20140428Annual DSM 2013 Report.pdf

ROCKY MOUNTAIN
FOWER
: l.n
201 South Main, Suite 2300
Salt Lake City, Utah 8411'l
April28,2014
VA OWRNIGHT DELIVERY
Jean D. Jewell
Commission Secretary
Idaho Public Utilities Commission
472W. Washington
Boise,ID 83702-5983
Re: Annual2013Idaho Demand Side Management Report
Dear Ms. Jewell:
Rocky Mountain Power hereby submits for filing seven (7) copies of the 2013 Annual Demand
Side Management Report, pursuant to Order No. 29976 from Case No. PAC-E-05-10.
Rocky Mountain Power respectfully requests that all formal correspondence and requests
regarding this filing be addressed to one of the following:
By E-mail (preferred): [e-mail]
By regulator mail: Data Request Response Center
PacifiCorp
825 NE Multnomah Blvd., Suite 2000
Portland, OR 97232
For any informal questions, please contact Ted Weston, Manager, Idaho Regulatory Affairs, at
(80r)220-2963.
Sincerely,
?'Wr(Xo"",'"/cr'-Jeffrey K. L-arsen
Vice President, Regulation and Govemment Affairs
I
I
Idaho Energy Efficiency and
Peak Reduction Annual
Report
January 1,2013 - December 31,2013
Issued May 1,2014
xffi:::la
Rocky Power ldaho Report Table of Contents
T.c.nI,n oF CoNTENTS
List of Abbreviations and Acronyms............. ........................5
Executive Summary .......6
2013 Performance .......... ...............9
Regulatory History................. l0
Schedule l9l, Customer Efficiency Services Rate Balancing Account Summary................... I I
Planning Process
Evaluation..................28
Low Income Energy Conservation Education ................28
Page 3 of43
Rocky Mountain Power ldaho Report Table of Contents
Program Specific ..................... 4l
Home Energy Savings program.................... 4l
Residential Refrigerator Recycling
FinAnswer Express and Energy FinAnswer ..................42
Agricultural Energy Services..... .................42
Evaluations ................... 43
Page 4 of 43
Rocky Mountain Power Idaho Report Abbreviations and Acronyms
Lrsr or AnnRnvr,lTroNs AND AcRoNyMS
CFLs Compact Fluorescent Lights
CAPAI Community Action Partnership Association of Idaho
DSM Demand-Side Management
EICAP Eastern Idaho Community Action Plan
HVAC Heating, ventilation and air conditioning
IECC International Energy Conservation Code
IDHW Idaho Department of Health and Welfare
IRP Integrated Resource Plan
kwh Kilowatt hour
LEDs Light-emitting Diode Lights
LIHEAP Low Income Home Energy Assistance
MW Megawatt
NTG Net-to-Gross
PCT Participant Cost Test
PTRC Total Resource Cost Test with 10 percent adder
RIM Ratepayer Impact Measure Test
Schedule 191 Customer Efficiency Services Rate
SEICAA SouthEastern Idaho Community Action Agency
TRC Total Resource Cost Test
UCT Utility Cost Test
Page 5 of43
Rocky Mountain Power ldaho Report Executive Summary
ExscurrvE SUMMARY
Rocky Mountain Power ("Company") working in partnership with its retail customers and with
the approval of the Idaho Public Utilities Commission ("Commission") acquires energy
efficiency and peak reduction resources as cost-effective altematives to the acquisition of supply-
side resources. These resources assist the Company in efficiently addressing load growth and
contribute to the Company's ability to meet system peak requirements. Company energy
efficiency and peak reduction programs provide participating Idaho customers with tools that
enable them to reduce or assist in the management of their energy usage while reducing the
overall costs to the Company's customers. These resources are relied upon in resource planning
as a least cost alternative to supply-side resources.
This report provides details on program results, activities, expenditures, and Customer Efficiency
Service Charge - Schedule l9l ("Schedule l9l") - revenue for the performance period from
January l,2013,through December 31,2013. The Company, on behalf of its customers, invested
$3.9 million in energy efficiency resource acquisitions during the reporting period. The
investment yielded approximately 20.2 gigawatt-hours in frrst year savingsl and approximately
3.4 megawatts of capacity reduction from energy efficiency2. Net benefits based on the projected
value of the energy efficiency program savings over the life of the individual measures are
estimated at$2.4 million'. The cost effectiveness of the energy efficiency portfolio from various
perspectives is provided in Table 1.
The company also offers an irrigation load management program to agricultural customers in the
state of Idaho. The program is positioned as a system resource and as such its costs are not
recovered through Schedule l9l. Additional information on the irrigation load management
program is provided later in this report.
t Reported savings at generation.
2 See Appendix I for explanation on how the capacity contribution savings values are calculated.
3 See Table I - Utility Cost Test Net Benefits.
Page 6 of 43
Rocky Mountain Power Idaho Report Executive Summary
Table 1-CostEffective the En Effi PortfoliNCSS IOT tctencv ro lo
Benefit/Cost
Ratio
Net Benefits
Total Resource Cost Test plus l0 percent ("PTRC") - total resource cost with
the addition of environmental and non-energy benefits4 1.26 $1,754,222
Total Resource Cost Test ("TRC")'l.l5 $1,002,449
Utiliw Cost Test ("UCT").1 .51 $2.436.0s 1
Particioant Cost Test (*PCT")'1.95 $6.128.360
Ratepayer Impact ('RIM")o 0.63 ($4,661,724)
The energy efficiency portfolio was cost effective based on four of five standard cost
effectiveness tests for the reporting period. The ratepayer impact measure test was less than 1.0
indicating near-term upward pressure was placed on the price per kilowatt-hour given a
reduction in sales. Annual performance information for 2013 cost effectiveness is provided in
detail in Appendix 2.
In 2013, the Company completed development of the Technical Reference Library which
contains preliminary measure-level savings data, including the methods, assumptions and
sources for those assumptions used for reporting of energy savings. The Energy Efficiency
Measures report is provided in Appendix 3.
Another Company system implementation that began in 2013 was the upgrade of the tracking
system which is used by Demand-Side Management ("DSM") to store information on completed
customer projects. The system is known as DSM Central and integrates with the Technical
Reference Library.
The Company, working with its third-paty delivery administratorse collaborates with the
following number of retailers, contractors, and vendors in the delivery of its energy efficiency
programs in the state of Idaho:
o The TRC plus 10 percent includes a benefit adder to account for non-quantified environmental and non-energy
benefits of conservation resources over supply-side alternatives.t The TRC compares the total cost of a supply-side resource to the total cost of energy efficiency resources,
including costs paid by the customer in excess of the program incentives. The test is used to determine if an energy
efficiency program is cost effective from a total cost perspective.6 The UCT compares the total cost incurred by the utility to the benefits associated with displacing or defening
supply-side resources.
' The PCT compares the portion of the resource paid directly by participants to the savings realized by the
participants.t The RIM examines the impact of energy effrciency on utility rates. Unlike supply-side investments, energy
efficiency programs reduce energy sales. Reduced energy sales lowers revenues (see UCT) putting upward pressure
on rates as the remaining fixed costs are spread over fewer kilowatt-hours.9^' See program specific sections for backgrounds on third-party administrators.
PageT of43
Rocky Mountain Power Idaho Report Executive Summary
Table 2 -Energy Efficiency Infrastructure
Sector Twe No.
Residential Liehtins Retailers 22
Aooliances Retailers 23
HVAC T' Contractors t4
Insulation Contractors t7
Low Income Asencies 2
Commercial and Industrial Liehtine Trade Allies 52
FIVAC Trade Allies 29
Motors & VFD Trade Allies 28
Ensineerins Firms 22
r0 Heating, ventilation and air conditioning
Page 8 of43
l
Rocky Mountain Power Idaho Report Executive Summary
2013 Performonce
Program and Sector level results for 2013 are provided in Table 3.
Table 3
Idaho Program Results for January l,2Ol3 - December 31,201311
See Appendix 4 for breakdown of program expenditures by category.
rr The values at generation include line losses between the customer site and the generation source. The Company's
line losses by sector for 2013 are 11.47 percent for residential, 10.75 percent for commercial,7.52 percent for
industrial and 1 1.45 percent for irrigation.
Page 9 of43
Prosram
kWh/Yr
Savings
(at site)
kWh/Yr
Savings
(at senerator)
Program
Exnenditures
Low Income Weatherization (21)rot.77t 113"440 $ 203.741
Refriserator Recvclins ( I I 7)692,799 77223s $ 923s3
Home Enersy Savines (l l8)2.512.461 2,800,54',1 $ 825,450
Total Residential 3.307.037 3.686.222 $ 1.121.544
Enersy FinAnswer (125)425205 470.9rc s 74,625
FinAnswer Express (l l5)2207.504 2.M4.789 s 597,379
Total Commerrcial 2.632.709 2.91s.699 $ 672.004
Enersy FinAnswer (125)1,914,074 2.0s8.0s1 s 254249
FinAnswer Express (l I 5)2.979.385 3203494 $ 362.s73
Total Industrial 4.893.459 5.261.545 s 616.822
FinAnswer Express (1 15)169-154 188.519 $ 17.567
Aericultural Enersy Services ( 155)7.321.s43 8,159,713 $ 1"180"s75
Iotal Asricultural 7.490.697 8.348.232 s 1.198.143
Total Enersv Efrciency 18"323.902 20.211.698 3.608.512
Commercial & Industrial Evaluation Costs
Residential Evaluation Costs
Low Income Enerry Conservation Education
Technical Reference Library
DSM Central
Total System Benefit Expenditures - All Pmgrams
$
$
$
$
$
73,655
129,658
25,000
23,705
13,566
3,874,096
I
Rocky Mountain Power Idaho Report Regulatory History
Rrcul,q.roRY HrsroRY
During the reporting period the Company filed a number of compliance and/or informational
reports, updates and requests with the Commission in support of the Company programs. The
following is a list of those filings:
o On March 8, 2013, the Commission approved the Company's application filed on
December 7 ,2012, to cancel Irrigation Tariffs 72 and 72A and approve the new Irrigation
Load Control Contract.
On April 25,2013, pursuant to Order No.29976, the Company submitted its 2012Idaho
Energy Efficiency and Peak Reduction Annual Report.
On May 15, 2013, pursuant to Order No. 32788, the Company filed a revision to
Schedule 2l - Low Income Weatherization Services Optional for Income Qualifying
Customers, sheet no. 3, to include $25,000 for the low income conservation education
fund. The Commission approved the updated tariff sheet with an effective date of June l,
2013.
On May 24,2013, in Case No. PAC-E-13-10, the Company filed to revise Schedule 155
- Agricultural Energy Services to suspend: (1) the Nozzle Exchange Program; and (2)
incentives for the pivot and linear equipment measures listed in the tariff. The
Commission approved the request in OrderNo. 32879, effective August 15,2013.
On November 7, 2013, in Case No. PAC-E-13-15, the Company filed for approval of a
one-time customer credit to refund over collection of Schedule l9l Customer Efficiency
Services rate ("Schedule l9l"). The refund was approved by the Commission in Order
No. 32967 on January 23,2014.
Page l0 of43
I
Rocky Mountain Power Idaho Report Regulatory History
Schedule 191, Customer Efficiency Services Rate Baloncing Account Summary
In Case Number PAC-E-O5-10 (Order No. 29976) the Commission approved the recovery of all
DSM program costs through Schedule l9l, with exception of the expenses associated with the
irrigation load control program''. Schedule l9l charges appear as a line item on customer bills.
The Company books eligible DSM program costs as incurred to the balancing account.
Schedule I 9 I balancing account activity for 201 3 is outlined in Table 4.
Table 4
Schedule Balancin Account Activit
* December 2013 total accrual 283,317
Column Explanations:
Monthly Proeram Costs - Fixed Assets: Monthly expenditures for all energy efficiency program activities.
Monthly Net Accrued Costs: Monthly net change of program costs incurred during the period not yet
posted.
Rate Recovery: Revenue collected through Schedule l9l.
Carrying Charee: Monthly "interest" charge based on "Accumulated Balance" of the account. The current
"interest rate" for the Accumulated Balance is 1 percent per year.
Cash Basis Accumulated Balance: Cunent balance of the account - a running total of account activities. A
negative accumulative balance means cumulative revenue exceeds cumulative expenditures; positive
accumulative balance means cumulative expenditures exceed cumulative revenue.
Accrual Basis Accumulative Balance: Current balance of account including accrued costs.
