IDAHO
Non-Residential Energy Elficiency
PURPOSE: Service under this Schedule is intended to maximize the efficient utilization of
the electricity requirements of new and existing loads in Non-residential Facilities through the
installation of Energy Efficiency Measures and energy management protocols. Service under this
Schedule is subject to funding availability.
APPLICABLE: To service under the Company's General Service Schedules 6, 6A, 7, 7 A, 9,
10,12,19,23,23A,24,35 and 35A in all territory served by the Company in the State of ldaho. This
Schedule is applicable to new and existing Non-residential Facilities and dairy barns served under the
Company's residential rate schedules.
CUSTOMER PARTICIPATION: Customer participation is voluntary and is initiated by
following the participation procedures on the ldaho energy efliciency program section of the
Company website, and available to customers without online access upon request. The Company
shall have the right to qualiff participants, at its discretion, based on criteria the Company considers
necessary to ensure the effective operation of the measures and utility system. Criteria may include,
but will not be limited to cost effectiveness.
DESCRIPTION: Ongoing program to provide incentives for a variety of equipment and
operational improvements intended for and located in Non-residential Facilities. Periodic program
changes will be made to encourage customer participation in the program and to insure or enhance
program cost-effectiveness as defined by the Company.
QUALIF"YING MEASURE: Measures which when installed in an eligible facility result in
verifiable electric energy efficiency improvement compared to existing equipment or baseline
equipment as defined by the Company. The baseline will be determined with reference to existing
equipment, applicable state or federal energy codes, industry standard practice and other relevant
factors.
QUALIFYING ENERGY MANAGEMENT:
Operational improvements which when implemented in an eligible facility result in verifiable electric
energy savings compared to standard operations as determined by the Company.
(Continued)
Submitted Under Case No. PAC-E-14-08
ISSUED: August 22,2014 EFFECTM: November l, 2014
V,.ROCKY MOUNTAINYTPOWER
\ awrsronormqflcoRP
I.P.U.C. No. I
Rocky Mountain Power
Exhibit No. 4 Page 4 ot 27
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Original Sheet No. 140.2
ELECTRICAL SERVICE SCHEDULE NO. 140 (Continued)
PROYISIONS OF SERYICE:
(l) Qualiffing equipment or services, incentive amounts and other terms and conditions will
be listed on the Idaho energy efficiency program section of the Company website, and
are available to customers without online access upon request. Program changes may be
made by the Company with at least 45 days advanced notice. Such changes will be
prominently displayed on the Idaho energy efficiency program section of the Company
website and include a minimum 45 days for processing prior offers.
(2) Company may elect to offer enerry efliciency measure (*EEM") incentives through
different channels and at different points in the sales process other than individual
Energy Efliciency Incentive Offer Letter(s) prior to EEM purchase. The differences will
depend on EEM and will be consistent for all EEMs of similar type.
(3) Incentives may be offered year-round or for selected time periods.
(4) Equipment or services receiving an incentive under this program are not eligible for
incentives under other Company programs.
(5) Company will employ a variety of quality assurance techniques during the delivery of
the program. They will differ by measure and may include pre- and post- installation
inspections, phone surveys, and confirmation of Owner/Customer and equipment
eligibility.
(6) Company may verifu or evaluate the energy savings of installed measures. This
verification may include a telephone survey, site visit, review of facility operation
characteristics, and pre- and post-installation of monitoring equipment as necessary to
quantiff actual enerry savings.
(7) Energy Project Manager co-funding is available according to the terms posted on the
Idaho energy efficiency program section of the Company website.
(8) Incentives will not be made available for fuel switching by Owner/Customer.
MNIMUM EOUIPMENT EFFICIENCY:
Retrofit energy efficiency projects must meet minimum equipment efficiency levels and
equipment eligibility requirements of qualiffing equipment that are listed on the Idaho
energy efficiency program section of the Company website.
(Continued)
EFFECTM: November l, 2014
Submitted Under Case No. PAC-E-I4-08
ISSUED: August 22,2014
Rocky Mountain Power
Exhibit No. 4 Page 5 ol 27
Case No. PAC-E-14-08
Wtness: Kathryn C. HymasROCKY MOUNTAIN
POWER
aoMsrof{of mon@at
I.P.U.C. No. I Original Sheet No. 140.3
ELECTRICAL SERYICE SCI{EDULE NO. 140 (Continued)
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and the
Company. The Electric Service Regulations of the Company on file with and approved by
the Idaho Public Utilities Commission, including future applicable amendments, will be
considered as forming a part of and incorporated in said Agreement.
Submitted Under Case No. PAC-E-14-08
ISSUED: August 22,2014 EFFECTryE: November 1, 2014
-,ROCKYMOUNTAINKpowen\ aousorc;^or'coae
I.P.U.C. No.1
Rocky Mountain Power
Exhibit No. 4 Page 6 ol27
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
+entbplevenlL Revision of Sheet No. 8.2
Canceling Ninthl&EliLRevision of Sheet No. B.2
Schedule
No.
23
234
24
3l
34
35
35A
36
70
7l
73
94
ELECTRIC SERVICE SCHEDULES - Continued
Class of Seruice
General Service - Small Power
General Service - Small Power (Residential and Farm)
Intemrptible Power Service
Partial Requirements Service - High Voltage
Pacific Northwest Electric Power Planning and Conservation Act -
Residential and Farm Kilowatt-Hour Credit
Optional Time-of-Day General Service - Distribution Voltage
Optional Time-of-Day General Service - Distribution Voltage (Farm)
Optional Time of Day Residential Service
Renewable Enerry Rider - Optional
Enerry Exchange Pilot Program
Renewable Enerry Rider - Optional - Bulk Purchase Option
Energr Cost Adjustment
Residential Refrigerator Recycling Program
Home Enerry Saver Incentive Program
Sheet
No.
23.1-23.3
234.1-234.4
24.1 - 24.5
3l.l -31.6
34.1-34.3
35.1 - 35.3
35A.1 -35A.4
36.1 - 36.3
70.1-70.4
7t.t -7t.6
73.1-73.4
94.1
I 15 FinAnswer Express I l5,l 115,2
n7
ll8
lt7.t - 1t7.2
ll8.l - 1r8.2
(Continued)
Submitted Under ffiase No. PAC-E-14-08
ISSUED: FFECTTVE:
I.P.U.C. No.1
ROCKY MOUNTAIN
POITi'ER
A Ovr3lon oF aAoFroofi?
Rocky Mountain Power
Exhibit No. 4 Page 7 ot 27
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
feu*tsElm nevision of Sheet No. B.3
Canceling Thir+FourtlL Revision of Sheet No. B.3
Schedule
No.
ELECTRIC SERVICE SCHEDULES - Continued
Class of Service
Sheet
No.
135.1 - 135.3
l9l
300.1 - 300.4
400.1
401.1
140 Non-Residential Energy Efficiency 140.1 - 140.3155 rlgrieulturd Enerry Serviees eptienal fer Qudiffing eusemers 155,1 155,6
135 Net Metering Service
401
Customer Efliciency Services Rate Adjustment
Regulation Charges
Special Contract
Special Contract
l9l
300
400
Schedule numbers not listed are not currently used.* These schedules are not available to new customers or premises.
Submitted Under ffiase No. PAC-E-14-08
ISSUED : MaYq,q++ p,ueust 2L20 1 a EF'F'ECTM: Aa*gustl5*el3November l. 20 I 4
ROCKY MOUNTAIN
POWER
ADMSION OF PAOTI@iP
Rocky Mountain Power
Exhibit No. 4 Page I ol27
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
LP.U.C. No. 1 Orisinal Sheet No. 140.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.14O
STATE OF IDAHO
Non-Residential Enerw Effi ciencv
PURPOSE: Service under this Schedule is intended to maximize the efficient utilization of
the electricity requirements of new and existing loads in Non-residential Facilities through the
installation of Energ.v Efficiency Measures and enerey management protocols. Service under this
Schedule is subject to funding availabilitv.
APPLICABLE: To service under the Company's General Service Schedules 6. 64. 7. 7A. 9.
10. 12. 19. 23. 23A. 24. 35 and 35A in all territory served by the Company in the State of Idaho. This
Schedule is applicable to new and existing Non-residential Facilities and dairy barns served under the
Company's residential rate schedules.
CUSTOMER PARTICIPATION: Customer oarticipation is voluntarv and is initiated bv
followins the oarticipation procedures on the Idaho energ.v efficiency program section of the
Company website. and available to customers without online access upon request. The Compan),
shall have the rieht to qualifr participants. at its discretion. based on criteria the Compan), considers
necessary to ensure the effective operation of the measures and utilitv system. Criteria may include.
but will not be limited to cost effectiveness.
DESCRIPTION: Ongoins program to provide incentives for a varietv of equipment and
operational improvements intended for and located in Non-residential Facilities. Periodic orosram
chanees will be made to encourage customer participation in the proeram and to insure or enhance
program cost-effectiveness as defined by the Company.
OUALIFYING ENERGY MANAGEMENT:
Operational improvements which when implemented in an eligible facility result in verifiable electric
enere.y savings compared to standard operations as determined by the Company.