'' The Commission, in Case No. PAC-E-10-07, ordered that the costs associated with the Idaho Irrigation Load
Control Program should be allocated as system costs and not situs to ldaho.
as of l2/3lll2
Monthly Monthly Net
Program Cost - Accrued
Fixed Assets Costs * Rate Recovery
Cash Basis Accrual Basis
Accumulated AccumulatedBalance Balance
(690,167) $ (370J53
(770378) S (359273
(637,366) $ (25e,r
(585910) $ (l7r
(4s6,170') s 07,791
(584268) $ (3
(e00,4ee) $ (654,8
(r,184,678) $ (941,4e3
(1,47s,929) $ (1,2r0,0r3
(1,634,799) $ (1,376,
(1,568,740) $ (
(1,459,953) $ (1,163,
$
(266,90) $ (608)'$
(253,184) $ (586) $
(226,s5s) $ (soe) $
(1e6,836) $ (434) $
(287,578) $ (433) S
(46r,103) $ (618) $
(634228) $ (868) $
(522,s02) $ (r,108) $
(403,843) $ (r,2%) $
(286J05) $ (r,334) $
(23s,147) $ (1,261) $
$
$
$
$
$
$
$
$
$
$
$
$
187,387 $
386,782 $
278,520 $
327,W9 $
159,9t4 $
148,490 $
350,917 $
232,359 $
246,269 $
353,699 $
345,194 $
9r,691 $
(32,874) $
35,772 $
(55,624) $
(e0J6l) $
(2r,930) $
(2,503) $
22,731 $
(8,033) $t42v $
23,813 $
$ (4,024,339) $ (10,042)$ 3,815,666
Page ll of43
a
Rocky Mountain Power ldaho Report Planning Process
Pu.rvxrxc Pnocrss
Integrated Reso urce Plan
The Company develops a biennial integrated resource plan ("IRP") as a means of balancing cost,
risk, uncertainty, supply reliability/deliverability and long-run public policy goals. The plan
presents a framework of future actions to ensure the Company continues to provide safe, reliable,
reasonable-cost service with manageable risks to its customers. Energy efficiency and peak
management opportunities are incorporated into the plan based on their availability,
characteristics and costs.
Energy efficiency and peak management resources can be divided into four general classes based
on their relative characteristics, the classes are:
o Class I DSM (Resources from fully dispatchable or scheduled firm capacity product
offerings/programs) - Capacity savings occur as a result of active Company control or
advanced scheduling. Once customers agree to participate, the timing and persistence of
the load reduction is involuntary on their part within the agreed limits and parameters.o Class 2 DSM (Resources from non-dispatchable, firm energy and capacity product
offerings/programs) - Sustainable energy and related capacity savings are achieved
through facilitation of technological advancements in equipment, appliances, lighting and
structures or sustainable verifiable changes in operating and maintenance practices, also
commonly referred to as energy efficiency resources.
o Class 3 DSM (Resources from price responsive energy and capacity product
offerings/programs) - Short-duration energy and capacity savings from actions taken by
customers voluntarily based on pricing incentives or signal.o Class 4 DSM (Resources from energy efficiency education and non-incentive based
voluntary curtailment programs/communications pleas) Energy and/or capacity
reduction typically achieved from voluntary actions taken by customers, to reduce costs
or benefit the environment through education, communication and/or public pleas.
As technical support for the IRP, a third-party analysis is conducted to estimate the magnitude,
timing and cost of altemative energy efficiency and peak management options.13 The main focus
of the study is on resources with sufficient reliability characteristics anticipated to be technically
feasible and assumed achievable during the IRP's 2}-year planning horizon. The estimated
achievable energy efficiency potential identified in the 2013 study for Idaho was 34 average
megawatts or I3 percent of retail sales.la By definition this is the energy efficiency potential that
may be achievable to acquire during the 20-year planning horizon if determined least cost and
cost-effective compared to supply-side alternatives within the Company's integrated resource
planning process.
" Assessment of Long-term, System-Wide Potential for Demand-Side and Other Supplemental Resources,
www.pacificorp.com/content/dam/pacificorp/doc/Energy_Sources/Demand_Side_Management/DSM_Potential_Stu
dy/Paci fi Corp_D SMPotential_FINAL_V olo/o20l.p df ,t4lbid, page 75.
Page 12 of 43
Rocky Mountain Power ldaho Report Planning Process
The achievable technical potential for Idaho by sector is shown in Table 5. The 2013 potential
study indicates that 5 percent of the achievable technical potential for the Company, excluding
oreionlt, is in ldaho.l6
Table 5
Idaho Energy Efficiency Achievable Technical Potential by Sector
Sector
Average Megawatts in
2032 Percent ofRetail Sales
Residential l6 l5o/o
Commercial 9 l5o/o
Industrial )8o/o
Irrigation 7 l0o/o
* Note there is an additional 0.2 aMW associated with street lights
Energy efficiency resources vary in their reliability, load reduction and persistence over time.
Based on the significant number of measures identified in the potential study it is difficult to
incorporate each measure as a stand-a-lone resource in the IRP. To address this issue, energy
efficiency measures are bundled by their relative cost to reduce the number of combinations to a
more manageable number.
The evaluation of energy efficiency resources within the tRP is also informed by state specific
evaluation criteria. While all states generally use commonly accepted cost effectiveness tests,
some states require variations in calculating or prioritizing the tests.
o Washington and Oregon utilize the total resource cost but allow for consideration of non-
energy benefits and a l0 percent regional conservation credit in the determination of cost
effectiveness.o Utah utilizes the utility cost test as the primary determination of cost effectiveness.
The Company evaluates program implementation cost effectiveness (both prospectively and
retrospectively) under a variation of five tests to identify the relative impact and/or value to
customers and the Company (i.e. utility cost, total resource cost, near-term rate impact, program
value to participants, etc.).
The 2013 Integrated Resource Plan preferred portfolio includes the acquisition of energy
efficiency resources. The plan seeks opportunities to accelerate these acquisitions as evidenced
by the range of the savings target and expanded set of demand side management related Action
Plan activities. The action plan savings targets for the 2013 Integrated Resource Plan 17 are
shown in Table 6.
rs Demand-side Management potential studies are performed by the Energy Trust of Oregon.
'u Page 75, Table 52 of the 2013 Assessment of Long-term, System-Wide Potential for Demand-Side and Other
Supplemental Resources.
" 2ol3IRP, April,2013,
www.oacificorp.com/content/dam/pacificorp/doc/Energy SourcesAntegrated_Resource Plan/20 I3lRP/PacifiCorp-
20 I 3IRP_Vol I -Main_4-30- I 3.odf, page 248.
Page 13 of43
Rocky Mountain Power Idaho Report Planning Process
Table 6
Preferred Portfolio Energy Efficiency Targets
2013 Prefened Portfolio I Acquire 1,425-1,876 gigawatt hours (GWh) of cost-effective Class 2
(energy efficiency) resources by the end of 2015 and2,034-3,180 GWh by
the end of20l7.
Page 14 of43
Rocky Mountain Power ldaho Report Peak Reduction Program
Pr,q.x RrnucTToN PRoGRAMS
Peak Reduction programs assist the Company in balancing the timing of customer energy
requirements during heavy use summer hours; deferring the need for higher cost investments in
delivery infrastructure and generation resources that would otherwise be needed to serve those
loads for a select few hours each year. These programs help the Company maximize the
efficiency of the Company's existing electrical system and reduce costs for all customers.
Irrigotion Load Control
The lrrigation Load Control program was offered to irrigation customers receiving electric
service on Schedule 10, Irrigation and Soil Drainage Pumping Power Service. Participants
enrolled with a third party to allow the curtailment of their electricity usage in exchange for a
participation credit. For most participants, their irrigation equipment is set up with a
dispatchable two-way control system giving the Company control over their loads. Under this
control option, participants are provided a day-ahead notification in advance of control events
and have the choice to opt-out of a limited number of dispatch events per season.
A summary of the program performance, participation and cost effectiveness results for the
program period of June 10,2013 - August 16,2013 are provided in Tables 7 and 8.
Table 7
Irrigation Load Control Program Performance
Total Enrolled MW (Gross - at Gen)219
Average Realized load (at Gen)150
Maximum Realized load (at Gen)186
Participation Customers 232
Participation (Sites)971
Table 8
Cost Effectiveness for lrrigation Load Control
Benefit/Cost
Ratio
Total Resource Cost Test plus l0 percent Pass
Total Resource Cost Test Pass
utility cost Test Pass
Particioant Cost Test N/A
Rate Payer Impact Pass
Program Management
The program manager who is responsible for the lrrigation Load Control program in Idaho is
also responsible for the lrrigation Load Control program in Utah. For each state the program
Page 15 of43
Rocky Mountain Power Idaho Report Peak Reduction Program
manager is responsible for the cost effectiveness of the program, contracting with program
administrator through a competitive bid process, establishing and monitoring program
performance and compliance, and recommending changes in the terms and conditions set out in
the tariff.
Program Administration
Starting with the 2013 program season, the Company selected EnerNoc to manage the irrigation
load control program through a pay-for-performance structure. See Appendix 5 for EnerNoc's
2013 PacifrCorp Inigation Load Control Program Report.
Load Control Events and Performance
There were ten control events initiated in 2013. The date, time and estimated
event is provided in Table 9.
for each
Table 9
Irrigation Load Control Events
Date Event Event Times
Estimated Load
Reduction - Idaho at Gen
(MW)
6/t8lt3 I 3om-7pm -15 I
6/28n3 2 3om-7om -182
7 /1113*3om-7om -128
7l2lt3 4 3pm-7pm -178
7t3lt3 5 3pm-7pm -l 86
7t9n3 6 3om-7om -172
7lt0lt3 7 3pm-7pm -l8l
7/t8lt3 8 3pm-7pm -162
7/25113 9 3om-7pm -88
7t26n3 l0 3om-7om -91
*Amps and Camas Subs excluded from dispatch
Performance of the Idaho Irrigation Load Control programs is contained in Appendix 6.
Page 16 of43
Rocky Mountain Power ldaho Report Residential Programs
Exrncy ErrrCrrxcY PROGRAMS
Energy efficiency programs are offered to all major customer sectors: residential, commercial,
industrial and agricultural. The overall energy efficiency portfolio includes six programs; Home
Energt Saver - Schedule ll8, Residential Refrigerotor Recycling- Schedule ll7, Low Income
Weatherization - Schedule 21, FinAnswer Express - Schedule ll5, Agricultural Energt Services
- Schedule 155 and Energt FinAnswer - Schedule 125. Program savings and cost results for
2013 were provided in Table 3. Additional program information is provided below.
RBsrnrxuAl PRoGRAMS
The residential energy efficiency portfolio is comprised of three programs, Home Energt Sover,
Residential Refrigerator Recycling and Low Income Weatherization. As shown in Table 10, the
residential portfolio was cost effective based on four of the five standard cost effectiveness tests
for the 2013 reporting period. The ratepayer impact test was less than 1.0 indicating that there is
near term upward pressure placed on the price per kilowatt-hour given a reduction in sales.
Table l0
Cost Effectiveness for Residential Portfolio
Benefit/Cost
Ratio
Net Benefits
Total Resource Test plus l0 percent 1.40 $614.9s5
Total Resource Cost Test t.28 $43s.742
Utility Cost Test 1.20 $2s3,336
Particioant Cost Test 4.03 $2,814,578
Rate Payer Impact 0.45 ($1,803,429)
Home Energlt Saver Program
The Home Energt Saver program is designed to provide access to and incentives for more
efficient products and services installed or received by customers in new or existing homes,
multi-family housing units or manufactured homes for residential customers under Electric
Service Schedules 1 and 36. Program participation by measure is provided in Table I 1.
Table I I
Eligible Program Measures (Units)
Measures 2013 Total
Units
2013 Total
Participants
2013 kwh
@ site
Attic Insulation 280.979 43 356.781
Central A"/C Equipment I I 98
Clothes Washer 491 490 66.833
Dishwasher 225 225 9.530
Page 17 of43
Rocky Mountain Power Idaho Report Residential Programs
Measures 2013 Total
Units
2013 Total
Participants
2013 kwh
@ site
Ductless Heat Pump t6 t6 56,000
Electric Water Heater t9 l9 2,569
Evaporative Cooler 4 4 I,708
Fixture 12.068 728 291.s02
Floor Insulation 3.896 3 9 217
Gas Furnace 5 5 2,640
Ground Source Heat Pump Conversion 12.525
Heat Pump System Conversion 2 2 t0.332
Heat Pump Water Heater 4 4 3,524
Refrigerator 61 6t 5.269
Room AC 4t 39 1,599
Wall Insulation ) )\)2 3,386
Windows 2,420 l9 6.r63
Lighting - CFL General 75.351 7,535 t,259,629
Lighting - CFL Specialty 18.230 r.823 413.142
Grand Total 396,066 I1,020 2-512.467
Program perforrnance results for January 1,2013 - December 31,2013 are provided in Table 12.
Table 12
Long-term Cost Effectiveness for Home Energy Saver Program
Benefit/Cost
Ratio
Net
Benefits
Benefit/Cost
Ratio
Net
Benefits
I nc luding Non-e nergt bene fi ts Exc luding No n-e nergt be nefi ts
Total Resource Cost Test olus l0 Dercenl 1.66 s726.220 t.24 s263.502
Total Resource Cost Test 1.54 $601.741 l.l3 $ r 39,023
Utility Cost Test l.5l $4 r 9,335 1.51 $4 19,335
Participant Cost Test 3.27 s2.114.020 2.69 $ l,571,91 l
Rate Payer Impact 0.49 ($ l .284.893)0.49 ($ 1.284.893)
Proqram Management
The program manager who is responsible for the Home Energt Saver program in Idaho is also
responsible for the Home Energt Saver program in California, Utah, Washington and Wyoming
and the Refrigerator Recycling program in ldaho, California, Utah, Washington, and Wyoming.
For each program and in each state the program manager is responsible for the cost effectiveness
of the program, identifying and contracting with the program administrator through a
competitive bid process, establishing and monitoring program performance and compliance, and
recommending changes in the terms and conditions set out in the tariff.
Page 18 of43
Rocky Mountain Power Idaho Report Residential Programs
Program Administration
The Home Energt Saver program is administered by PECI. PECI, a private non-profit
corporation, has been designing and implementing energy efficiency programs since 1990.
PECI is responsible for the following:
Retailer and trade ally engagement - PECI identifies, recruits, supports and assists
retailers to increase the sale of energy efficient lighting, appliances and electronics. PECI
enters into promotion agreements with each lighting manufacturer and retailer for the
promotion of discounted compact fluorescent lighting ("CFL"). The agreements include
specific retail locations, lighting products receiving incentives and not-to-exceed annual
budgets. Weatherization and HVAC contractors engaged with the program are provided
program materials, training and receive regular updates.
Inspections - PECI recruits and hires inspectors to verify on an on-going basis the
installation of measures. A summary of the inspection process is in Appendix 7.o Incentive processing and call-center operations - PECI receives all requests for
incentives, determines whether the applications are completed, works directly with
customers when information is incorrect and/or missing from the application and
processes the application for payment.
o Program specific customer communication and outreach A summary of the
communication and outreach conducted by PECI on behalf of the Company is outlined in
the Communication, Outreach and Education section.
Infrastructure
The Company, through its third party vendor, is working with 22 retailers to promote CFLs and
light-emitting diodes ("LEDs"). Table 13 lists the lighting retailers participating in the program.
Table 13r8
Retail Stores - Lighting
Store Name Citv CFLs LEDs
Ace Hardware#14355 Rexburg
Ace Hardware#9479 Saint Anthony
BMC West - Rexburg Rexburg {./
Broulim's Fresh Foods #l Montpelier ./
Broulim's Fresh Foods #2 Rexburg
Broulim's Fresh Foods #3 Saint Anthony
" To be considered for participation for discounted CFLs and LEDs, sales coming from the Company's customers
must be a significant majority of total sales.
Page 19 of43
Rocky Mountain Power Idaho Report Residential Programs
Store Name City CFLs LEDs
Dollar Tree #3691 Rexburg {
Downey Food Center Downey {
Mickelsens #2 Rexburg {
Platt Electric Supply #53 Pocatello ./{
Platt Electric Supply #54 Idaho Falls {
Platt Electric Supply #88 Rexburg {./
Thomas Market Inc. #1 Malad City ./
True Value #0l 19 Preston {./
True Value #0217 Montpelier {i
True Value #064 Malad City {
True Value #6s4 Rexburg
True Value #5448 Terreton
True Value Hardware - CAL Ranch Stores Rexburg {
Walgreens #9918 Rexburg ./
Walmart #1878 Rexburg {
Wolfe Lighting Rexburg {
Twenty three local and national retailers now consistently promote high efficiency appliances on
behalf of the program. Table l4re lists the retailers whire customers can purchase program
qual ifying app I iances for program incentives.
Table l4
Retail Stores - Appliances
Retailer City
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o
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od
Ace Hardware #14355 Rexburg
Ace Hardware #9479 Saint Anthony
Best Buy #944 Idaho Falls {./
Bingham & Sons Furniture and Appliance Rexburg {./
Blacker's Home Furnishings Idaho Falls {./
Denning's Showcase Idaho Falls ./././
Do It Best - Stronks and Sons Ashton {{
Do It Best - Yellowstone Rigby
El Gene's TV and Appliance Rexburg ./
re Check mark indicates retailer participation during 2013
Page20 of 43
Rocky Mountain Power Idaho Report
Retailer Citv
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Falls Plumbing Supply Idaho Falls {
Ferguson Enterprises Inc Idaho Falls ./{
First Street Plumbing Idaho Falls
Home Depot #1802 Idaho Falls ^/./{,{./{
Lowe's #1906 Idaho Falls {{{{./
Northgate Appliance Idaho Falls {{{
Rocknacks Hardware Plus Idaho Falls ./
Sanders Furniture Soda Springs {{
Sears#2278 Idaho Falls {{./,/
Sears #3290 Rexburg {{./{
Thomas Electric & Furniture Malad City ,/
True Value #10217 Montpelier ./{
U&I Furniture Preston
Wolfe Lighting #l Rexburg {
Table l5 and Table 1620 list the HVAC, weatherization and window contractors.
Table l5
HVAC Contractors
Trade Allv Name City
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Alpine Heating Idaho Falls
Conan Heating Idaho Falls {.J
20 Check mark indicates retailer participation during 2013
Page2l of 43
Rocky Mountain Power Idaho RePort Residential Programs
Trade Ally Name ciw
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Ductz of Post Falls Post Falls
First Call Jewel, Inc Idaho Falls ./{{{
Hallmark Exteriors Ammon
Holeshot Plumbing Ammon
Johnson Brothers Idaho Falls
Malad Heating and
Coolins LLC
Malad
Citv
Master Tech LLC Rigby ./
Palmer Heating and
Coolins LLC Idaho Falls
Quantum Group
Ensineerins Idaho Falls
Sermon Service and
Electric Idaho Falls
Sprinter Heating and
Hydronics Rigby
Young Electric, Heating
and Air Shelley ./
Table l6
Weatherization Contractors
Trade Allv Name City
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oo
IL
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cO>
BoE.>
Alpine Heating Idaho Falls ^/
Advanced Insulation Idaho Falls
BDI Insulation of Idaho Falls Idaho Falls
Bi-State Siding & Windows,
Inc Lewiston
Page22 of 43
Rocky Mountain Power Idaho Report Residential Programs
Trade Allv Name Cifv
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BMC Wesl Idaho Falls ./
Campbell's Quality Exteriors Idaho Falls
Classic Remodeling Ogden
Clearwater Custom Carpentry
& Construction Lewiston
Eco Insulation Blackfoot ./
First Call Jewel Idaho Falls
Go Green Insulation Caldwell
Hallmark Exteriors Ammon
Hansen Paint & Glass Preston
Holeshot Plumbing Ammon
Newt Construction LLC Idaho Falls
Precision Glass Pocatello
Rocky Mountain Insulation Pocatello {
Demographics
Approximately 64 percent of all Home Energt Savers incentive applications in 2013 were
received from customers located in Idaho Falls, Rigby, Rexburg, and Ammon. Table 17
summarizes customer applications by city.
Table l7
Customer Application by City
City
%o ofTotal -
Appliance &
Fixture
Annlications
% ofTotal -
HVAC
Applications
o/o of Total -
Weatherization
Applications
o/o of Total -
Alt
Applications
IDAHO FALLS 25.80Yo 27.30o/o 12.50o/o 25.30o/o
RIGBY 14.600/o 3.00o/o 7.80Yo 14.lUYo
REXBURG 12.800/o 6.10o/o 32.80%13.40Yo
AMMON tt.t0%18.20%15.60%11.40%
SHELLEY 5.20o/o 9.10o/o 6.30Yo 5.30%o
PRESTON 4.50o/o 0.00%9.40o/o 4.60%
SUGAR CITY 2.600/o 0.00o/o 3.100/o 2.60%
SAINTANTHONY 2.20o/o 3.00o/o l.60Yo 2.20o/o
IONA 1.80o/o 0.00%0.00%1.70%
MALAD CITY 1.40o/o 3.00%0.00%1.30o/o
PageZ3 of 43
Rocky Mountain Power Idaho Report Residential Programs
City
% of Total -
Appliance &
Fixture
Anolications
% ofTotal -
HVAC
Applications
% of Total -
Weatherization
Applications
Yo of Total -
All
Applications
ASHTON 1.300/o 0.00Yo 0.00%1.20o/o
FIRTH 7.00o/o 9.100/o 0.00o/o l.l0o/o
UCON 0.80%3.00%3.10o/o 1.00o/o
45 Additional Cities < lYo
Evaluation
During 2013, a process and impact evaluation was initiated by a third party evaluator for
program years 201 l-2012. The process and impact evaluation was completed in first quarter of
2014.
Refr iger ato r Recy c li n g
The Refrigerator Recycling program, also known as "See yo later, refrigerator@," is designed to
decrease electricity use through voluntary removal and recycling of inefficient refrigerators and
freezers for residential customers served on Electric Service Schedule l. Participants receive a
$30 incentive for each qualifying refrigerator or freezer recycled through the program and an
energy-saving kit which includes two CFLs, a refrigerator thermometer card, energy-savings
educational materials, and information on other efficiency programs relevant to residential
customers.
Program participation by measure is provided in Table 18.
Table 18
Eligible Program Measures (Units)
Measures 2013
Total
2013 kwh
@ site
Refrieerator Recvcline 437 520,030
Freezer Recycline r29 134,289
Energv Savines Kit 520 38,480
Program performance results for January 1,2013 - December 31,2013 are provided in Table 19.
Page24 of 43
Rocky Mountain Power ldaho Report Residential Programs
Table l9
Long-term Cost Effectiveness for Refrigerator Recycling
BenefiUCost
Ratio
Net
Benefits
Total Resource Cost Test plus l0 percent 1.63 s58.099
Total Resource Cost Test 1.48 s44.421
Utility Cost Test 1.48 s44-421
Participant Cost Test 'N/A $377, l 35
Rate Payer Impact 0.48 (s149.359)
ln2013, more than 73,580 pounds of metal, 11,320 pounds of plastics, and l,3ll pounds of
tempered glass were recycled as a result of the program. In addition, the capture, recovery or
destruction of more than 737 pounds of ozone depleting Chlorofluorocarbons (greenhouse gases)
and Hydro fluorocarbons, commonly used in refrigerants and foam insulation equates to
approximately 2,143 metric tons of carbon dioxide.
Pro8ram Manaqement
The program manager who is responsible for the Refrigerator Recycling program in Idaho is also
responsible for the Refrigerator Recycling program in California, Utah, Washington and
Wyoming and Home Energt Saver program in Idaho, California, Utah, Washington, and
Wyoming. For each program and in each state the program manager is responsible for the cost
effectiveness of the program, identiffing and contracting with the program administrator through
a competitive bid process, establishing and monitoring program performance and compliance,
and recommending changes in the terms and conditions set out in the tariff.
Pro gram Administration
The Refrigerator Recycling program is administered by JACO Environmental ("JACO"). JACO
started over 20 years ago in Snohomish County, north of Seattle, Washington, JACO has grown
to become one of the largest recyclers of house-hold appliances in the United States. The
Company contracts with JACO to provide customer scheduling, pick-up, incentive processing
and marketing services for the program.
JACO's process ensures that over 95 percent of the components and materials of the discarded
appliance are either recycled for beneficial uses or eliminated in an environmentally responsible
way. The remaining 5 percent can then be productively used as "fluff' to facilitate the
decomposition of biodegradable landfi ll material.
JACO is responsible for the following:
. Appliance handling - JACO handles all customer and field service operations for the
program including pick-up of refrigerators and freezers from customers, transporting the
units to the de-manufacturing facility and recycling of the appliances.
2r Participants in See ya later, refrigerotortD program incur no costs.
Page25 of 43
Rocky Mountain Power Idaho Report Residential Programs
o Incentive processing and call-center operations - Customer service calls, pick-up
scheduling and incentive processing are handled by JACO.o Program specific customer communication and outreach - Working in close coordination
with the Company, JACO handles all the marketing for the program. The program is
marketed through bill inserts, customer newsletters and TV, newspaper and online
advertising.
As part of the program control process, the Company contracts with a third-party independent
inspector to conduct ongoing oversight of the program's appliance recycling process, from
verification that the units being recycled meet the program eligibility criteria to verifying they
are being recycled and that the program records are accurate.
A summary of the inspection process is included in Appendix 7.
Infrastructure
A crew from Salt Lake City, Utah, picks up units collected through the program in Idaho and
transports the units to a JACO facility in Salt Lake City for disassembly and recycling.
Evaluation
In October 2013, a process and impact evaluation was completed by a third party evaluator for
program years 201 l-2012. The impact evaluation provided data on the gross realized savings and
the Net-to-Gross ("NTG") ratio. The process evaluation investigated participant satisfaction,
implementation and delivery processes, marketing methods and quality assurance. The
Company's response to the recommendations and web link to the evaluation report are included
in Appendix 8.
Low Income Weatherization
The Low Income Weatherizotion program provides energy effrciency services through a
partnership between the Company and local non-profit agencies to residential customers that
meet the income-eligible guidelines. Services are at no cost to the program participants.
Program participation and number of homes receiving specific measures in 2013 are provided in
Table 20.
Table 20
Homes Receiving Specific Measures
Participation - Total # of Completed/Treated Homes 74
Number of Homes Receivinp Soecilic Measures
Attic Ventilation 23
Ceiline Insulation 26
Page26 of 43
Rocky Mountain Power Idaho Report Residential Programs
Comoact Fluorescent Lisht Bulbs 68
Duct Insulation l9
Floor Insulation 20
Furnace Reoair 34
Health & Safety Measures 26
Infiltration 47
Refrieerators J
Reolacement Windows 38
Thermal Doors 35
Wall Insulation 6
Water Heater Repair 6
Water Pipe Insulation 58
Program perfonnance results for January I , 2013 - December 31, 2013 are provided in Table 2 I .