(Continued)
Submitted Under Case No. PAC-E-14-08
ISSUED: Aueust 22.2014 EFFECTM: November 1.2014
ROCKY MOUNTAIN
POWER
aon,lsloilof aAcFrgoRP
Rocky Mountain Power
Exhibit No. 4 Page I oI27
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
ELECTRICAL SERVICE SCHEDULE NO. 140 (Continued)
PROYISIONS OF SERVICE:
(l) Oualitving equioment or services. incentive amounts and other terms and conditions will
be listed on the Idaho energy efficiency proeram section of the Company website. and
are available to customers without online access uoon request. Program changes may be
made by the Company with at least 45 days advanced notice. Such changes will be
prominently displayed on the Idaho energ.v efficiency proeram section of the Company
website and include a minimum 45 da)rs for orocessine orior offers.
(2) Company ma), elect to offer energy efficiency measure ("EEM") incentives throueh
different channels and at diflerent points in the sales process other than individual
Enerry Efficiency lncentive Offer Letter(s) prior to EEM purchase. The differences will
depend on EEM and will be consistent for all EEMs of similar tvoe.
(3) Incentives may be offered year-round or for selected time periods.
(4) Equipment or services receiving an incentive under this proeram are not elisible for
incentives under other Company programs.
(5) Company will employ a varietv of qualitv assurance techniques during the delivery of
the proeram. They will differ by measure and may include pre- and post- installation
inspections. phone surveys. and confirmation of Owner/Customer and equipment
eligibility.
(6) Company ma), verify or evaluate the enerKv savings of installed measures. This
verification may include a telephone survey. site visit. review of facilitv operation
characteristics. and pre- and post-installation of monitorine equipment as necessary to
quantifu actual energ.v savines.
(7) Enere.v Project Manager co-funding is available according to the terms posted on the
Idaho energv efficiency proeram section of the Company website.
(8) Incentives will not be made available for fuel switching by Owner/Customer.
MTNIMUM EOUIPMENT EFFICIENCY:
Retrofit enerey efficiency projects must meet minimum equipment efficiency levels and
equipment elieibility requirements of qualifring equipment that are listed on the Idaho
enerw efficiency program section of the Company website.
Submitted Under Case No. PAC-E-14-08
ISSUED: Aueust 22.2014 EFFECTM: November 1.2014
V,.ROCKY MOTJNTAIN(pgtirEp
\ eonrsrorormcracoif,
Rocky Mountain Power
Exhibit No. 4 Page'lO ot 27
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
I.P.U.C. No. I Orieinal Sheet No. 140.3
ELECTRICAL SERVICE SCHEDULE NO. 140 (Continued)
ELECTRIC SERYICE REGULATIONS: Service under this Schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and the
Compan)r. The Electric Service Resulations of the Company on file with and approved by
the ldaho Public Utilities Commission. including future applicable amendments. will be
considered as formine a part of and incomorated in said Agrcement.
Submitted Under Case No. PAC-E-14-08
ISSUED: Aueust 22.2014 EFFECTM: November 1.2014
ROCKY MOUNTAIN
POWER
ADfVmOilOf R SFTCORP
Rocky Mountain Power
Exhibit No. 4 Page 11 ol27
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Third Revision of Sheet No. 115.1
I.P.U.C. No. I Canceling Second Revision of Sheet No. 115.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 1I5
STATE OF IDAHO
FinAnswer Express
PURPOSE: Service under this Schedule is intended to lization
of the electricity requirements of new and existing loads in ndustrial
Facilities through the installation of Energy Efficiency
subject to funding availability.
APPLICABLE: To service under the
7A,9, 12, 19,23,23A,24,35 and 35A in all
Idaho. This Schedule is applicable to new
Facilities and dairy barns served under the
CUSTOMER PARTICIP
by following the participation on the
Company website, and avai
DESCRIPTION:
services intended for
program changes
Company.
schedules.
is voluntary and is initiated
efficiency program section of the
General
by
Schedule is
Schedules 6, 6A,7,
in the State of
and IndustrialBuildings
lne access upon request.
ide incentives for a variety of equipment and
buildings and industrial facilities. Periodic
or enhance program cost-effectiveness as defined by the
NT OR SERYICES: F4uipment or services which when
bligible facility result in verifiable electric energy efficiency
sting equipment or baseline equipment as defined by the Company.
(Continued)
QU
Submitted Under Case No. PAC-E-12-10
ISSUED: May 15,2012 EFFECTryE: July 14,2012
V,ROCKYMOUNTAINYpowee\ A O|VE|ON Of iAOfGORP
I.P.U.C. No. I
Rocky Mountain Power
Exhibit No. 4 Page 12 o'f 27
Case No. PAC-E-14-08
\Mtness: Kathryn C. Hymas
Second Revision of Sheet No. 115.2
Cancelinq First Revision of Sheet No. 115.2
ELECTRICAL SERVICE SCHEDULE NO. 115 (Continued)
PROVISIONS OF SERYICE:
(l) Qualiffing equipment or services, incentive amounts and other terms and conditions
will be listed on the Idaho energy efTiciency program section of the Company website,
and are available to customers without online access upon
may be made by the Company with at least 45 days advanced
will be prominently displayed on the Idaho energy
Company website and include a minimum 45 days for
(2) Company may elect to offer EEM incentives and at
different points in the sales process other than indivi Incentive
Agreement(s) prior to EEM purchase. The d!EEM and will
be consistent for all EEMs of similar type.
(3) Incentives may be offered year-rou
(4) Equipment or services receiv program arE not eligible for
incentives under other
(5) Company may offer the Idaho energy efficiency progam
section of the team members to encourage early initial
Company ustomer design and plans for New
C
(6) Company will a viilE$of quality assurance techniques during the delivery of
the ll differ by EEM and may include pre- and post- installation
, and confirmation of Owner/Customer and equipment
iff or evaluate the energy savings of installed EEMs. This
include a telephone survey, site visit, review of facility operation
and pre- and post-installation of monitoring equipment as necessary to
energy savings.
C SERVICE REGULATIONS Service under this Schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and
the Company. The Electric Service Regulations of the Company on file with and
approved by the Idaho Public Utility Commission, including future applicable
amendments, will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Case No. PAC-E-I2-10
ISSUED: May 15,2012
changes
EFFECTM: July 14,2012
V,ROCKYMOUNTAINYrcrwER\ A Onnsoir oF PAOACOftP
I.P.U.C. No. I
Rocky Mountain Power
Exhibit No. 4 Page 13 ot 27
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
First Revision of Sheet No. 125.1
Canceling Original Sheet No. 125.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.125
STATE OF IDAHO
Energy FinAnswer
PURPOSE: Service under this schedule is intended to max ion of
lities bythe electricity requirements of new and existing loads in
promoting the installation of Energy Efficiency Measures.
APPLICABLE: To service under the C
12, 19,23,23A,24,35 and 35A in all territory
Schedule is not applicable to existing
schedule is applicable to dairy barns served
footage is the total Building or Facility area
DEFINITIONS:
Annual kWh
installation of
6, 64, 8,9,
of Idaho. This
square feet. This
schedules. Square
The annual -hour (kWh) savings resulting from
enc Measures, as estimated by Company using
engineering analysis)
A ings: The Average Monthly kilowatt (kW) savings
estimated byresultinginstallation of Energy Efliciency Measures as
ing analysis as described below:
Savings = (baseline average monthly kW - proposed average
monthly kW = sum of the 12 Monthly Maximum kwl2, where;
ly Maximum kW = highest of all 15 minute average kW (as determined
).
= l5 minute average kW : sum of kWh used over 0.25 hrs/0.25 hrs
from'
using
=
(Continued)
EFFECTIV : May 1,2008
Submitted Under Advice No. 08-03
ISSUED: May 15,2008
ROCKY MOUNTAIN
POWER
A OnnsoN oFRAOFT@iP
Rocky Mountain Power
Exhibit No. 4 Page 14 ot 27
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Original Sheet No 125.2I.P.U.C. No.l
ELECTRIC SERVICE SCHEDULE NO l2s-Continued
DEFINITIONS: (continued)
Baseline Level:
Baseline Adjustments: Company may adjust
consumption and costs during engineering
following: energy codes, standard practice,
production or facility use and equipment
existing fixtures, baseline wattages
Efficiency Measures in all facilities shall be
or the energy efficiency
combination.
Commercial Building: A
applicability
energy
of the
m
For
Enerry
equipment
savings lamp
Company and meets the
time an Enerry Efficiency
Incentive not meet the definition of an
Industrial Facility.
verifring and documenting that the
meets the design intent andng systems
has applied for, been accepted and receives
, or is the electricity user at the real property.
Incentive: Payment of money made by Company to
for installation of an Energy Efficiency Project pursuant
Energy Efliciency Incentive Agreement.
Efliciency Incentive Agreement: An agreement between Owner or
and Company providing for Company to furnish Energy Efficiency
Schedule.
(Continued)
EFFECTM: May 1,2008
Submitted Under Case No. PAC-E-08-01
ISSUED: February 14, 2008
-ROCKYMOUNTAIN<PCit{ER\ A OMSTO| OF PACIFICORP
I.P.U.C. No. I
Rocky Mountain Power
Exhibit No. 4 Page '15 ot 27
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Original Sheet No. 125.3
ELECTRIC SERVICE SCHEDULE NO 125- Continued
DEFINITIONS: (continued)
Energy Efficiency Measure (EEM): Permanently installed
Energy Efficiency Incentive Agreement which can improve.
CustomeCs electric energy use. EEMs designed to
Monthly kW must also improve the electric energy
Energy Effi ciency Incentives.
Enerry Efliciency Measure @EM) Cost:
New construction: EEM Cost is the total
equipment or system minus the cost
equipment or system.
Major renovation: EEM Cost
equipment or system minus tb( cost
equipment or system.
Retrofit: EEM Cost is
modification.
ified in an
of the
verage
for
of the energy eflicient
iance/common practice
the energy efficiency equipment or
Buildings and process equipment associated with
(Continued)
In the case of renovation and retrofits, EEM Costs shall
mean the Owner or costs incurred (net of any discounts,
rebates than Efficiency Incentives from the Company, or
other the final actual EEM Cost incurred by the Owner or
Customer) to and install EEMs at the Owner or Customer's facility. If the
lls the EEM then the cost of installation shall be equal to
the 's actual labor costs for such installation.
Project: One or more EEM(s) covered by one Energy Efficiency
Annual kWh and Average Monthly kW savings for an Energy
shall be the sum of the individual EEM values.
Efficiency Project Cost: Energy Efficiency Project Cost shall be the sum
individual EEM costs.
Industrial Facility:
manufacturing.
Submitted Under Case No PAC-E-08-01
ISSUED: February 14, 2008 EFFECTM: May 1,2008
VROCKYMOUNTAIN
<PCTWER\ A DNlsroor OF PAOF|COftP
I.P.U.C. No. I
Rocky Mountain Power
Exhibit No. 4 Page 16 of 27
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Original Sheet No. 125.4
ELECTRIC SERVICE SCHEDULE NO. f25 - Continued
DEFII\IITIONS: (continued)
Mixed Use: Buildings served by a residential rate schedule and a
under Applicable shall be eligible for services under this
Energy Efficiency Project meets the definition of NewT
Renovation.
Nery Construction: A newly constructed
footage added to an existing facility.
INCENTIVES
faci
le listed
ided the
Major
square
Major Renovation: A change in facility use type or the system will
not meet owner/customer projected requi within footage.
Owner: The person who has both benefic to the real property
specified in an Energy Efficiency t is the mortgagor under
a duly recorded mortgage or deed of trust or a
purchaser under a duly to such real property.
Retrofit: Changes,systems or equipment in existing
facility square footage.
Supplemental
and Company
agreement between Owner or Customer
furnish Supplemental Services with respect
to Supplemental TariffSchedule.
PROJECTS:
tives: Energy Effrciency Incentives made by the Company
pursuant to an Energy Efficiency Incentive Agreement shall
lrum of (a) and (b) OR (c):
Wh for the Energy Efficiency Project Annual kWh savings as
ined using Company provided or approved engineering analysis;
$50/kW for Energy Efliciency Project Average Monthly kW savings
determined using Company provided or approved engineering analysis.
50% of the Energy Efliciency Project Cost as determined by the Company.
(Continued)
EFFECTM: May
Submitted Under Case No. PAC-E-08-01
ISSUED: February 14, 2008
ROCKY MOUNTAIN
POWER
A OrUSKlir OF RA0HOoaP
Rocky Mountain Power
Exhibit No. 4 Page 17 ot 27
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Original Sheet No. 125.5I.P.U.C. No.l
ELECTRIC SERVICE SCHEDULE NO. f2s-Continued
INCENTMS FOR ENERGY EFTICIENCY PROJECTS (continud)
below.Energy Efliciency Projects are eligible for Energy Efficiency lncenti CTable 1
Plogram track Deslgn
Asclstanca Standad .#i, ,,\\ ts[7
lard
ProJect Scope Comprehensive System , sv*eil[7) sv.t",
Type New Construction/
Major renoration
Narr Construdbny'l
Major renorra![1n Iru"r*#fri)/ Retrorrt
Energy ode
applies Yes {-,\./No
Enelgy
savlngs
threshold
Must exceed code by
10% - whole
building elecUk
basls dm(-):"
none
owner/Gusbmer Energy ,",(rrL$r"
""pc Jp,i b the Enersy Efridency Prciect
5O t)6 of
proiect @st
a-tn
No\^3--S/Yes Yes
I year simple
oaYback cao ilr I\ yes Yes Yes
llghUng
savings cap \1t* \50%50%50%
D""JA,,*f-IZ
llnorarium .Vo Yes Not avaihbh llot avaihble
ke ,* "" proJect size Not availabh Not available l,lot available
(Continued)
EFFECTM: May 1,2008
Submitted Under Case No. PAC-E-08-01
ISSUED: February 14,2008
-,ROCKYMOUNTAIN<PoIwER\ AOlvlSloilOFBOFI@fiP
I.P.U.C. No.1
Rocky Mountain Power
Exhibit No. 4 Page 18 ol27
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Original Sheet No. 125.6
ELECTRIC SERVICE SCHEDULE NO. 125 - Continued
INCENTMS FOR ENERGY ETTICIENCY PROJECTS: (continued)
All proposed Energy Effrciency Measure costs are subject tq
approval prior to offering an Energy Efiiciency Incentive
Efficiency Measure costs are subject to Company review and
Energy Effrciency Incentive per the terms of an Energy E
Company review and approval of Energy Efficiency
documentation from the Customer or Owner.
For the purposes of calculating maxi
lighting, electric savings nesulting from lighti
from lighting controls will be considered tq savings.
The ten percent whole
follows: The Energy
consumption by at least l0%
energy consumption that wou have resulted
gn shall
review and
Energy
an
resulting from
equipment and
90.1
The
ve only one financial incentive from the Company
include Energy Efliciency lncentive payments.
are available per Table I and the terms posted on the Idaho
of the Company web site.
(Continued)
baseline and proposed
Informative Appendix
the applicable ldaho
establish the
shall be calculated as
EStr re(ucllhe proposed electic energy
the basfirfe level of whole building electric
applicable ldaho energy code. The
led using the methodology defined in
or successor revision) using values from
of the building permit application shall
Customer
Submitted Under Case No. PAC-E-08-01
ISSUED: February 14, 2008 EFFECTM: May
V,ROCKYMOUNTAIN-(g;rl1Ep.
\ A CXVTSTO{i| OF RAdFICOfiP
LP.U.C. No. 1
Rocky Mountain Power
Exhibit No. 4 Page 19 ot 27
Case No. PAC-E-I4-08
\Mtness: Kathryn C. Hymas
Original Sheet No. 125.7
ELECTRIC SERVICE SCHEDULE NO. 125 - Continued
PROVISIONS OF SERVICE:
(l) Energy Analysis
Company shall meet with Customer or Owner and any design
an initial site visit/plans review to determine what EEMs may
energy analysis.
(2) Supplemental Senices
Company may offer Supplemental Services
Tariff Schedule through a Supplemental Serv
shall include, but are not limited to: detailerd design,
compliance documentation for green q( high
Company will negotiate the amount s of the
project specific basis and may
perform
for an
in this
servlces
calculations or
ilding standards.
servlces on a
llowing: installation of
EEMs delivering a certain offset of a portion of the
available incentive or direct (up to 100%) of the direct
Company costs for the seryi
(3)EEM Inspection
Company will i are funded by or installed under this
program. Sati pany will be required prior to receiving
Energy Efficiency ified in the Energy Efficiency Incentive
EEM
that)EEMs as specified in the Energy Efficiency Incentive
prior to receiving Energy Efficiency Incentives
Efficiency lncentive Agreement.
missioning Opt-Out: Required EEM Commissioning may be omitted
ing adjustments. Annual kWh savings, Average Monthly kW savings
EEM Costs will all be reduced by 20% and an Energy Efficiency
calculated using the provisions specified under Incentives for Energy
iency Projects. EEMs where the Owner or Customer has "opted--out" of EEM
Commissioning and are later commissioned are not eligible for an additional Energy
Efficiency Incentive after the Energy Efficiency Project Incentive is paid.
lof
(4)
EEMs
(4a)
with
and di
(Continued)
EFFECTryE: May 1,2008
Submitted Under Case No. PAC-E-08-01
ISSUED: February 14, 2008
-,,ROCKY
MOUNTAIN<P(lltER\ Aon/lSONOFmOFrCOfiP
I.P.U.C. No.l
Rocky Mountain Power
Exhibit No. 4 Page 20 of 27
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Original Sheet No. 125.8
ELECTRIC SERVICE SCHEDULE NO. 125 - Continued
PROVISIONS OF SERVICE: (continued)
(5) MeasurePerformanceVerification/Evaluation
Company may verifu or evaluate the energy savings of i
Measures specified in the Energy Efficiency Incentive
may include a telephone survey, site visit, review
and pre- and post-installation of monitoring
actual energy savings.