Table 2l
Cost Effectiveness for Low Income Weatherization
Benefit/Cost
Ratio
Net
Benefits
Total Resource Cost Test plus I 0 Dercent 0.81 ($39.705)
Total Resource Cost Test 0.60 ($80.763)
Utiliw Cost Test 0.60 (s80.763)
Particioant Cost Test N/A $323,423
Rate Payer Impact 0.34 ($239.5 l 9)
As shown in Table 21, the Low Income Weatherization program ex-ante results suggest the
program was not cost effective based on the five standard cost effectiveness tests for the 2013
reporting period. This is largely due to a decrease in number of homes served and measures
installed by over 28 percerrt from the program's 2012 program results and a decrease in the
Company's avoided costs." All applicable and identifiable non-energy benefits recommendedin Order No. 32788 were applied. The Company is investigating possible program
improvements while awaiting the results of the 2014 program evaluation before making a
determination on what broader actions will be necessary to ensure program cost effectiveness
going forward.
Program Management
The program manager who is responsible for the Low Income Weatherization program in Idaho
is also responsible for the Low Income Weatherization program in California, Utah, Washington
and Wyoming; energy assistance programs in Idaho, California, Oregon, Utah, Washington and
Wyoming; and bill discount programs in California, Utah and Washington. The program
manager is responsible for the cost effectiveness of the weatherization program in each state,
" The2Ol3Integrated Resource Plan filed in March, 2013, generated lower avoided costs for energy efficiency
resources than the value previously provided in the Company's 201 I Integrated Resource Plan and used in the
calculation of the program's economics inlhe2012 annual report.
Page27 of 43
Rocky Mountain Power Idaho Report Residential Programs
partnerships and agreements in place with local agencies that serve income eligible households,
establishing and monitoring program performance and compliance, and recommending changes
in the terms and conditions set out in the agency contracts and state specific tariffs.
Program Administration
The Company currently has contracts in place with Eastem Idaho Community Action Partnership
("EICAP") and SouthEastern Idaho Community Action Agency ("SEICAA") to provide services
through the low income weatherization program. These two agencies receive federal funds
allocated to the Idaho Department of Health and Welfare ("IDHW") and administered by the
Community Action Partnership Association of ldaho ("CAPAI") through subcontracting non-
profit agencies. Energy efficiency measures are installed in the homes of income eligible
households throughout the Company's service area by EICAP and SEICAA. Company funding
of 85 percent of the cost of approved measures is leveraged by the agencies with the funding
received by IDHW.
By contract with the Company, EICAP and SEICAA are responsible for the following:
o Income Verification - Agencies determine participants are income eligible based on
CAPAI guidelines. Household's interested in obtaining weatherization services apply
through the agencies. The current income guidelines are included in Appendix 9.o Energy Audit - Agencies use a United States Department of Energy approved audit tool
to determine the cost effective measures to install in the participant's homes (audit results
must indicate a savings to investment ratio of 1.0 or greater).
o Installation of Measures - Agencies install the energy efficiency measures.o Post Inspections - Agencies inspect 100 percent of completed homes.
CAPAI also inspect a random sample of homes. See Appendix 7 for
IDHW and
verification
summary.o Billing Notification - Agencies are required to submit a billing to Company within 120
days after job completion. The agencies include a form indicating the measures installed
and associated cost on each completed home along with their invoice.
Evaluation
The Low Income Weatherization program will be evaluated in 2014 by Smith & Lehmann
Consulting. This firm was selected through an RFP process and will complete the evaluation by
the end of 2014.
Low Income Energy Conservation Educotion
Commission Order No. 32788 dated April 12,2013, ruled that the Company's funding of Low
Income Energt Conservotion Education should be $25,000 annually. These services are
provided by EICAP whose main office is located in Idaho Falls, Idaho, and SEICAA whose
main office is in Pocatello, Idaho. They target the Company's customers that receive Low
Income Home Energy Assistance ("LIHEAP") funds. EICAP, SEICAA and the Company staff
discussed the allocation of the annual funding amount and the agencies determined the efficiency
Page28 of 43
Rocky Mountain Power Idaho Report Residential Programs
measures they wanted to distribute. These measures were discussed with Commission staff.
EICAP received $13,250 and SEICAA $l1,750 for a total of $25,000 prior to the beginning of
their 2013/2014 LIHEAP program year. While the conservation education activities do result in
energy savings, the savings are not considered when calculating the performance results of the
Low Income Weatherization program, other energy efficiency programs or portfolios results.23
The agencies provided a conservation education curriculum to households and reported the
following activities and program specifics for 2013:
Eastern Idaho Communitv Action Partnership
Number households served: 679
Number kits distributed: 679
cost of each kit: $19.50/kit, $13,240.50 in total
Items in kits: 1 showerhead, I window insulation kit, l0 outlet gaskets, l0 switch plate gaskets,
rope caulk, I compact fluorescent light bulb (20 watt), I compact fluorescent light bulb (13
watt), I refrigerator thermometer, I hot water temperature card, I bath aerator, I kitchen aerator,
I night light, Teflon tape and I air filter whistle
Program design: Educate the Company's customers on how to conserve energy and understand
their bill.
Target audience: The Company's customers receiving energy assistance.
Gauge program's success in meeting goals: Acceptance of energy conservation tools after
education.
Indicate how Company funds are used: Purchase items that encourage energy conservation.
Describe how the program benefits participants: Households receive useful tips and tools to help
them save energy while applying for LIHEAP.
SouthEastern Idaho Community Action Aeency
Number households served: 128
Number old kits distributed: 75
Number of new measures distributed: shower timers :27 , night lights : 26
Cost of new measures: shower timers : $2.63 each, night lights : $2.95 each, total cost incurred
of new measures purchased : $7,681.30
Program design: Reduce electricity usage and monthly bills for participants of the LIHEAP
program.
" O.de. No. 32788
Page 29 of 43
Rocky Mountain Power Idaho Report Residential Programs
Target audience: LIHEAP recipients that have not had weatherization program services as a
high priority. Households can also be identified through SEICAA's other programs. The
Company may refer customers for possible participation using current LIHEAP income
guidelines as the first criteria.
Gauge program's success in meeting goals: The program's success will be gauged through
periodic reporting and the response from the participants through surveys.
Indicate how Company funds are used: To purchase energy conservation measures (energy
saving night lights and shower timers). Funds are also used for educator salaries.
Describe how the program benefits participants: Households are educated on how they can
reduce kWh usage through behavioral changes as well as the installation and benefits of the
energy conservation measures they receive during LIHEAP intake.
SEICAA is continuing to distribute kits purchased from the Company funding provided in 2010.
These kits include I compact fluorescent light bulb (13 watt), I compact fluorescent light bulb
(19 watt), I compact fluorescent light bulb (23 watt), l0 outlet gaskets, I kitchen aerator, I
refrigerator temperature card and I night light. As of l2l3lll3 they have 106 old kits yet to
distribute.
Page 30 of43
Rocky Mountain Power Idaho Report Commercial and Industrial Programs
CorrtrurnclAl AND INDUSTRIAL PNOCRAUS
The commercial and industrial energy efficiency portfolio is comprised of three programs,
FinAnswer Express, Agricultural Energt Services and Energt FinAnswer. The commercial and
industrial portfolio was cost effective based on four of the five standard cost effectiveness tests
for the 2013 reporting period, as provided inTable 22.
Table22
Cost Effectiveness for Commercial and Industrial Portfolio
Benefit/Cost
Ratio
Net Benefrts
Total Resource Test plus l0 percent .24 $l,201.s37
Total Resource Cost Test t2 $628.978
utilitY cost Test .64 $2,244,985
Participant Cost Test .60 $3,3 r 3.782
Rate Paver Impact 0.70 (2.796.02s)
FinAnswer Express
The FinAnswer Express program is designed to help commercial and industrial customers
improve the efficiency of their new or replacement lighting, HVAC, motors, building envelope,
and other equipment by providing prescriptive or pre-defined incentives for the most common
efficiency -iaiu."r listed in the program incentive tables.2a The program also includes custom
incentives and technical analysis services for measures not listed in the program incentive tables
that improve electric energy efficiency. The program provides incentives for both new
construction and retrofit projects, and is designed to operate in conjunction with the Energy
FinAnswer program. Program participation by measure group is provided in Table 23.
2a Incentive tables can be found online at
https://www.rockymountainpower.net/content/dam/rocky_mountainjower/doc/Business/Save_Energy_Money/ID_
FinAnswerExpress_Brochure_Retrofi t.pdf for retrofits and
https://www.rockymountainpower.net/content/dam/rocky_mountainlrower/doc/Business/Save_Energy_Money/ID_
FinAnswerExpress_Brochure_NCMR.pdf for new construction/major renovation projects
lnstalled
Buildine Shell
Page 3l of43
Rocky Mountain Power Idaho Report Commercial and Industrial Programs
Program savings by measure group is provided inTable 24.
Table24
lnstalled Program Measures (gross kWh/year at site)
Measure Groups 2013 Total
Buildine Shell 150.075
Compressed Air 56.783
Dairv Farm Eouipment t69.154
Food Service 46.424
HVAC 455.257
Liehtins 4.478.350
Proqram Total 5.356.043
Program performance results for January 1,2013 - December 31,2013 are provided in Table 25.
Table 25
Cost Effectiveness for FinAnswer Express
Benef,rVCost
Ratio
Net Benefits
Total Resource Test plus l0 percent 1.58 $849"841
Total Resource Cost Test 1.44 $639.09s
utiliw cost Test 2.16 st-129.944
Particioant Cost Test 2.63 s2.690.900
Rate Payer Impact 0.61 ($ 1,367,018)
Program Management
The program manager who is responsible for the FinAnswer Express program in Idaho is also
responsible for the FinAnswer Express program in California, Utah, Washington and Wyoming
and the Agricultural Energt Services program in Idaho. For each state the program manager is
responsible for the cost effectiveness of the program, identifying and contracting with the
program adminisffators through a competitive bid process, program marketing, establishing and
monitoring program performance and compliance, and recommending changes in the terms and
conditions of the program.
Proeram Administration
The program is primarily marketed through local trade allies who receive support from one of
two program administrators hired by the Company. The Company contracts with Nexant, Inc.
('Nexant") and Cascade Energy ("Cascade") for trade ally coordination, training and application
processing services for commercial and industrial/agricultural measures respectively.
Nexant and Cascade are responsible for the following:
Page 32 of 43
Rocky Mountain Power Idaho Report Commercial and Industrial Programs
o Trade ally engagement - Nexant and Cascade identify, recruit, train, support and assist
trade allies to increase sales and installation of energy efficient equipment at qualifying
business customer facilities.
o Incentive processing and administrative support - Nexant and Cascade handle incoming
inquiries as assigned, process FinAnswer Express incentive applications, develop and
maintain simplified analysis tools and provide program design services, evaluation and
regulatory support upon request.
o Inspections - Nexant and Cascade verify on an on-going basis the installation of
measures. Summary of the inspection process is in Appendix 7.
In addition, the Company's project managers coordinate FinAnswer Express projects and
provide customers with program services and incentives using the energy engineering
consultants described further in the Energy FinAnswer program section.
Infrastructure
To help increase and improve the supplier and installation contractor infrastructure for energy-
efficient equipment and services, the Company established and developed trade ally networks for
lighting, HVAC and motors. This work includes identifying and recruiting trade allies, providing
program and technical training and providing sales support on an ongoing basis. The current list
of the trade allies who have applied and been approved as participating vendors are posted on the
Company website and included as Appendix l0 to this report. Customers are not required to
select a vendor from this list to receive an incentive.
The total number of participating trade allies is currently 91. The current count of participating
trade allies by technology is in Table 26.
Table 26
Participating Trade Al lies2s
Lighting trade allies HVAC trade allies Motor and VFD
trade allies
List dated 41312013 52 29 28
Evaluation
In February 2013, a process and impact evaluation was completed by a third party evaluator for
program years 2011-2012. The impact evaluation provided data on the gross realized savings and
the NTG ratio. The process evaluation investigated participant satisfaction, implementation and
delivery processes, marketing methods and quality assurance. The Company's response to the
recommendations and web link to the evaluation report are included in Appendix 8.
" Some trade allies may participate in more than one technology so the count of unique participating firms is less
than the total count by technology.
Page 33 of43
Rocky Mountain Power Idaho Report Commercial and lndustrial Programs
Agric ult ural E nergt Services
The lrrigation Energt Savers program is designed to improve the overall energy efficiency of
irrigation systems by promoting energy efficient irrigation practices and the installation of
energy efficient measures for customers on Schedule l0 and who qualify as a o'Farm Load"
under the Pacific Northwest Electric Power Planning and Conservation Act, P.L. 96-501. The
program also complements the Inigation Load Control program by focusing on improving the
effrciency and management of these seasonal loads.
In an effort to address the "high degree of uncertainty regarding the program energy savings"
identified through third party evaluations, the Company filed to revise Schedule 155 -
Agricultural Energy Services to suspend: (l) the Nozzle Exchange Program; and (2) incentives
for the pivot and linear equipment measures listed in the tariffon May 24,2013 (Case No. PAC-
E-13-10). The Commission approved the request in OrderNo. 32879, effective August 15,2013.
The 2013 program included the following:
o Equipment exchange - Provides new standard brass sprinkler nozzles, gaskets, and drains
to replace worn equipment on hand lines, wheel lines and solid set sprinklers systems.