(6)Min imum Equipment Elliciency
For Retrofit Energy Efficiency minrmum equrpment
Schedule ll5 to beefficiency levels and equipment
eligible for incentives available
Enerry Efficiency Incen e to induce fuel switching by
Owner.
Design team
with current
incentives to a design team member
ncluding architects and engineers. lncentives
are available ule and include honorariums and design
to encourage early initial Company consultation on
rgn and plans. Honorariums will be equally available to all
architects and engineers for Idaho projects within Company's
limited to one honorarium per project.
ives will be offered to all professionally certified architects and
for Idaho projects within Company's territory. Payment of incentives to
the gn team will require final construction documents include an efficient design
company requirements. Incentives will be based on the square footage of
(7)
(8)
the project and limited to one per project.
(Continued)
EFFECTryE: May 1,2008
Submitted Under Case No. PAC-E-08-01
ISSUED: February 14, 2008
ROCKY MOUNTAIN
POWER
A Dn iBror{ of ilqrcoiP
Rocky Mountain Power
Exhibit No. 4 Page 21 ol27
Case No. PAC-E-14-08
\Mtness: Kathryn C. Hymas
Original Sheet No. 125.9LP.U.C. No.1
ELECTRIC SERVICE SCEEDULE NO. f25 - Continued
PROVISIONS OF SERVICE: (continued)
Additional conditions for design team incentives will be
energy efliciency program section of the Company's web
with 45 days notice posted on the web site.
ELECTRIC SERVICE REGULATIONS: Service under this
Rules and Regulations contained in the tariff of which this
prescribed by regulatory authorities.
Submitted Under Case No. PAC-E-08-01
ISSUED: February 14,2008 EX'F'ECTM: May l,2008
Rocky Mountain Power
Exhibit No. 4 Page 22 of 27
Case No. PAC-E-14-08
Vvitness: Kathryn C. HymasROCKY MOUNTAIN
POWER
A DMgrOt{ oF PAOnC(nP
I.P.U.C. No.1
First Revision of Sheet No. 155.1
Canceling Original Sheet No. 155.1
ROCKY MOT'NTAIN POWER
AGRICULTT]RAL ENERGY SERVICES SCHEDULE NO. 155
STATE OF IDAHO
Optional for Qualifying Customers
PURPOSE: Service under this Schedule is intended to
of the electricity requirements of new and existing loads in
irrigation district pumping systems by promoting electric energy-e
the installation of Energy Efliciency Measures.
APPLICABLE: To service under the
Power Service Schedule 10, and to any
Pacific Northwest Electric Power Planning
electric service on a retail schedule in all
DEFINITIONS:
Annual kWh
installation of
Drainage Pumping
Load" under the
.L. 96-501 and receives
pany in the State of Idaho.
(kwh) savings resulting from
or improved equipment operation,
as estimated by the or Company.
Average kW Savings: The Average Monthly On Peak
resulting from the installation of Energy Efficiency
equipment operation as estimated by Program
pany using engineering analysis as described below:
A Monthly On Peak kW Savings = (baseline average monthly On Peak kW
verage monthly On Peak kW), where;
+jverage Monthly On Peak kW = sum of the 12 Monthly Maximum On Peak
kWl12, where;
(Continued)
May 1,2008
Submitted Under Case No. PAC-E-08-01
ISSUED: February 14, 2008
Rocky Mountain Power
Exhibit No. 4 Page 23 ol27
Case No. PAC-E-14-08
\Mtness: Kathryn C. HymasROCKY MOUNTAIN
POWER
A DMSloil Of TAOHCOAP
LP.U.C. No.1 Original Sheet No. 155.2
AGRICULTURAL ENERGY SERVICES SCHEDULE NO. 155 (Continued)
DEFINITIONS: (Continued)
= Monthly Maximum On Peak kW = highest of all 15 minute average kW (as
determined below) for On Peak hours. On Peak hours hours
specified in the electric service schedule under which
electric service.
+ l5 minute average kW = sum of kWh used over
Baseline Adjustments: Program Administrator lne
electric energy consumption and costs during any of
the following: standard practice, changes in
system use and equipment at the end of iqflrseful life.
Customer: Any party who has hnd receives service at
the real property, is the owner the electricity user at the
real property.
Energr Efficiency money made by Program
Administrator or installation of Energy Efficiency
Measures Efficiency Incentive Agreement or
approved Appl
: An agreement between Customer and
Company providing for Program Administrator or
fficiency Incentive with respect to Energy Efficiency
to this tariffSchedule.
Incentive Application: An application provided by the
or Company, completed by the Customer and approved by
inistrator or Company requesting the Program Administrator or
Energy Efficiency Incentives with respect to Energy Efficiency
pursuant to this Schedule.
Efficiency Measure (EEM): Permanently installed measure specified in
5n Energy Efficiency Incentive Agreement or Application which can improve the
efficiency of the Customer's electric energy use.
Enerry
(Continued)
EFFECTM: September 15, 2006
Submitted Under Advice Letter No. 06-06
ISSUED: August 14,2006
Rocky Mountain Power
Exhibit No. 4 Page 24 ol27
Case No. PAC-E-14-08
Vvitness: Kathryn C. HymasROCKY MOUNTAIN
POWER
A OMSTOT{ OF PActFTCOiP
I.P.U.C. No. I Original Sheet No. 155.3
AGRICULTURAL ENERGY SERVICES SCHEDULE NO. 155 (Continued)
DEFINITIONS: (Continued)
Energy Efficiency Project: One or more EEM(s) covered by one Energy
Efficiency Incentive Agreement or Application .
Enerry Efficiency Measure (EEM) Cost:
New Construction: EEM Cost is the total installed
equipment or system minus the cost of the
or system.
Major System Upgrades: EEM Cost
efficient equipment or system minus
equipment or system.
Retrofit: EEM Cost is the total i
modification.
the
cost
ls
the
In the case of New
Costs shall mean the
rebates or incentives
Schedule or United
Quality lncenti
the final
EEMs atofi
labor costs
Program Administrator:
administer this Schedule.
er than
tes De
and Retrofits, EEM
incurred (net ofany discounts,
Incentives available under this
Agriculture (USDA) Environmental
Qualified person or entity hired by the Company to
(Continued)
(EQrP) i or other consideration that reduces
by the Customer) to purchase and install
the Customer installs the EEM, then the cost
to the Customer's reasonable and realistic actual
irrigation piping, pumping, or system to provide
irrigated acreage or loads.
Upgrades: Changes, modifications or additions to existing
l or equipment that involve substantial removal and replacement
systems or equipment where such changes, modifications or additions
:d to replace equipment at the end of its useful life, add capacity or
the utilization of the acreage or loads.
ihe energy
Submitted Under Advice Letter No. 06-06
ISSUED: August 14,2006 EFFECTM: September 15, 2006
I.P.U.C. No. 1
ROCKY MOUNTAIN
POVI'ER
A OMSTot{ Or PACTFEOnP
Rocky Mountain Power
Exhibit No. 4 Page 25 ol 27
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
First Revision of Sheet No. 155.4
Canceling Original Sheet No. 155.4
AGRICULTURAL ENERGY SERVICES SCHEDULE NO. 155 (Continued)
DEFINITIONS: (Continued)
Retrofit: Changes, modifications or additions to systems or equipment serving
existing acreage or loads.
INCENTIVES FOR EEMS:
Energy Efficiency Incentives: Program shall
establish procedures and requirements for prov
to Customers which shall be posted on the
Incentives include amounts available accordi
formula listed below. All proposed Energy Effic
Program Administrator or Company
Efficiency Incentive Agreement or
Company will establish Energy
criteria on the Company web
Energy Efficiency llation of EEMs pursuant to
an Energy Efficiency
the sum of (a) and (b)
lication shall be the lesser of
(b)
(c):(a) $0.12 /k the Annual savings as determined using Program
Admini or approved engineering analysis;
$so/kw y On Peak kW savings determined using
Company provided or approved engineering
as determined by the Program
(Continued)
, {enffi and cost
iecf dre subject to
ng an Energy
Administrator or
criteria and post the
50%
Submitted Under Case No. PAC-E-13-10
ISSUED: May 24,2013 EFFECTM: August 15, 2013
Rocky Mountain Power
Exhibit No. 4 Page 26 of 27
Case No. PAC-E-14-08
Wtness: Kathryn C. HymasROCKY MOUNTAIN
PCIUI'ER
A DMSTON Of PAOfTCOfiP
LP.U.C. No.l Original Sheet No. 155.5
AGRICULTURAL ENERGY SERVICES SCHEDULE NO. 155 (Continued)
INCENTMS FOR EEMS: (Continued)
Energy Efficiency Incentives may be adjusted such that Customer does not receive
more than 100% of EEM Costs in total incentives including i available
under this Schedule and EQIP incentives.
All proposed EEM Costs are subject to Program
review and approval prior to offering an Energy
or approving an Application. All final EEM
Administrator or Company review and hn Energy
Efficiency Incentive per the terms of an Energy Eflic Agreement or
and approvalapproved Application. Program Admini
of EEM Costs may require additional ustomer.
The Customer may receive
Schedule per EEM.
PROVISIONS OF
Incentive under this
(l)
shall meet with Customer and any
an initial site visiUplans review to determine
riate for an energy analysis. The energy
ude a visual pump check, water management
ing, and/or irrigation/pump system analysis.
the coil[sion of the visual pump check and water management
, the Customer may be asked to sign an approval to proceed to
step in the program and to commit to implement operational
identified in the water management consultation. If
signs the approval, Customer will receive an irrigation/pump
post-installation testing of installed system.
Energy
(Continued)
EFFECTM: September 15, 2006
Submitted Under Advice Letter No. 06-06
ISSUED: August 14,2006
ROCKY MOUNTAIN
POWER
A OIvlSrOil Of ;AOF|COhP
I.P.U.C. No.1
Rocky Mountain Power
Exhibil No. 4 Page 27 ol 27
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
First Revision of Sheet No. 155.6
Canceling Original Sheet No. 155.6
AGRICULTURAL ENERGY SERVICES SCHEDULE NO. 155 (Continued)
PROYISIONS OF SERYICE: (Continued)
(2) EEM Inspection
Program Administrator or Company may inspect any which are
funded by or installed under this program. Sati ion by
rvmg
Agreement or approved Application.
(3)Measure Performance V
Program Administrator and/or Company or evllite the energy
savings of installed Energy Effigi iffd in the Energy
Efticiency lncentive ication. This
verification may include a it, review of system
operating ion of monitoring
equipment as savmgs.
(4)made available to induce fuel
switching by
ELECTRIC SE Service under this Schedule is subject to
the General Rules and iffof which this Schedule is a part, and to
those prescribed by
Program Administrator or Company will be
Energy Efliciency lncentives specified in the
TIO
din
Submitted Under Case No. PAC-E-I3-10
ISSUED: May 24,2013 EFF'ECTM: August 15, 2013
Case No. PAC-E-14-08
Exhibit No. 5
Witness: Kathryn C. Hymas
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Testimony of Kathryn C. Hymas
Explanation of Typical/Prescriptive Measure Changes
August 2014
Rocky Mountain Power
"BlXJ,i;lLi3t1,xll8
Witness: Kathryn C. Hymas
Exhibit 5
EXPLANATION OF TYPICAL/PRESCRIPTIVE MEASURE CHANGES
Lighting Incentives
Table I highlights the proposed lighting measure changes, including modifications to align with
changes in federal lighting standards.
Table 1
Retrofit Lighting Changes
Exhibit 5 - Explanation of prescriptive incentive table changes - Idaho - Filed August 2014
Page I of10
Measure Chanse Reason for Change
Linear Fluorescent,
CEE T8
Adjust measure category
name to be "CEE T8"
With the removal of the Standard T8
incentive, CEE T8 high performance lamp
becomes the base-level incentive offering for
T8 fixtures
To encourage installation of lower wattage
CEE T8, a higher incentive will be offered
for fixtures using CEE T8 Reduced Wattage
lamns.
Linear Fluorescent,
T8, Relamp
Increase the incentive to
$1.00 per lamp.
The baseline shift for linear fluorescent has
taken place in part due to the prevalence of
standard T8 lamps in the market. This
prevalence is also a large opportunity for
additional kWh savings by relamping to a
lower wattage T8
Relamp incentive is targeting percentage of
an elective lamp unsrade
Linear Fluorescent,
T8, High Bay
Tier the high bay incentive
based on lamp count per
fixture.
Recent cost analysis shows that the cost per
lamp for a high-bay fixture decreases as the
lamp count increases. The tiered incentive
offers the appropriate incentive based on
incremental costs.
Linear Fluorescent,
T5, Relamp
Increase the incentive to
$1.00 oer lamo.
This increase is for consistent relamp
messasins resardless of T8 or T5.
Linear Fluorescent,
T5, High Bay
Tier the high bay incentive
based on lamp count per
fixture.
Recent cost analysis shows that the cost per
lamp for a high-bay fixture decreases as the
lamp count increases. The tiered incentive
offers the appropriate incentive based on
incremental costs.
Compact
Fluorescent Lamp
- screw-in lamo
Remove measure from
table.
Measure was sunset from the program
effective January l, 2014.
Induction Fixture Reduce the incentive
amount to $75lfixture.
The reduction in incentive is in response to
reduced market costs.
Other LED Group all LED categories
(except integral screw-in
and recessed downlight)
into a single category and
offer incentives at a rate of
$0.15 per kWh saved.
The LED category is ever evolving. The
technology is expanding in its uses and
application.
Removing defined categories and specific
incentives per fixture enables the incentive
to evolve with the technology and market
and maintain a cost-effective result.
Custom Increase incentive to
$0.r5/kwh
The incentive rate is aligned with the custom
incentive rate of the wattsmart Business
Drosram.
Daylighting
Control
Clarify eligibility
requirements.
Adjust eligibility requirements to include
interior fixtures with drivers (i.e. LEDs), and
require at least 50% reduction in output of
connected fixtures.
Occupancy Control Define the incentive rate
per watt controlled instead
of per sensor
Incentives based on controlled wattage
encourage controlling more watts, rather
than installing more sensors.
Daylighting
Control
Define the incentive rate
per watt controlled instead
ofner sensor
Advance
Daylighting
Control
Define the incentive rate
per watt controlled instead
ofner sensor
Dimming Ballast Remove the measure.The dimming ballast is an inherent part of
the daylighting control measure. The
incentive for daylighting control was
established with consideration of the
additional costs for dimmine ballasts.
Rocky Mountain Power
Exhibit No. 5 Page 2 of 10
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Table 2 highlights the proposed changes to new construction and major renovation lighting
measures.
Table 2
New Construction/lVlajor Renovation Lighting
Measure Chanse Reason for Chanse
Exterior Lighting, LED Revise the exterior
LED categories to
include new types
of fixtures and
defined wattage
ranges.
The new categories are aligned with the
qualified list updates, current market costs, and
enable most exterior LED lighting applications
to be eligible for incentives.
Exterior Lighting,
Lighting Control
Change incentive
to be based on per
controlled watt
Incentives based on wattage controlled
encourage controlling more watts, rather than
instal I ing more sensors.
Rocky Mountain Power
"E:lJ,i":Jf3:.:,"j-13
Wtness: Kathryn C. Hymas
Table 3 summarizes modifications for existing HVAC, building envelope, food service,
appliances and office energy efficiency measures included in the program.
Table 3
Summary of Proposed Changes to Existing HVAC, Building Envelope, Food Service,
Appliances and Office Energy Efficiency Measures
Measure
Catesorv
Measures
HVAC
Other HVAC
Equipment and
Controls
Unitary commercial air
conditioners and heat Dumos
Update deemed costs to align with market
data.
PTAC/PTHP Occupancy
Based Controller
Revise eligibility to include door-key
occupancy sensors in addition to
infrared/ultrasonic sensors.
Portable Classroom HVAC
Control
Revise eligibility to include occupancy based
thermostat control in addition to 3651366
schedulins.
Food Service Commercial Dishwasher Update deemed savings/costs and incentive
to align with ENERGY STAR specification
update and current industry standard
baseline.
Remove eligibi lity requirement of electrically
heated DHW, but require electric booster
heater to increase program participation.
Savings willvary based on DHW energy
source.
Refrigerator/Freezer Discontinue offering incentives for solid door
refrigerators/freezers. Very limited savings
potential relative to industry standard
baseline. Revise incentives for transparent
door refrigerators/freezers based on updated
cost data.
Electric Insulated Holding
Cabinet
Adjust incentives based on revised deemed
costs/savings.
Electric Combination Oven Update deemed savings/costs and incentive
to align with ENERGY STAR specification
update (effective I I I l20l 4).
Add/define size category to account for large
differences in incremental costs.
Electric Convection Oven Update deemed savings/costs and incentive
to align with pending ENERGY STAR
specification uodate (effective I I I 1201 4\.
Electric Griddle Discontinue offering incentives for ENERGY
STAR Tier I electric griddles. Negligible
incremental cost difference and small savings
between standard and ENERGY STAR Tier
I qualified products. Adjust eligibility
requirements to ENERGY STAR Tier 2
Rocky Mountain Power
Exhibit No. 5 Page 4 of 10
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
qualified models only. Update deemed
costs/savinss.
Electric Steam Cooker Tier I - Update deemed costs/savings and
incentive.
Tier 2 - Adjust eligibility requirements and
deemed savings/costs and incentive to align
with revised RTF data.
Electric Commercial Fryer Tier 2 - Adjust eligibility requirements and
deemed savings/costs and incentive to align
with revised RTF data.
Air-Cooled Ice Machines Update deemed savings/costs and incentive
to align with ENERGY STAR specification
undate.
LED Case Lighting Update deemed savings and costs to align
with revised RTF data.