This offer ended effective August 15,2013.
o Pivot and linear equipment upgrades - Incentives were provided for certain pivot and
linear system measures including sprinkler packages, pressure regulators, and drains. The
list of prescriptive incentives that were available until August 15,2013 was not designed
to be exhaustive and other pivot measures are eligible for incentives if energy savings can
be calculated and the customer incurs costs to make the changes.. System consultation - This service provides a simple site specific audit of a customer's
irrigation system to promote irrigation water management and identify energy savings
opportunities. This consultation provides information prior to a full pump test.o Pump testing - The pump test includes directly measuring pump lift, flow, electrical
demand, and system pressures and is performed after the pump has been screened and the
owner' s financial investment criteria understood.o System Analysis - The program provides energy engineering to help growers quantify
the costs and savings of their system efficiency upgrades. Often these upgrade decisions
are made in conjunction with operational production change considerations impacting a
growers equipment needs. Incentives are based on a standard formula tied to costs and
first year energy savings.
A summary of the program savings by measure group for 2013 is provided inTable?T.
2013 Total
7.321.543
site)
Page 34 of 43
Rocky Mountain Power Idaho Report Commercial and Industrial Programs
Program performance results for January 1,2013 - December 31,2013 are provided in Table 28.
The cost effectiveness for the system redesign measure group is being provided to show its
results in support of Order No. 32879 that was approved August 15, 2013 .
Table 28
Cost Effectiveness for Agricultural Energy Services
Benefit/Cost
Ratio
Net Benefits Benefit/Cost
Ratio
Net Benefits
Prosram Level Svstem Redesisn Level
Total Resource Test plus l0 percent 0.92 ($219.310)2.43 $ 1.544.965
Total Resource Cost Test 0.84 (s458.284)2.21 $ l .30s.992
Utility Cost Test t.t4 s289,167 5.41 $ r .948.1 l2
Participant Cost Test 0.86 (444.822)r.00 $6.471
Rate Payer Impact 0.78 (s904.624\2.39 $1.376.221
The results for TRC plus 10 percent and the TRC are not cost effective at the program level
which was expected. The Company encountered an increase of nozzle exchanges and pivot and
linear equipment upgrades as a result of qualifying customers learning of the application filing
submitted with Commission for program changes.
Program Management
The program manager who is responsible for the Itigation Energt Savers program in ldaho is
also responsible for the FinAnswer Express program in ldaho, California, Utah, Washington, and
Wyoming. For each program and in each state the program manager is responsible for the cost
effectiveness of the program, identifying and contracting with the program administrators
through a competitive bid process, program marketing, establishing and monitoring program
performance and compliance, and recommending changes in the terms and conditions set out in
the tariff.
Program Administration
The program was primarily marketed through irrigation specialists, trade allies and retailers
serving local irrigators. These efforts in 2013 were supported by the program administrator,
Nexant.
The Company contracted with Nexant to provide trade ally coordination and application
processing services for Itigation Energt Savers program. Nexant was responsible for the
following:
Trade ally engagement - identify, recruit, train, support and assist trade allies to increase
sales and installation of energy efficient equipment at qualifying customer site.
Incentive processing and administrative support - handle incoming inquiries as assigned,
process incentive applications and provide program design services, evaluation and
regulatory support upon request.
Page 35 of43
Rocky Mountain Power Idaho Report Commercial and Industrial Programs
o Inspections - verify equipment installation on a sample basis for Equipment Exchange
and every installation for System Analysis.o Engineering analysis - provide site specific engineering as required by the program for
System Analysis.
Infrastructure
To help increase and improve the supplier and installation contractor infrastructure for energy-
efficient equipment and services, the Company developed trade ally networks for irrigation
equipment. The current lists of the trade allies who are participating vendors are posted on the
Company website26.
Evaluation
In May 2013, a process and impact evaluation was completed by a third party evaluator for
program years 201l-2012. The impact evaluation provided data on the gross realized savings and
the NTG ratio. The process evaluation investigated participant satisfaction, implementation and
delivery processes, marketing methods and quality assurance. The Company's response to the
recommendations and web link to the evaluation report are included in Appendix 8.
Energlt FinAnswer
The Energt FinAnswer program is offered to all non-residential new construction, retrofit
commercial (buildings 20,000 square feet and larger) and industrial customers. The program is
designed to target comprehensive projects requiring project specific energy savings analysis and
operates in concert with the more streamlined FinAnswer Express program. The program
provides Company-funded energy engineering, incentives of $0.12 per kilowatt hour ("kWh")
for first year energy savings and $50 per kilowaff of average monthly demand savings, up to a
cap of 50 percent of the approved project cost. In addition to customer incentives, the program
provides design team honorariums (a finder fee for new construction projects) and design team
incentives for new construction projects exceeding International Energy Conservation Code
("IECC") 2009 energy code by at least 10 percent.
Projects completed by sector during 2013 are provided in Table 29.
Table29
Proiects Completed
I 2013 Total
M
FinAnswer Industrial I 16
Total Proiects Completed I 17
http://www.rockymountainpower.net/contenUdam/rocky_mountainjower/doclBusiness/Save_Energy_Money/Irrig
ation_Energy_Savers_Participating_Dealers.pdf
Page 36 of43
Rocky Mountain Power Idaho Report Commercial and Industrial Programs
Program savings by measure group is provided in Table 30.
Table 30
Program Measures (gross kWh/year at site)
Measure Groups 2013 Total
Additional Measures 236.902
Controls 362,311
HVAC 337.755
Irrisation 27.684
Lishtins 97.846
Motors 949_422
Refriseration 327.359
Program Totals 2.339.279
Program performance results for January 1,2013 - December 31,2013 are provided in Table 31.
Table 3l
Long-term Cost Effectiveness for Energy FinAnswer
Benefit/Cost
Ratio
Net
Benefits
Total Resource Cost Test olus l0 Dercent 1.91 $644.662
Total Resource Cost Test 1.74 $521.821
utilitv cost Test 3.74 $899.530
Particioant Cost Test 2.64 s 1.067.703
Rate Payer Impact 0.73 ($4s0.728)
Program Management
The program manager who is responsible for the Energt FinAnswer program in Idaho is also
responsible for the Energt FinAnswer program in California, Utah, Washington, and Wyoming;
the Self-Direction program in Utah and Wyoming; and the Commercial & Industrial Re-
Commissioning prigram in Utah. The Company employs five full-time project -unug"tt" in
support of the program manager.
The Energ,, FinAnswer program is administered by the Company. Consequently, the program
manager is responsible for the following:
Program cost effectiveness and performance
Ensuring the program is operated in compliance with commission tariffs and Company
guidelines including but not limited to qualification of customers
Customer communication and outreach
Monitoring code and standard changes
" Based on the volume of projects, temporary project managers and/or support staff are employed from time-to-time
Page37 of43
a
o
a
a
Rocky Mountain Power Idaho Report Commercial and Industrial Programs
o Qualification of materials and equipment
o Engineering analysis of customer opportunities
o Quality control and assurance
o Customer service, including the delivery of services and incentive
o Verification of installation and savings28
The program is marketed primarily via the Company's customer and community managers, trade
allies, Energy FinAnswer consultants and project staff. Other leads come via advertising in
business publications, company newsletters, word-of-mouth, past participants returning for
additionalprojects and a combination of other Company outreach efforts.
Infrastructure
Given the diversity of the commercial and industrial customers served by the Company, a pre-
approved, pre-contracted group of engineering firms are used to perform facility specific energy
efficiency analysis, quality assurance and verification. This being said, the individual projects are
directly managed by one of the Company's project managers. The project manager works
directly with the customer or through the appropriate community and customer account manager
located in ldaho. Table 32 lists the engineering firms currently under contract with the Company.
Table 32
Firms
Ensineering Firm Main OfIice Location
Abacus Resource Management Company Beaverton, OR
Brendle Group Fort Collins, CO
Cascade Enersy Engineering Cedar Hills, UT
Comoression Eneineerine CorD Salt Lake Citv, UT
Ecova Portland. OR
EMP2,Inc Richland. VA
Energy Resource Integration, LLC Sausalito, CA
Enersy and Resource Solutions North Andover, MA
EnerNOC Inc.Portland, OR
EnSave. Incorporated Richmond. VT
ETC Group. Incorporated Salt Lake Citv. UT
Everpreen Consulting Group Beaverton, OR
Fazio Ensineerins Weston. OR
kW Eneineering. Inc.Salt Lake Citv, UT
Lincus Incorporated Temoe. AZ
Nexant, Incomorated Salt Lake Citv, UT
OEI Enersv Manaqement. Inc.Beaverton. OR
RM Energy Consulting Pleasant Grove. UT
Rick Rumsev, LLC Ammon, ID
SBW Consultine. Inc.Bellevue, WA
Solarc Architecture & Engineering, Inc.Eusene. OR
Triole Point Enersv Portland. OR
" Summary of inspection process is in Appendix 7.
Page 38 of43
Rocky Mountain Power Idaho Report Commercial and Industrial Programs
Evaluation
In February 2013, a process and impact evaluation was completed by a third party evaluator for
program years 2011-2012. The impact evaluation provided data on the gross realized savings and
the NTG ratio. The process evaluation investigated participant satisfaction, implementation and
delivery processes, marketing methods and quality assurance. The Company's response to the
recommendations and web link to the evaluation report are included in Appendix 8.
Page 39 of43
Rocky Mountain Power Idaho Report Communication
CournnuxrcATloNs, OutnracH AND Eouc.q.ttox
The Company utilizes earned media, customer communications, paid media and program
specific media in an effort to communicate the value of energy efficiency, provide information
regarding low-cost, no-cost energy efficiency measures, and to educate customers on the
availability of technical assistance, services and incentives. The overall goal is to engage
customers in reducing their energy usage through behavioral changes as well as changes in
equipment, appliances and structures.
Idaho Earned Media
Earned media is managed by the Company's communications department in cooperation with the
company's customer and community managers in Idaho. The company identified one news story
in 2013 that mentioned its energy efliciency programs (there may be additional news stories not
posted online):
o lllSll3 - Idaho State Joumal: Rocky Mountain Power proposes credit for Idaho
customers early next year
http://www.idahostatejournal.com/news/local/rocky-mountain-power-proposes-credit-
for-idaho-customers-early-next/article_a2ce9262-48d5- l I e3-9b8c-00 I a4bcf887a.html
The company distributed three news releases to media in Idaho during 2013 that included
information about its energy efficiency programs:
o 9ll9/13 - See yaLater, Refrigeratort 2013 Refrigerator Roundup is underway
https ://www.rockymountainpower.net/about/nrlnr20 I 3/slrmr.html
ll/8/13 - Rocky Mountain Power proposes credit for Idaho customers early next year
https://www.rockymountainpower.net/about/nrlnr20l3lrockv_mountainJowerproposesc
reditforidahocustomersearlynextyear.html
l2l2/13 - Idaho communities shine during Rocky Mountain Power's Refrigerator
Roundup
https ://www.rockymountainpower.net/about/nrlnr20 I 3/icsdrmprr.html
C ustomer Communications
As part of the Company's regular communications to its customers, newsletters across all
customer classes promote energy efficiency initiatives and case studies on a regular basis. Inserts
and outer envelopes featuring energy efficiency messages and programs have also been used on a
consistent basis. ln2013, the Company also issued two newsletters focused entirely on seasonal
energy efficiency information targeted in the fall and spring.
The Company also utilizes social media, such as Twitter and Facebook to communicate and
engage customers on DSM offers and incentives.
Page 40 of43
Rocky Mountain Power ldaho Report Communication
Program Specijic
All energy efficiency program marketing and communications are under the wattsmart umbrella
to ensure a seamless transition from changing customer behavior to the actions they could take
by participating in specific programs. Separate marketing activities administered by and specific
to the programs ran in conjunction with the wattsmart campaign.
Home Energy Savings program
The Home Energt Savings program communicates to customers, retailers and trade allies
through a variety of channels. A new program brochure was developed, which highlights the
benefits of energy-efficient appliances and equipment and lists the incentives available in [daho.
In addition, a sales kit folder with marketing materials was used by program field staff as a
resource for retailer and trade ally engagement.
In the summer, program communications focused on cooling measures. The cooling campaign
included:o Point of purchase materialso Handout material for retailers and trade allies to use in their sales to customerso Web featureso Bill inserto Social media
A similar heating campaign was developed for the fall and winter, including:o Web featureso Sales handout and outreach to trade allieso Bill insert and incentive check inserto Emailo Social media
In November, program communications emphasized the deep discounts and incentives available
for the GE GeoSpring Hybrid Water Heater. This offer was communicated to Idaho customers
via newsletters, email, website and social media.
To make it easier for customers to submit and track online applications, program staff worked to
enhance the system to allow customers to upload electronic receipts and other documents. Other
improvements were also made to the online system for appliance and lighting applications.
Residential Refri gerator Recyclin g
The Company promotes its See ya later, refrigerator@
other customer communications. In April and May
impressions through digital display ads and paid search.
program through digital advertising and
2013, the program garnered 270,000
Page 4l of43
Rocky Mountain Power Idaho Report Communication
Inserts promoting the See ya later, refrigerator@ program went out in February, April and
September bills. In addition, a postcard was sent in February to customers who had recently
purchased a new refrigerator and received an incentive through the Home Energt Savings
program.
From August through October, the Company promoted the "refrigerator roundup" to Idaho
customers and reported the communities that recycled the most refrigerators and freezers during
this time through news releases, social media and on the website.
FinAnswer Express and Energy FinAnswer
During 2013 communications continued to emphasize the change in federal lighting standards
that took place July 14, 2012. This standard applies to manufacturers of general service
fluorescent lamps. Spring radio ads encouraged customers to retrofit their older linear fluorescent
lighting and tne Compariy added a video2e -and retained a page3o on the website dedicated to this
topic. The program's breakdown of impressions by media type is shown in Table 33.