Residential Refrigerator
(used in a Business)
Update eligibility/incentives and reported
costs/savings to align with the Home Energy
Savinss Drogram.
Residential Dishwasher
(used in a Business)
Remove commercial in alignment with recent
Home Enersv Savinss Drosram uodates.
Appliances Commercial Clothes Washer Update incentives, deemed costs/savings to
align with market data for ENERGY STAR
qualified models.
Remove incentives for CEE Tier 3 qualified
models as CEE has suspended its commercial
clothes washer snecifi cation.
Residential Water Heater
(Used in a Business)
Update eligibility/incentives and reported
costs/savings to align with the Home Energy
Savings program.Residential Clothes Washer
(Used in a Business)
Office Network Power PC
Management
Update deemed savings and costs to align
with data from NWPCC 6'h Plan RTF since
RTF measure is now limited to K-12 schools.
Reduce incentive to $5/pc. Update eligibility
criteria to include only desktop computers for
hisher savinss certaintv.
Smart Plug Strip Update deemed savings and costs to align
with revised data from RTF.
Rocky Mountain Power
='u:xJ,i":Jf3:,:,"I3
Witness: Kathryn C. Hymas
To further increase participation and the comprehensiveness of the program and streamline
program administration, the Company is proposing to add new measures to existing measure
categories, as detailed below in Table 4. In addition, there are new industrial/ag measures in
subsequent tables.
Table 4
New Measures
Measure
Catesorv
Measure Description
HVAC Variable Refrigerant Flow
(VRF) Heat Pump
Offer a prescriptive incentive for VRF systems,
which are an increasingly requested HVAC
option in small/medium commercial buildings.
Align eligibility requirements with CEE high-
efficiency HVAC specification and calculate
savings based on building type, climate and size
of svstem.
Evaporative Pre-Cooling Offer a prescriptive incentive (based on air
conditioning equipment size) for equipment that
pre-cools air before it reaches the air conditioner
condenser coil.
Food Service Anti-Sweat Heater Controls
(Retrofit-Only)
Offer prescriptive incentives (per linear foot of
refrigerated case) for anti-sweat heater controls
installed in retrofit applications. Align deemed
savings/costs with recently approved RTF UES
data.
Demand-Controlled Kitchen
Ventilation (Retrofit-Only)
A simplified calculator tool will be utilized to
estimate savings based on kitchen operating
hours, climate, and HVAC system efficiency.
Incentives offered on a $lkWh saved basis.
Residential Refri gerator/
Freezer Recycling
Allow non-residential customers to participate
in the residential refrigerator and freezer
recycling program for qualifoing residential
refriserators and freezers used in a business.
Rocky Mountain Power
Exhibit No. 5 Page 6 of '10
Case No. PAC-E-14-08
Vvitness: Kathryn C. Hymas
Table 5
Farm and Dairy
Measure Catesorv Description of Chanee Reason for Chanse
Farm and Dairy Revise the basis for
determining incentives
for the heat recovery
measure.
The previous incentive for heat reclaim - using
heat rejected from the milk refrigeration system
to offset electric water heating - was calculated
as $220 per condenser kW. The revised
approach uses a calculator to directly calculate
energy savings from pounds of milk/day,
temperature d i fference s, and i nformation about
the refrigeration system. Incentive rate is
aligned with the custom project rate, $0.15/kWh
annual savings upto70%o ofproject cost or
one-year payback.
This is a measure in the existing program and
currentlv utilizes site soecific calculations.
Revise incentive rate
for milk pre-cooler
measure from the
previous $0.12lkwh
plus $50/kW to the new
custom rate of
$0.15/kwh.
This revision brings the incentive rate for milk
pre-coolers into alignment with the standard
custom rate.
This is a measure in the existing program and
currently utilizes site specific calculations.
Add new measure:
variable frequency
drives for fans in potato
or onion storages.
Potato and onion storage fan VFDs have been
eligible for custom incentives in the current
programs. Key variable affecting energy
consumption and available savings can be
gathered. The measure is well suited to utilize a
calculator to determine savings. Making
potato/onion storage fan VFDs a listed measure
enables rapid turnaround on the incentive
process, low cost administration, and optimal
participation by vendors and growers. The
Regional Technical Forum (RTF) has
maintained a Unit Energy Savings (UES) value
(on a per horsepower basis) for this measure in
the oast.
Apply project level
caps (percent of project
costs and one-year
payback) to all Farm
and Dairy measures.
Customer costs for Farm and Dairy measures
vary. While incentives are set to be a portion of
(but not exceed) the measure costs, having
project cost and simple payback caps consistent
with the custom project offer in the program
aligns program delivery with design intent and
simplifies marketing to customers and trade
allies.
Rocky Mountain Power
Exhibit No. 5 Page 7 of 10
Case No. PAC-E-14-08
\Mtness: Kathryn C. Hymas
Table 6
Compressed Air Measures
Measure Category Description of
Chanse
Reason for Change
Compressed Air Revise savings for zero
loss condensate drain
from 0.14590 kWh per
hour ofoperation per
year to 786.37 kWh/yr.
Revise incentive from
$90 each to $l 00 each.
Using average annual system runtime to
determine Unit Energy Savings is a simpler
approach for this small system measure than
collecting runtime for each system to calculate
system-specific savings. Experience over time
with the program has led to an annual average
runtime close to the Department of Energy
estimated average. This runtime has been used
to simplify the UES value. Measure cost has
increased slightly, and available savings
support a slight increase in incentive to help
further increase participation.
Revise savings for
cycling refrigerated
dryer from 0.00242
kWh per scfm per hour
ofoperation per year to
12.73 kWh/scfm per
year. Revise incentive
from $1.50/scfm to
$2.00/scfm. For
projects where a new
dryer is installed along
with a new air
compressor, use the
Northwest Regional
Compressed Air Tool
to calculate dryer
savings and pay the
incentive at the custom
incentive rate rather
than using the Unit
Energy Savings kWh
and incentive value.
Same note as above regarding runtime and RTF
Incentive slightly increased to encourage
participation. Cycling dryers installed with a
compressor may take advantage of the fact that
the load profile for the specific installation has
already been estimated. The Northwest
Regional Compressed Air calculator can
calculate actual dryer savings using the
compressor load profile and can package the
presentation of compressor and dryer
economics into the same single sheet
presentation for the decision maker. Hence the
use of the custom approach for the dryer when
purchased in conjunction with a compressor.
Revise savings for
receiver capacity
addition measure from
0.00249 kWh per
gallon per hour of
operation per year to
13.10 kWh per gallon
per year. Revise
incentive from $1.50
per sallon to $3.00 per
Same note as above regarding runtime.
Incentive has been increased to encourage
participation.
Rocky Mountain Power
Exhibit No. 5 Page I of 10
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
gallon of receiver
capacity above the first
2 gallons/scfm of trim
comDressor caDacitY.
Revise savings for low
pressure drop filter
measure from 0.00129
kWh per scfm per hour
of operation per year to
6.79 kwh per scfm per
year. Revise incentive
from $0.80 per scfm to
$2.00 oer scfm.
Same note as above regarding runtime.
Incentive has been increased to encourage
participation.
Revise savings for
outside air intake
measure from 0.00931
kWh per hp per hour of
operation per year to
48.97 kwh per hp per
year. Incentive
remains unchansed.
Same note as above regarding runtime.
Remove the constraint
on the VFD
compressor measure
that the system be
comprised of only a
single operating
compressor (not
counting backup
capacity). Allow VFD
compressors to be
treated as listed
measures as long as the
compressor receiving
the incentive is
installed in a system
with totalcapacity of
75 hp or less, not
counting backup
compressor(s) that do
not normallv run.
Clarifies program design intent to focus on
smaller systems with identifiable key variables
that affect energy consumption and savings.
Second machines may be in place for back-up
purposes and may not materially affect
available energy savings. Eliminates confusion
when a customer wishes to install VFD
compressor in a system with a second fixed
speed compressor that operates at times to keep
up plant pressure and the total system is less
than75 hp in total capacity. Systems with
multiple compressors can be handled through a
combination of calculators and program staff
engineering calculations outside of the
calculator.
Rocky Mountain Power
Exhibit No. 5 Page 9 of 10
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
For the VFD
compressor measure,
remove the constraint
that "compressor must
not use inlet
modulation when
demand is below the
minimum speed
threshold of the VFD
compressor."
Aligns program eligibility with best available
market information on how various
manufacturers control a compressor when
demand for compressed air in less than that
delivered by the machine once the VFD has
slowed to its minimum allowable speed. Some
of these methods are more efficient than others,
yet the net effect on savings is minimal given
the amount of time system typically is in this
operating mode. Removing the language
broadens the equipment options for customers.
Add compressed air
end use reduction as a
listed measure. Use the
Northwest Regional
Compressed Air Tool
to estimate savings and
pay at the custom rate.
Inefficient uses of compressed air are very
common in industry. Where functionally
equivalent alternatives are available, savings
can be had by undertaking small projects to
make a change in the system. Examples
include replacing simple blowing applications
with engineered nozzles, using electric pumps
in place of air operated pumps, and adding
isolation valves to close off a portion of a
distribution system when not operating (saving
on leak load). Compressed air savings in cfm
may be estimated by program staff, and the
Northwest Regional Compressed Air tool may
then be used to estimate savings and incentives.
This approach makes such small projects
feasible to administer.
Apply project level
caps (percent of project
costs and one-year
payback) to all
Compressed Air
projects.
Customer costs for Compressed Air measures
vary. While incentives are set to be a portion of
(but not exceed) the measure costs, having
project cost and simple payback caps consistent
with the custom project offer in the program
aligns program delivery with design intent and
simplifies marketing to customers and trade
allies.
Rocky Mountain Power
Exhibit No. 5 Page 10 of 10
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Table 7
Waste Water and Other Refrigeration
Measure Catesorv Descrintion of chanse Reason for Change
Other -
Refrigeration and
Wastewater
Add adaptive
refrigeration control
measure. Use
calculator to estimate
savings and pay at the
custom rate of
$0.15/per kWh with
project level caps
(percent ofproject
costs and one-year
oavback).
Adaptive refrigeration controllers replace
conventional thermostat, defrost time clock and
defrost termination controls in refrigerated
spaces cooled by unitary systems. Projects are
typically small, with savings ranging from
2,000 to 20,000 kWh per controller, depending
on system size. Savings is readily determined
using nameplate information and operating
schedules. These opportunities are efficiently
administered as a calculator-based listed
measure.
Add fast acting door
measure. Use
calculator to estimate
savings and pay at the
custom rate of
$0.15/per kWh with
project level caps
(percent ofproject
costs and one-year
pavback).
Fast acting doors replace manually operated
doors, automatic doors with long cycle times,
strip curtains, or entryways with no door at all
in refrigerated or conditioned space. Savings is
highly situation specific. A calculator-based
listed measure takes into account the details of
each situation, while affording an efficient
administrative approach.
Add low power mixer
measure. Use
calculator to estimate
savings and pay at the
custom rate of
$0.15/per kWh with
project level caps
(percent ofproject
costs and one-year
navback).
Low power mixers, also called extended range
circulators, take the place of high powered
mixers or the practice of using aeration for
mixing in wastewater treatment ponds. A
calculator-based approach is an effective
method of generating leads and administering
project using the custom incentive rate and cap.
Case No. PAC-E-I4-08
Exhibit No. 6
Witness: Kathryn C. Hymas
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Testimony of Kathryn C. Hymas
Enhanced Offer for Small Business Customers
August 2014
Rocky Mountain Power
Exhibit No. 6 Page 'l of 8
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Exhibit 6
Enhanced offer for small business customers
In this application the Company is also requesting to add a targeted incentive offer to capture
additional savings from the harder to reach small/medium business customer segment. The
initial offer will be an enhanced retrofit lighting upgrade offering. There is high market potential
for energy savings from lighting upgrades in the small/medium business customer segment as
evidenced by:
An analysis of past program participation which showed that99o/o of small business
customers (approximately 9,000 customers) have not participated in energy efficiency
programs.
The findings of the Company's 2013 DSM Potential Study which shows the largest
savings potential of all measure categories continues to be in commercial lighting -37%of the achievable technicalpotentialacross five of six statesl served by the Company.
(The Cadmus Group, lnc.,2013).2
The small business offer is designed to overcome participation barriers for small/medium
business customers, as identified by the Center for Energy and Environment3:
. Lack of awareness of energy-efficienc), opportunities and relative benefits in both
customer-owned and leased facilities.
. Lack of time and resources to investigate and implement energy efficiency improvements
. Limited access to capital for energy efficiency projects
Overview o-f the small business qffer
As proposed, the small business offer will align with a best-practice approach used by many
other utilities (listed in Table l, below) utilizing a pool of Company-approved and managed
contractors to work directly with small/medium business customers to identify energy-efficiency
upgrades, estimate savings and incentives, and install high-efficiency equipment. Participating
customers utilizing an approved contractor will be eligible for an enhanced incentive offer
targeted at80Yo ofthe project cost. To reduce the customer's out-of-pocket expenses and
minimize cash flow impacts, the customer can assign the incentive to the contractor who will
then apply it as an up-front reduction to the overall project cost. Participating contractors will
complete and submit the required incentive application and documentation to the Company for
payment of the incentive amount that was assigned to them by the customer.
I Excludes Oregon
'The Cadmus Group, Inc. (2013). Assessment of Long-Term, System-Wide Potentialfor Demand-Side and Other
Supplemental Resources, 20 I 3-2032 Volume L PacifiCorp.
3 Center for Energy and Environment. (n.d.). One-Stop Efliciency Shop 2000-2007. Minneapolis: Centerfor Energt
and Environment.
Exhibit 6 - Small Business Offer - Idaho - Filed August2014
Page 1 of8
Rocky Mountain Power
Exhibit No. 6 Page 2 of 8
Case No. PAC-E-14-08
Wtness: Kathryn C. Hymas
Table I - Similar Offers from Other Utilities
mffiE;i.RiBht Lights Small and Mid-Sized
Business
O+Express Solutions Demand < 100 kW +
schools
--\E-UJIF Business Solutions Small
Business Program
< 145,000 kwh/yr
m Small Business Direct lnstall
Lighting Program
< 350 kw
gE6TS6ffi Direct lnstall Small and Mid-Sized
Business
lJmlo Complete Energy Solutions Up to 299 kW / mo
natbnalgEkl
nrffiddst
Small Business Services
program
<300kW / month
erm Small Business Energy
Advantage
Avg peak demand l0
kw - 200 kw
e x=i-Small Business Energy
Solutions
< 200 kW / month
ffi.Smart Energy Savers <60 kW / mo
@xae,wgy-Small Business
Lishtins
< 400 Kw
In this application, the Company is requesting approval to consolidate all non-residential
programs into the wattsmart Business program. The small business offer is proposed to be added
as a component of the wattsmart Business program. The existing design/infrastructure and trade
ally/contractor administration team will be utilized, linking customers with the program options
and contractor resources that most appropriately address their needs. Customers not eligible to
receive the small business offer remain eligible to participate in all other elements of waffsmart
Business including the program's other lighting offers.
The Company has hired an administrator for the small business offer using a competitive RFP
process. The administrator will identifu, solicit, and approve contractors to participate in the
delivery of the small business offer. Selection criteria will be based on business reputation,
offered lighting retrofit costs, past program participation, geographic area served, and capability
to pursue projects. Preference will be given to existing local Idaho contractor businesses
operating successfully for the past l2 months. Approved contractors will be required to enter into
an agreement with the Company indicating they will abide by the terms and conditions of this
offer and will be provided with local sales, marketing, and program training. Contractor
performance will be monitored closely to ensure high customer satisfaction, accurate project
information, and cost-effective savings.
Exhibit 6 - Small Business Offer - Idaho - Filed August 2014
Page 2 of8
Rocky Mountain Power
Exhibit No. 6 Page 3 of 8
Case No. PAC-E-14-08
VMtness: Kathryn C. Hymas
Table 2 - Small/lVledium Business Barriers and Solutions
Barrier Solution
Lack of awareness of energy-
efficiency opportunities and
relative benefits in both
customer-owned and leased
facilities.
Contractors identify upgrades and provide customers, owners
and tenants with the output of a lighting tool summarizing the
project economics with available incentives. Contractors
explain energy and non-energy benefits.
Lack of time and resources to
investigate and implement
energy efficiency
improvements
Contractors approved by the Company-hired administrator
review existing lighting and provide customers with a proposal
for upgraded lighting.
Contractors provide completed paperwork for customer
signature.
Limited access to capital for
energy efficiency projects
Incentives are targeted to cover 80% of the implementation
costs, significantly reducing the initial customer out-of-pocket
expenses. Customers are expected to recoup their total out-of-
pocket investment in the form of electric bill savings in as little
as one vear.
Customer Particioation Process
The small business offer will be available to customers exclusively through approved
contractors, according to the process outlined in
Exhibit 6 - Small Business Offer - Idaho - Filed August2014
Page 3 of8
Rocky Mountain Power
Exhibit No. 6 Page 4 of 8
Case No. PAC-E-14-08
Vvilness: Kathryn C. Hymas
Figure t below. Outreach and sales effbrts of the approved contractors will be the primary means
by which customers will learn about the offer, but may be supplemented by Company-led
marketing efforts.
Once engaged, approved contractors will work with the customer to confirm eligibility,
inventory existing equipment, recommend high-efficiency upgrades, estimate the overall project
cost, identify energy/cost savings, and provide available incentive calculations. Incentives are
targeted to cover 80% of the overall project cost and may be credited against the overall cost
quote provided to the customer as part of the contractor bid.
The customer
o decides whether to proceed with the projecto decides which participating vendor to work witho decides to assign the incentives to contractor (reflected as a credit on the contractor
invoice to the customer) or to receive a cash incentive at project completion.o schedules the installation date with the contractor, and. pays the non-incentivized portion of the project cost directly to the contractor.