Table 33
Impressions by Media Type
Communications Channel 2013
Radio 200,229
Print 135.897
Dieital 1.573
Asricultural Enersy Services
The Company promotesthe Agricultural Energt Services program at key events and reaches out
directly to participating customers and dealers when there are updates or changes to the program.
Communication activities during 2013 included:
o Letter with Irrigation Hotline brochure was mailed on March 21,2013, to Idaho irrigation
customers to inform them about upcoming changes to the Irrigation Load Control
program and introducing EnerNoc, our contractor overseeing the program.o Letter and frequently asked questions mailing on May 31, 2013, to Idaho irrigation
customers to inform them about requested changes to the Irrigation Energy Savers
program, effective August 15,2013. The changes affected incentives for nozzles, gaskets
and drains as well as pivot and linear system upgrades.
2e www.rockymountainpower.net/idsave
30 www.rockvmountainpower.net/li ghtinsstandards
Page 42 of 43
Rocky Mountain Power Idaho Report Evaluations
Ev^Lr,ultIoNs
Evaluations are performed by independent external evaluators to validate energy and demand
savings derived from the Company's energy efficiency programs. Industry best practices are
adopted by the Company with regards to principles of operation, methodologies, evaluation
methods, definitions of terms, and protocols including those outlined in the National Action Plan
for Energy Efficiency Program Impact Evaluation and the California Evaluation Framework
guides.
A component of the overall evaluation efforts is aimed at the reasonable verification of
installations of energy efficient measures and associated documentation through review of
documentation, surveys and/or ongoing onsite inspections.
Verification of the potential to achieve savings involves regular inspection and commissioning of
equipment. The Company engages in programmatic verification activities, including inspections,
quality assurance reviews, and tracking checks and balances as part of routine program
implementation and may rely upon these practices in the verification of installation information
for the purposes of savings verifications in advance of more formal impact evaluation results. A
summary of the inspection process is included in Appendix 7.
Evaluation, measurement and verification tasks are segregated within the Company's
organization to ensure they are performed and managed by personnel who have a neutral interest
in the benefits associated with anticipated savings.
Information on evaluation activities completed or in progress during 2013 is summarized in the
chart below. Summary of the recommendations are provided in Appendix 8. The evaluation
report is available at www.pacificorp.com/es/dsm/idaho.html
Program / Activities Years fvaluated Evaluator Progress Status
See ya later, refrigerator@ 2011-2012 The Cadmus Group Completed
FinAnswer Expess 2009-2011 Navigant Consulting, Inc.Completed
Irrigation Energy Savers 2009-2011 Navigant Consulting, Inc.Completed
Energy FinAnswer 2009-2011 Navigant Consulting, Inc.Completed
Home Energy Savings 20tt-2012 The Cadmus Group Ql of 2014
Low-Income 2010-2012 Smith & Lehmann In Progress
Page 43 of 43
ROCKY MOUNTAIN
POWER
A DtVtStoN 0F PACIFICof,P
Appendix I
Explanation of Cap acity Estimates
2013
Energv Efficiencv Programs
The MW reported savings of 3.44 (at generation) for energy efficiency programs during 2013
represents the summation of estimated MW values made available through the Company's
business and residential energy efficiency programs; calculations for the business and residential
programs differ.
The Company's business programs MW contributions are based on engineering estimates of
capacity values for installed measures; project unique factors are individually calculated for
custom projects while deemed factors are utilized for prescriptive measures. These calculations
are based on actual installed measures in the reported year. For 2013, it is calculated that 2.41
MW of capacity contribution were made available through business program energy efficiency
acquisitions. Specific hours during which business program measures contribute MW capacity
are dependent upon several factors including specific business operations and general economic
conditions.
For the residential programs, an energy to capacity factor is utilized to calculate the MW savings
made available through these programs. The energy to capacity factor utilized in the calculation
(2.46 MW in 2013 for each average MWh of energy efficiency acquired) is the same as the
average load profile factor of energy efficiency resources selected in the 2013 IRP, i.e. the
average peak contribution of the energy efficiency resource selections across all measures and
sectors. The utilization of this factor in the MW calculation assumes that the energy efficiency
resources acquired through the Company's residential programs have the same average load
profile as those energy efficiency resources selected in the 2013 IRP. Utilization of this factor in
determining the MW contribution of energy efficiency programs for 2013 is detailed in the table
below.
Line Description Value
I First year EE program savings acquired during 2013 3,686
2 Average MWh value (line I 18760 hours)0.42
J Peak MW contribution of 2012 EE acquisitions 1.04
As demonstrated, it is estimated that the residential energy efficiency program acquisitions in
2013 contributed 1.04 MW of capacity contribution. As with the business programs, when these
savings occur on an hourly basis is dependent upon several factors including energy usage
patterns of res idential customers.
Together, the 2.41 MW's estimated for the business programs and the 1.04 MW's estimated for
residential programs make up the 3.44 MW savings value of energy efficiency programs.
ROCKYMOUNTAIN
P(OWER
ADN'ISION OFillclHOOEP
Appendix 2
Idaho Cost Effectiveness
Table of Contents
Portfolio and Sector Level Cost Effectiveness.................. .................3
Program Level Cost Effectiveness.................. ...............6
Home Energy Savers Program...... .........5
Refrigerator Recycling (See ya later, refrigeratoro)........ ..............9
Low lncome Weatherization - Schedule 21 ........... ....................11
FinAnswer Express ..........13
Agricultural Energy Services (lrrigation Energy Savers) ..............15
Energy FinAnswer - Schedule 125.............. ............ 18
Page 2 ot L9
Portfolio and Sector Level Cost Effectiveness
The tables below present the cost-effectiveness analysis for the Idaho DSM Portfolio based on
Rocky Mountain Power's 2013 costs and savings estimates. Individual program cost-
effectiveness is provided in the following pages.
Table I lists the utility sector-level inputs. Table 2 lists the portfolio costs, Table 3 through Table
5 provide the cost-effectiveness results for:
Idaho 2013 Total DSM Portfolio, lncluding Non-Energy Benefits
Idaho 2013 C&l DSM Portfolio, Including C&l Evaluation Costs
Idaho 2013 Residential DSM Portfolio, Including Residential Evaluation Costs and Non-
Energy Benefits
The overall energy efficiency portfolio and component sectors were cost effective on a
PacifiCorp Total Resource Cost Test (PTRC), Total Resource Cost Test (TRC), Utility Cost Test
(UCT), and Participant Cost Test (PCT) basis.Table l. Portfolio Utility Inputs
a
a
O
Discount Rate
ResidentialLine Loss
Commercial Line Loss
Industrial Line Loss
Irrigation Line Loss
Residential Energy Rate ($/kWh) (base year 2013)
Commercial Energy Rate ($/kWh) (base year 2013)
Industrial Enerry Rate ($/kWh) (base year 2013)
Irrigation Energy Rate ($/kWh) (base year 2013)
Inflation Rater
t Future rates determined using a 1.9%o annual escalator.
6.88%
ll.47Yo
10.7s%
7.52%
11.45Yo
$0.r062
s0.088s
$0.0689
$0.0898
1.90%
Page 3 of 19
Table 2. Portfolio Costs 2013
Commercial & Industrial Evaluation
Costs $73,655
Residential Evaluation Costs $129,658
Technical Reference Library $23,705
DSM Central $13,566
Low lncome Weatherization Portfolio
Costs s25,000
Total $265,584
Table 3. Idaho 2013 Total DSM Portfolio Cost-Effectiveness Results
N Benefits
Total Resource Cost
Test (PTRC) +
Conservation Adder
$0.079 $6,690,405 $8,444,627 $1,754,222 1.26
Total Resource Cost
Test (TRC) No Adder $0.079 $6,690,40s $7,692,854 $1,002,449 l.l5
Utility Cost Test (UCT)$0.0s6 $4,794,08s 97,230,136 $2,436,051 1.51
Rate Impact Test (RIM)$12,639,711 $7,977,986 ($4,661,724)0.63
Participant Cost Test
(PCT)$6,476,925 $12,605,285 $6,128,360 1.95
Lifecycle Revenue
Impacts ($/kWtrl s0.000096705
Discounted Participant 2.96
Page 4 of 19
Table 4. Idaho 2013 C&I DSM Portfolio Cost-Effectiveness Results
Total Resource Cost
Test (PTRC) +
Conservation Adder
dins C&I Evaluation Costs
s5,096,620 $6,299,157$0.078 sI,201,537 I
I
1.24 i
i
Rate Impact Test (RIM) ;
Participant Cost Test i
'1 $9,269,473 i $6,473,448 i (52,796,025) t
l, $s,s+a,ln i,
tt s8,860,499
Residential Evaluation Costs and Non Benefits
$3,307,967 $1,504,538
i llrnrl, j s3,744,787 i $2,814,578 i
s0.00003741I
iTotalResourceCost I i i I iiTest(pTRC)+ i $0.078i $r,531,514 i $2,146,470 i $Ot+,lSS iin^--^-,^.:^-r,ss^- | i ! i I
i Tota Resource cost - , so.ort i s,,rrr,s,o i $r,967,256 | s435,742 \ r.z8;iTest(TRC)NoAdder I i r i : ii-IUtilityCostTest(UCT) I $0.063't 51,251,202 $1,504,538 | $253,336 I 1.20',
i Total Resource Cost Il:
Rate Impact Test (RIM)
Participant Cost Test
Lifecycle Revenue
($ru
Discounted Participant
back
I4.03 i
I
I
!
a
I
i_t
Table 5. Idaho 2013 Residential DSM Portfolio Cost-Effectiveness Results
($1,803,429)
Page 5 of 19
Program Level Cost Effectiveness
Home Energy Savers Program
The tables below present the cost-effectiveness results for the Idaho Home Energy Savers
program based on Rocky Mountain Power's 2013 costs and savings estimates. The utility
discount rate is from the 2013 PacifiCorp Integrated Resource Plan (IRP).
Cost-effectiveness was tested using the 2013 IRP east residential house 35%o load factor
decrement for all measure groups except for lighting, for which the 2013 IRP east residential
lighting 48Yo deuement was used. Table I lists the utility inputs. Table 2 lists the annual
program costs. Table 3 shows the annual energy savings and measure lives. Table 4 shows the
annual program non-energy benefits. Table 5 provides the cost-effectiveness results including
non-energy benefit. Table 6 provides the cost-effectiveness results excluding non-energy
benefits. The Home Energy Savings program was cost-effective from all perspectives except for
the rate impact test (RIM).
Table 4. Home Ene Annual
Appliances $13,541 $114,959 s274,233 $402,733
HVAC $3,116 i $26,455 $19,225 i $48,796
Lighting $2,196 $18,646 s82,862
$194,697
$930,209
Residential Energy Rate ($/kWh) (base year 2013) I $O.tOOZ
' Future rates determined using al.9Yo annual escalator.
Page 6 of 19
i HVAC i 86,827 | 100%o t 86,827 ; 860/o | 74,671 i 20 i,---
-+-
--i*"'- '*--*--*-1-- --*----f-i Lighting | 1,672,771 t l00o/o'. 1,672,771 ' 85o/o i, 1,421,855 ' 5 ,*----:--=-.---. ---j- | --._- -.-----.-,---+-- --i---.----: Weatherization ; 375,567 i IOO% i 375,567 i 87% i 326,7441 30
lrr_lt___ i :fJ2,467j :".2lr?,_t:!fl1 ___l_Jr:t:110*l_____j
Appliances
i Total Resource Cost ii Test ffRC) No Adder l
I Lifecycle Revenue i
t_t*p""t. Gtwt ) 1_ __$0.000026654 '
Table 5. Home Savi Annual
377,302 l00Yo i 377,302 | 860/o | 324,480 i tS :
Table 6. Home En Annual Non-En Benefits
I CFL General Purpose : $58,020 | PTRC,TRC, PCT I--l---L-----)
TotalResourceCost I j I i i :Test(prRC)+ : S0.0631 $1,105,762i St,ggt,gtzi $726,220i r.ooj
ConservationAdder i i i , i l
Table 7. Home Energy Savings
Cost-Effectiveness Results (Includine Non-Benelits
iili*t---*---_ -__f___* .--._
----riliiii rorar Kesource uo$ - , $0.06g i s1,105,762; $t,zoz,sot 1 $601,741 , t.5+ 'I Test (TRC) No Adder , *"'""" ! : r :----"--- -. --1i UtilitvCostrestruCT) ; $0.0s1 I $825.450 ', $1.24411_sS:__ _--$4Pfi:__ __*_J sl
-'..---:_-.,.-.-:_--:-.r...--._'-......}
I i#fir*tcostrest i $e30,20e i 53,044,22e:1. $2,114,020 , 3.27 ,
,=-L-----._* I -..-.-.- .
I Discounted Participant i , ,,Lr"ilsilcaD__::__, _ =_ t't' __:_ ,
Page 7 of 19
Table 8. Home Energy Savings
Total Resource Cost
I Test (PTRC) +
Conservation Adder
Cost-Effectiveness Results Non-
i
$1,369,264 |
$1,244,786
s7,244,786
$2,502,119 $1,571,91I
$1,105,762 i
$0.000026654
$139,023
s1,244,786 I ($1,284,893)
I (PCD :
Lifecycle Revenue i
Imnacts (S/kWh
DiscountedParticipant t
Page 8 of 19
Refrigerator Recycling (See ya later, refrigerator@)
The tables below present the cost-effectiveness results for the Idaho See Ya Later Refrigerator@
(SYLR) program based on Rocky Mountain Power's 2013 costs and savings estimates.