Upon completion and approval of the project, the incentive is paid according to the instructions
in the customer's application (either paid directly to the contractor or paid to the customer).
Exhibit 6 - Small Business Offer - Idaho - Filed August 2014
Page 4 of8
Rocky Mountain Power
Exhibit No. 6 Page 5 of 8
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
Figure t: Small Business Lighting Participation Process
wattsmart Small Business Lighting Participation Process
,,., Optional Project Pre-approval
Program Marketing and Outreach
Assign lncentive to
Contractor and Pay lnvoice
lssue lncentive Check to
Cusiomer or Contraclor (if
assigned)
Receive lncentive Check
Eligible Customers
Exhibit 6 - Small Business Offer - Idaho - Filed August20l4
Page 5 of8
Rocky Mountain Power
Exhibit No. 6 Page 6 of B
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
To ensure the small business offer targets its intended audience. the company's small/medium
business customers, eligibility will be limited as follows:
r Rate Schedule 23 &23A - all customers on this rate schedule will be eligible
Additional eligibility criteria may be added, (e.g. square footage. operating hours, kWh usage) to
align with savings targets, incentive budgets, and cost effectiveness requirements and will be
posted on the Company website.
Oualil)tins Measures
Initially, the measure list will be focused on high-efficacy fluorescent lighting technologies,
occupancy controls, and LED recessed downlights and exit signs that are frequently found in
small/medium businesses, as shown in Table 3. Measures not included in the small business
customer incentive table will be incentivized at the standard rates offered in the wattsmart
Business program.
Table 3 - Enhanced Incentives for Small Businesses
Exhibit 6 - Small
Page 6 of 8
Measure Category Eligibility Rcquirements
I-8 l'-luorcscenl
Retrofit
(Lamp/Ballast)
4" CEE Qualilied Reduced Wattage l-amp and CEE,
Qualilled Ballast included on qualilred ballast list
Delamp
4' CEE Qualilled Rcduced Wattage or Iligh Performance
Lamp and CI-.E Qualilied Ballast. Must remove one or more
Iamps. 'l'o delamp an existing fixture. the lamp and all
corresoondins. sockels must be oermanentlv disabled.
Tl2 Conversion
(Kit/Lamp/Ballast)
8' Tl2 to (2) 4' CEI] Qualilied Reduced Wattage or High
Perlbrmance l'8 l-amrrs and CEE Qualilled Ballast.
Relamp Lamp rvatlage reduction ) 3 Watts. No ballast retrofit
Replacement
High Bay
(Fixturei Lamp/Ballas
r)
Fixture with less than six (6) Ianrps: 4' CEE Qualified High
Perlbrmance l-amo. Must replace TI2HO/VHO or HID
Fixture u,ith six (6) or more lamps: 4' CEE Qualified High
Performance l,amp. Must replace Tl2tlO/Vt{O.
incandescent or I ll D
J'5 I:luorescent
Replacement - T5
Standard
(Fixture/Lamp/Ballas
t)
4' Nominal [,amp < 28 Watts. Ballast Factor < 1.0
Relamp [,amp wattage reduclion > 3 Watts. No ballast retrofit
Replacement -
High Bay
( Fixture/Lamp/Ballas
r)
Fixture uith less than six (6) lamps: Must replace
1'l2HO/VtlO. lncandescent or HII)
Fixture rvith six (6) or more lamps: Musl replace
TI2HO/VtlO or lllD
l.EI)
ReplacemenVRetrofit
- Recessed Downlight
(Fixture or Kit)
Must replace existing incandescent or fluorescent.
l-[:,[) must be listed on qualified equipment list
Replacement - Exit
Sisns Must replace incandescent or fluorescent
l-ighting Control
Wall Occupancl
Sensor Retrofit PIR. I)ual 'Iech
Ceiling Occupancl
Sensor Re1rofi1 PIR. Dual Tech
Business Offer - Idaho - Filed August 2014
Rocky Mountain Power
Exhibit No. 6 Page 7 of 8
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
The Company will continue to review other possible qualifying measures that are found cost
effective either at a program or individual project level. The Company will bring those measures
forward to the Commission and into the offering as they are identified.
Incentive Structure
The Company is proposing to define the incentives for this offer on a measure-specific basis
targeted to cover 80% of the customer cost. Incentives will initially be determined relative to
market costs collected from the contractor application process used to select and approve
contractors and will not exceed the maximum incentive values in Schedule 140. The incentive
table will be posted on the Company's website.
Incentives will be explicitly defined in the agreement made with each contractor. When the
customer has opted to assign the incentive payment to the contractor, contractors will be required
to pass-through the full incentive amounts as an up-front discount off the cost quote provided to
participating customers through the assignment of the incentives to the contractors by the
customers.
Upon completion and approval of a project, the incentive will be paid by the Company directly
to the contractor who was assigned the incentive or to the customer if the incentive was not
assigned to the contractor. This approach significantly reduces the customer's out-of-pocket
expenses, as detailed in the example project below.
Figure 2 - Example Project
Project Specifics are from a past wattsmart
Business retrofit project:
" Idaho schedule 23 customer in Shelley,
IdahoEnergy Cost: $0.08788 &Wh. Demand Cost = $0.00 lkW- (42) 2-Lanp, 4' Premium T8 fixtures
installed
Total Proiect Cost $3-300
F.nerw Savinos /LWh/wr'l 9.532
Demand Savings ftWmonth)2.90
Electric Cost Savinss $838
Enhanced Incentive (80o/o)- $2"640
Net Customer Out-of-Pocket Cost s660
Simple Payback (Pre-Incentive)3.9 vrs
Simple Payback (Post-Incentive)0.8 vrs
The example shows the customer's out-of-pocket expenses reduced from $3,300 to $660 with the
simple payback going from 3.9 to 0.8 years after incentives. Compare this to the same project
receiving the typical wattsmart Business incentives where the customer's out-of-pocket expenses
are $ I ,650 with a simple payback of 2.0 years after incentives.
Taritf structure -for small business incentives
Exhibit 4 includes the above Table 3 listing the qualifying measures. Although participants have
the option to receive their incentive payment directly, the Company anticipates most will assign
their incentive payment to the lighting contractor. The Company will have an agreement with
lighting contractors that includes pricing levels. Contractors will be required to propose pricing
that is consistenta with their agreement with the Company.
a Note contractors will have the flexibility to account for site specific variations in their proposed pricing to
customers (e.g. include costs for rental of a lift for high ceiling applications, after hours installation, etc.)
Exhibit 6 - Small Business Offer - ldaho - Filed August2014
Page 7 of8
Rocky Mountain Power
Exhibit No. 6 Page 8 of 8
Case No. PAC-E-14-08
Witness: Kathryn C. Hymas
It is important to have the capability to adjust incentive levels in response to changing market
conditions. It is the Company's intent to make adjustments to the incentive table periodically to
address market conditions for lighting (changes in material costs, product availability, and price
competition), ensure the customer out-of-pocket expenses are approximately 20Yo of the overall
project cost, and align with savings targets, incentive budgets, and cost effectiveness
requirements.
When the Company needs to adjust the small business incentives, the Company will post a notice
on its website announcing the coming changes. The notice will be posted at least 45 days prior
to the changes taking effect. In no event will incentives exceed the not-to-exceed amounts listed
in Schedule 140 without Commission approval.
Oualit.v Assurance and Controls
A robust quality assurance regime is planned for the small business offer, focused on the
following:
Contractors - Contractors will be evaluated and selected no less than annually to deliver the
small business offer to customers. Each selected contractor will be required to sign an agreement
with the Company outlining quality, customer service, and participation requirements.
Contractor performance will be regularly monitored by the Company-hired administrator through
project application review, customer satisfaction surveys, on-site inspections, office visits, and
ongoing communications. Contractors not meeting or exceeding quality, customer service,
project, invoicing, and other requirements will be subject to removal from participation in the
small business offer.
Project Review - Contractors will be conducting a site-specific assessment and calculating
incentives using the Company-provided standard calculation workbook. Each project application
will be examined to validate customer eligibility, review submitted costs, and confirm adherence
to program policies and procedures before issuing an incentive check. Contractors are expected
to provide customer pricing consistent with costs submitted during the selection process. Project
costs will be closely monitored and deviations from the submitted costs will be investigated.
Installation Verification - On-site inspections and customer phone calls will be performed on a
sample of completed projects to confirm contractor-submitted charges, verify installation quality
and reported accuracy, and solicit customer feedback of the participation process.
Projected Costs and Enerw Savings
The Company has set a 2014 savings goal of 133,300 kwhs. Through an analysis of the eligible
customer base and the savings potential from the qualifying measures, a reasonable average
savings of 3.500 - 6,800 kWh is expected per project coming from 20-40 completed projects in
the remaining months of 2014.
Projected costs and savings for the first three years are provided
in Exhibit 2.
the cost effectiveness analysis
5 Gross savings at the customer site (does not include a net-to-gross adjustment or line loss adjustment). Assumes a
start date of 8lll20l4.
Exhibit 6 - Small Business Offer - Idaho - Filed August 2014
Page 8 of8