Cost-effectiveness was tested using the 2013 IRP east residential house 35o/o load factor
decrement for refrigerators and freezers and the 2013 IRP east residential lighting 48%o load
factor decrement for kits. Table I lists modeling inputs. Table 2 lists annual program costs. Table
3 provides the annual energy savings and measure lives. Table 4 shows the program cost-
effectiveness results. The program is cost-effective from all perspectives except for the RIM.
Discount Rate 6.880
r Residential Line Loss 11.47%
Residential Energy Rate ($/kWh) (base year 2013) $0.1062
Inflation Rater l.go%
' Future rates determined using a l.9Yo annual escalator.
Refrigerators
Freezers
Kits
Total
$7,230
$2,1 06
$292
$9,628
$39,543
$1 1,517
s 1,599
$52,659
86%
97%
47Yo
$7,566
s2,204
s306
$10,075
s13,1 10
$3,870
$3,01I
$19,991
$67,448
$ 19,697
s5,208
$92,353
Table 3. SYLR Annual Ene Savi
Refrigerators
Freezers
Kits
Total
520,030
134,289
38,480
692,799
447,226
130,260
18,086
595,572
s4%
48%
t00%
241,502
62,525
18,086
322,112
7
5
6
1. SYLR UtiI
Table 2. SYLR Annual
Page 9 of 19
Table 4. SYLR Cost-Effectiveness Resu lts
Total Resource Cost Test
(PTRC) * Conservation
Adder
$0.047 $92,353 s150,452 $58,099 1.63
Total Resource Cost Test
(TRC) No Adder $0.047 $92,353 $136,774 $44,421 1.48
Utility Cost Test (UCT)$0.047 $92,353 s136,774 $44,421 1.48
Rate Impact Test (RIM)$286,133 $136,774 ($149,359)0.48
Participant Cost Test
(PCr)$0 $377,135 $377,135 N/A
Lifecycle Revenue
Impacts (S/kWh)s0.000007506
Discounted Participant
Payback (years)N/A
Page 10 of 19
Low Income Weatherization - Schedule 21
The tables below present the cost-effectiveness results for the Idaho Low Income Weatherization
program based on Rocky Mountain Power's 2013 costs and savings estimates. The utility
discount rate is from the 2013 PacifiCorp Integrated Resource Plan (IRP).
Cost-effectiveness was tested using the 2013 IRP east residential house 35o/o load factor
decrement. Table I lists the utility inputs. Table 2 lists the annual program costs. Table 3
provides the annual energy savings and measure life. Table 4 shows the program's non-energy
benefits. Table 5 shows the program cost-effectiveness results. The program is cost-effective
only from the participant cost test (PCT) perspective.
Discount Rate
Residential Line Loss
Residential Energy Rate ($/kWh) (base year 2013)
lnflation Rater
' Future rates determined using a 1.9%o annual escalator.
6.88%
11.47%6
$0.1062
1.90%
Table 1. Low Income Weatherization Utili
Page 11 of 19
Table 2. Low Income Weatherization Annual ram Costs
I
$17,866 i S36l s164,667 i $203,741 1
- ---=-r-_-]
Table 4. Low Income Weatherization: Present Value of Non-Benefits
i Health, Safety and Repair
; Total Resource costTest , so.r+: 1 s203,74r t stzz,glg i ($g0,763) i o.oo
;l*Gscl No3*49gr* " _* ,___.. __ -_ , , I :
[1rui_cesi;"e{_*l--__!5Jil!*7ir_ll?ry7{_]te_rtgU_____q_._r_]
N/A i
--li I ifecycle Revenue Impacts i 90.000005332iQelD -i Discounted Participant N/AileDesE-r,vs{9 -
Table 3. Low Income Weatherization Annual E
Low lncome ;
I
Table 5. Low Income Weatherization Cost-Effectiveness Results
Total Resource Cost Test
Page 12 of 19
FinAnswer Express
The tables below present the cost-effectiveness results for the Idaho FinAnswer Express program
based on Rocky Mountain Power's 2013 costs and savings estimates. The utility discount rate is
from the 2013 PacifiCorp Integrated Resource Plan [RP).
Cost-effectiveness was tested using the 2013 IRP east system T}Yoload factor decrement. Table
I lists the utility inputs. Table 2 lists the annual program costs. Table 3 shows the annual energy
savings and measure lives. Table 4 provides the cost-effectiveness results. The program was
cost-effective from all perspectives except for the rate impact test (RIM).
Discount Rate
Commercial Line Loss
Industrial Line Loss
Commercial Enerry Rate ($/kWh) (base year 2013)
Industrial Energy Rate ($/kWh) (base year 2013)
Inflation Rate
' Future rates determined using a l.9Yo annual escalator.
Table 10. FinAnswer Exoress Annual P
6.88%
10.75%
7.52Yo
$0.088s
$0.0689
7 -90o/o
Commercial
Industrial
Total
$52,352 $23,288 $155,334
$12,914 S18,503 560,222
$65,266 $41,791 $215,556
$12,472 $353,933
$26,646 $261,855
$39,118 $615,788
s597,379 $1,043,566
$380,140 $608,131
$977,519 $1,651,697
Table 11. FinAnswer Express Annual En
Commercial
Industrial
Total
2,207,504
3,148,539
5,356,043
l0lo/o 2,229,579
ljlYo 3,180,024
5,409,603
67%
67%
1,493,919
2,130,676
3,624,434
t2
t2
Table 9. FinAnswer Ex
Page 13 of 19
Total Resource Cost Test
(PTRC) + Conservation
Adder
$0.045 | $1,468,368
$0.045 I S1,468,368Total Resource Cost Test
(TRC) No Adder
$1,129,944Utility Cost Test (UCT)$2,107,463
92,107,463 (s1,367,018)s3,474,481
Participant Cost Test (PCT)$1,651,697
Table 12. FinAnswer Cost-Effectiveness Resu lts
Page 14 of 19
Agricultural Energy Services (Irrigation Energy Savers)
The tables below present the cost-effectiveness results for the Idaho Agricultural Energy Savers
program based on Rocky Mountain Power's 2013 costs and savings estimates. The utility
discount rate is from the 2013 PacifiCorp Integrated Resource Plan (IRP).
Cost-effectiveness was tested using the 2013 IRP east commercial cooling 20Yo load factor
decrement. Table 1 lists the utility inputs. Table 2 lists the program costs. Table 3 shows the
annual energy savings. Table 4 lists program cost-effectiveness results. Table 5 lists the system
redesign cost-effectiveness results. The Agricultural Energy Savers program was cost-effective
only from the utility cost test perspective (UCT). The system redesign measure group is cost-
effective from all perspectives.
Discount Rate
Irrigation Line Loss
Irrigation Energy Rate (S/kWh) (base year
2013)
Inflation Ratel
' Future rates determined using a 1.9%o annual escalator
6.88%
11.45Yo
$0.0898
1.90%
Table 1. U Itural Ene
Page 15 of 19
Table 2.Savers Annual
$20,077 i $710,307 i $t,tgo,szsi $t,930,892$133,940 t, $22,602
Table 3.ricultural E Savers Annual E
Table 4.Savers Cost-Effectiveness Results
; Total Resource Cost
I Test (PTRC) +$0.20r
J
$2,628,705l.
!
($219,310) i 0.92
iConservationAdder I i I i'-- t '-
i Total Resource Cost : : i
i Test(TRC)NoAdder $0.201 : $2'848'015 $2'389,731 : ($458,284) i 0.84 j
F---:.
i utititycostTest(ucT) : s0.149 I $2,100,564 i $2,389,731 i s289,167 I t.t+ i
i Rate lmpact Test (RIM) ; ; s4,042,206, $3,137,582 i ($904,624) 0.78 I
---.---l
---- -.--i----------r-- f---- -*iIlrr
i Participant Cost Test | |
I (pCT) , ; $3,242,915, $Z,Zgg,Oq: i ($444,822), O.SO i
rlrtl; (r\, r,, I I--:_::_=-:-=_ _.i __ I
I LifecycleRwenue i S0.000045463 i
Illr.npactsl$r31y1) _ _ _ i_
i Discounted Participant i VA ::
Page 15 of 19
Cost-Effectiveness Results
Total Resource Cost
Test (PTRC) +
Conservation Adder
Total Resource Cost
Test (TRC) No Adder
Utility Cost Test (UCT)
Rate lmpact Test (RIM)
Participant Cost Test
(PCr)
Lifecycle Revenue
Impacts ($/kwh)
Discounted Participant
Payback (years)
s0.047 $ 1,083,740 s2,628,705
$2,389,731
s2,389,731
$2,389,731
$2,368,294
($0.00000032s)
2.12
$1,544,965
$ 1,305,992
$1,948,112
$6,471
$1,376,221
2.43
$0.047
s0.019
$ 1,083,740
s441,620
$2,383,261
$992,073
5.41
1.00
2.39
Page L7 of L9
Energy FinAnswer - Schedule 125
The tables below present the cost-effectiveness results for the ldaho Energy FinAnswer program
based on Rocky Mountain Power's 2013 costs and savings estimates. The utility discount rate is
from the 2013 PacifiCorp Integrated Resource Plan (IRP).
Cost-effectiveness was tested using the 2013 tRP east system TDYoload factor decrement. Table
I lists the utility inputs. Table 2 lists the annual program costs. Table 3 shows the annual energy
savings and measure lives. Table 4 provides the cost-effectiveness results. The program is cost-
effective from all perspectives except for the rate impact test (RIM).
Table 14. En FinAnswer Annual m Costs
Table 15.FinAnswer Annual
j Commercial ': 425,205 i 83% 352,920 \ 89% i 314,099 i 15 ii-- .-.. -. : -.: -'- --... ---------*-----'1
, lndustrial 1 l,gl4,O74 i 83%o ; 1,588,681 1, 89% | 1,413,926 i tS Ii !y1,,q02 i_-__ _- . j_*1{19{2s)____j
Table 13. E FinAnswer Utility I
Page 18 of 19
Total Resource Cost
Test (PTRC) +
Conservation Adder
s706,592 ! S1,351,243
Total Resource Cost
Test (TRC) No Adder
$899,530 I 3.74Utility Cost Test (UCT) i $0.018
$1,679,131 t $1,228,403
$652,105 i $l,7tg,g0g
Rate Impact Test (RIM)
$1,067,703
FinAnswer Cost-Effectiveness Results
Participant Cost Test
Lifecycle Revenue $0.000013118lmpacts (S/kWh
Discounted Participant 3.43 Ik
Page 19 of 19
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.90L:
ROCKY MOUNTAIN
POWER
A DMSION OF PASRCORP
Appendix 5
ENERNOC Irrigation Load Control Report
OTNERNoc ROCKY MOUNTAIN
POYI'ER
OENERNoc
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
201 3 PacifiCorp lrrigation Load
Control Program Report
EnerNOC,lnc
One Marina Park Dr, Ste 400
Boston, MA 02110
www.enernoc.com
Rocky Mountain Power
825 NE Multnomah St, Ste 550
Portland, OR97232
www.pacificorp.com
Date:
March 3,2014
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Contents
Overview of the 2013 lrrigation Load Control Program .........................3
Review of 2013 enrollment and enablement.............. ...........................4
Customer outreach ...........4
Provider payment structure..... .............4
Enrolled customers ...........5
EnerNOC site servers ........5
Legacy devices,....... ...........6
Technical challenges .........6
Data quality challenges .........................7
Review of 2013 program performance ...........8
lmpacts of pay-for-performance model ...................8
lmpact of crop type............. ................10
lmpact of irrigation technology and water availability.. .............11
Geographic segmentation.................. .....................11
Weekly available load reduction.................. ...........L2
Load control events......... ....................13
Customer satisfaction and issues... ........................,L7
Key lessons learned from 2013... ..................18
Enrollment and retention ................. ......................18
Enablement .....................19
Dispatch mana9ement.................. ......20
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Overview of the 2013Irrigation Load Control Program
This report provides an overview of PacifiCorp's lrrigation Load Control Program in the Rocky Mountain
Power (RMP) seruice territory, as implemented and administered by EnerNOC. EnerNOC and RMP are
pleased with all that the program accomplished in 2013, including a large-scale transition to a new
business model and technology platform over a compressed timeframe. This report is intended to
document program results, accomplishments, and challenges, including lessons learned and, where
applicable, plans for 2014.
PacifiCorp selected EnerNOC to manage the irrigation load control (lLC) program beginning in 2013 and
through 2022. EnerNOC's responsibilities include enrollment, equipment installation, dispatch
management, performance calculations, and customer service. Along with program management
changes, the performance measurement and incentive structure changed substantially from previous
years. A new pay-for-performance structure rewards irrigators for the value they provide during
program hours, versus peak monthly capacity. lmportantly, under this construct PacifiCorp only pays for
capacity available during program hours, as measured by EnerNOC's energy monitoring technology and
adjusted through a performance factor to account for those sites which opt not to participate during
specific dispatch events. ln order to achieve this incentive structure, interval metering was necessary.
EnerNOC's equipment solution provides 5-minute interval energy monitoring as well as remote
irrigation equipment control. EnerNOC's web-based portal now provides irrigators and PacifiCorp with
near real-time energy usage data.
The motivation for these program changes was to develop a sustainable program that meets the needs
of irrigators, the utility and ratepayers over the long-term. ln January and February 2013, RMP and
EnerNOC met and collaborated with various stakeholders to explain the program changes and refine the
program offering to better meet all parties' needs. The ldaho lrrigation Pumpers Association (llPA) and
Utah Farmers Bureau provided valuable feedback about program incentives and rules. Regulatory
approvalwas achieved in ldaho and Utah in mid-March 2013.
The ILC program is currently available to Tariff Schedule 10 customer sites in the Rocky Mountain Power
(RMP) ldaho and Utah service territories. ln future years, participation may expand to customers in
Oregon, California and Washington. Participating sites are compensated for shutting off irrigation load
for specific time periods determined by RMP, and are provided day-ahead notice of dispatch events.
Customers always have the opportunity to opt out of (i.e., choose not to reduce load) for dispatch
events as necessary for their operations. Customer incentives are based on a site's average available
load during load control program hours adjusted for the number of opt outs or non-participation. The
program hours are 12 to 8pm Mountain Time (MT), Monday through Friday, and do not include
holidays.
The 2013 program season ran from Monday, June 10 through Friday, August 15. Average weekly
available load reduction was 120.9 MW. RMP utilized forty of the fifty-two possible program event
hours. There were ten load control events, each four hours in length, which will be described in more
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detail below. On average the program delivered 115.6 MW of actual load reduction compared to
baseline load (determined as usage on the day prior to the dispatch) of 137.0 MW. This actual load
reduction is calculated according to 5-minute interval data from EnerNOC's energy monitoring
equipment. As a result load not monitored is not included in EnerNOC's reported performance, and
therefore EnerNOC's load reductions may differ from those RMP reports, ln 2013, the average
performance factor was 84%, which indicates the percentage of customer load opting out of events.
EnerNOC's implementation of this ILC program was consistent with its approved agreement with RMP.
Review of 2Ol3 enrollment and enablement
Customer outreach
After regulatory approvalwas obtained, EnerNOC initiated outreach to eligible irrigators. EnerNOC
worked with RMP to introduce the program changes and rules via marketing collateral, including RMP's
website, an FAQ, and postcard mailings. EnerNOC led "town hall style meetings" in ldaho Falls, Preston
and Rexburg, ldaho. A dedicated team at EnerNOC called and met with potential participants. EnerNOC
also formed a channel partnership with Spartan Energy Control Systems, who knows irrigators through
normal course of business and from installing equipment during previous load control program years.
EnerNOC's 2013 enrollment efforts focused on transitioning participants from prior years, especially
given the short time between regulatory approval and the program season. EnerNOC aimed to identify
load that was best fit for the new program structure and would provide the greatest financial incentive
to the participant. Pumps with load during program hours and weeks, as well as larger pumps, were
targeted in conversations.
New participants and pumps of all sizes were eligible and welcome to participate. However, smaller
pumps and pivots do not typically use enough electricity during peak periods to cover the costs of
participation in the program, and thus were not prioritized for enrollment.
Provider payment stmcture
EnerNOC and Rocky Mountain Power established three tiers for payments in order to provide fair and
consistent treatment for sites of similar size and operation. The tiers rewarded customers who made
larger contributions to the program. A customer's entire portfolio of eligible sites was evaluated in
aggregate to determine the average expected kW per pump and subsequent payment tier as described
in Figure 1.
Over lfl!kW 23 2s N/A
50-100 kw 19 2t A
Under 50 kW 19 2t 1500
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The bonus incentive rate was designed to encourage customer sign-up by rewarding all participants if
the entire enrolled portfolio size was greater than 125MW. The 2013 enrolled portfolio achieved this
goal, so all participants received the bonus rate.
ln order to cover the costs of participation in the program, an enablement fee was necessary when the
average expected load per pump was less than 50 kW. Most customers with primari[ small pumps
chose not to enroll in the program in 2013 due to the enablement fee. Customers with a variety of
pumps most often chose to enroll only their larger pumps to take advantage of the higher base incentive
rates and to avoid the enablement fee. No customers chose to pay the enablement fee in 2013.
Enrolled customers
Between March L5,2Ot3 and July L0,20L3, EnerNOC enrolled 320 RMP accounts at 1,354 sites. Figure
2 shows the split of enrolled accounts and sites across the two regions. Billing kW is the 2013 RMP peak
demand.
Figure 2 is a snapshot in time as of July, !0,20t3. Not all customers were able to be enrolled or enabled
prior to the end of the 2013 ILC season due to timing considerations or technical challenges. Customers
who enrolled prior to the end of the season but did not have the opportunity to fully participate in the
program received transition year payments from RMP and EnerNOC.
Figure 2: Enrolled and participating RMP accounts and sites compared to Schedule 10 Customers, as of
10,2013
Count of Billing
Account/ kW
Site
Count of
Account/
Site
Billing
kw
Count of Billing
Account/ kW
Site
Schedule 10
Customers
L,7561 458,258
4,863
t,6921 136,073
2,743
t,4/]81 594,331
7,@6
Enrolled 2581 220,793
L,lL4
26,67962/
240
tzol 247,472
L,154
Participating L96,9462321
971
s4/
207
24,LL8 2861 22t,Oil
L,L78
EnerNOC site servers
By July tO,2OL3,286 RMP accounts and 1,178 RMP sites were participating in the ILC program. The
majority of these sites participated using an EnerNOC site server (ESS). The ESS solution includes
hardware/software for remote load control and energy monitoring at the pump panel. EnerNOC Field
Operations deployed 1,323 ESS devices across 1,075 sites by mid-July. This represented the bulk of
installation activity for 2013.
Due to volume of work orders and timing of enrollment, some sites were not able to be installed with an
ESS prior to the program start. lnstallation efforts were also delayed by the following factors:
o Winter and spring weather impacted access to certain geographic regions.
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o Customer availability limited access of electrical subcontractors to sites.
o Needed irrigation system repairs postponed installation.
o Pumps and irrigation systems needed to be operating under load in order to confirm the
functionality of the devices. Delayed start-ups delayed the ability to verify functionality.
Legacy devices
A sub-set of participating sites in 2013 used data from legacy irrigation load control devices already in
the field from previous years. These legacy devices report changes in pumps' onloff status rather than
reporting the energy usage. The allowance of these devices was critical in enabling customers to
participate in the 2013 program despite the aggressive program launch schedule. Moving forward in
2014, EnerNOC has been installing ESS devices at these sites so that their curtailment can be more
accurately monitored. No legacy devices will be involved in a customer's participation in 2014.
Technical challenges
Some customer sites were not able to be installed in 2013 due to technical challenges as described
below.
1. Sites with 2300V services were not able to participate in the 2013 season.
/ssue
o These sites primarily use old submersible pumps, which are often large horsepower (on the
order of 800hp) and are costly to replace. Customers expect to replace these pumps over time,
only as necessary.
o Safety concerns prevented the installation of current transformers at sites with 2300V service.
Solution
o To enable this load for ILC participation in2OL4 (before the customers have replaced these
pumps), EnerNOC has requested the installation of utility KYZ pulses as an alternative energy
data source.
o Rockv Mountain Power agreed to replace existing meters with those compatible with KYZ pulse
outputs.
o EnerNOC will install an ESS system at these sites utilizing the KYZ pulse meters. Customers will
participate manually, but all load will be monitored to verify performance.
2. Sites without cellular reception could not participate in 2013.
lssue
o Data communication is necessary for EnerNOC devices to enable control of pumps for event
participation and to report energy usage for payment calculations per program rules.
Solution
o EnerNOC continues to explore alternative solutions for future participation; however there is no
solution lor 20L4.
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Data quality challenges
EnerNOCs device solution for ILC includes use of current transformers (CIs) to monitor the pump's
curtailable load in 5-minute intervals. The specific configuration of installations was virtually identical
across all sites and was designed for minimum points of error. ESS monitoring was at the pump panel
level, so demand data did not necessarily correspond one-to-one with utility meter load. This added a
layer of complexity to data quality verifications.
During the course of verification, EnerNOC identified several data quality issues and worked with RMP to
determine the appropriate resolution and payment method for customers as needed. The key technical
issues identified were as follows:
1. Sixty-one sites were identified as having a magnitude offset in the S-minute interval data.
Root Cause
o Errors in the CT phasing or system programming caused the offset.
Solution
o These issues have been fixed through the course of on-site maintenance visits.
o EnerNOC expects to be able to accurately reprocess readings in2OL4 once irrigation load
resumes.
o To calculate 2013 performance, EnerNOC and RMP agreed to adjust actual electric demand.
2. Twenty-six sites had a persistent data quality issue during program hours and demonstrable
participation in ILC events.
Root couse
o lncorrectly installed CTs on variable frequency drive irrigation systems resulted in erroneous
readings when the pump was not running at either peak usage or not running at all.
Solution
o These installation issues have either been fixed on-site or work orders have been created for
the spring of 2OL4.
o To calculate 2013 performance, EnerNOC and RMP agreed to adjust actual electric demand.
3. Sixty-seven sites reported no data during events, but the customers confirmed participation.
Root Couse
o Loss of power to EnerNOC's device on-site results in no data reported for those intervals.
o During events, lack of data is treated as zero load reduction; yet in these instances power
was cut to EnerNOC's device and a participating pump.
Solution
EnerNOC and RMP agreed to adjust actualelectric demand to zero kW for intervals during
the appropriate events upon verbal confirmation from the customer.
For 2OL4 performance calculations, EnerNOC is exploring the possibility of implementing a
remote "power off" signal to report when power is cut to the ESS.
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Review of 2OL3 program performance
Impacts of pay-for-performance model
Due to the pay-for-performance program model, customers' success in and satisfaction with the ILC
program for 20L3 varied according to pump run-time during program hours and participation across the
ten load control events called by RMP. The following four examples illustrate varying levels of availability
and participation at individual irrigation pumps in 2013. Screenshots are from EnerNOC's web-based
DemandSMART platform, where participants can view near real-time energy usage data. ln each figure
the x-axis shows time and the y-axis is actual electric demand kW, as measured by EnerNOC's devices.
The shaded regions indicate weekends, which are outside of program hours. EnerNOC's equipment
solution provides 5-minute interval energy monitoring, in addition to remote irrigation equipment
control.
Figure 3: High availability and high participation
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T 6
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Figure 3: High availability and high participation shows electric demand (kW) for a single pump across
the entire program season from June 10 through August 15. This pump participated in all events and
had high availability due to potato crops. This pump ran consistently for the entire ten weeks of the
program season and shut down (only) during load control events. For example on July 26, there was an
ILC event from 3 to 7pm Mountain Time, and load at this site dropped to 0kW. This pump had almost
100% availability and a LOO% participation factor for shutting the pump off during all ten load control
events. As a result, the customer received the maximum expected compensation for this pump.
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Figure 4: Average availability and high participation
Drt lrtarval lrhr
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Figure 5: tow availability during program hours focuses on a two-week period during the program
season in order to illustrate this pump's time of use. Note on July 2nd, the pump cycled usage regularly
but was watering most often during early morning hours (e.g. 3 am), which are not covered by the
program hours (12 to 8 pm), The pump ran most consistently on weekends (note the light blue
columns), which are not included in program hours. As a result of alfalfa crops and running at night and
on weekends, this pump had low availability during the program hours. This site participated in all
events; however low availability resulted in a much lower overall payment.
fingc
la rd lb lh h YID It
- Rilq.
ocrronors - - odtclrorr ld d 'lh 3h 6h YtD 'lt
Figure 4: Average availability and high participation shows electric demand (kW) across the entire
program season for a pump, which shut off for over three full weeks at the end of the program season.
As a result of this wheat harvest, the site's availability was about 65%. The pump did shut off during all
ten load control events, so the participation factor was 100%. The combination of high participation but
average availability resulted in the customer receiving average compensation for this pump. Payment
could have been higher with longer run-time.
Figure 5: Low availability during program hours
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o
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60
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0
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Figure 5: Low participation during events
filg.
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ROCKY MOUNTAIN
POWER
mhttrdVlr
lttlu v I
ol2llb1, - omtbl,
Figure 6: Low participation during events shows a single week of the program season in order to
demonstrate pump run-time during a week with multiple load control events (week of June 22to271.
This site has high availability but fell behind on watering and needed to opt out of the events on July 25
and 26. Lack of participation is apparent because the pump ran without shut-off from Monday, June 22
until the following weekend. As a result, the participation factor for this pump was lowered by 20% (two
events out of ten total events in 2013) across the entire program season. Payment for this pump was
lower due to the opt-outs during events, and could be raised with higher participation during events.
Impact of crop type
Crop type typically correlates with availability and can be a predictor of customer success in the ILC
program. lrrigators in ldaho and Utah most commonly grow alfalfa, wheat, barley, potatoes, corn, or
some combination thereof over the course of a multi-year planting schedule.
Alfalfa is typically grown on a five to seven year planting cycle and is watered consistently across
the season. Alfalfa can be grown across the ldaho and Utah territory. Prices are particularly high
right now; so many irrigators are choosing to plant this crop. Typically alfalfa crops have the
flexibility to participate in events due to a tolerance for shifts in watering schedules. However,
the load profile of alfalfa is intermittent. Pumps watering alfalfa are shut off for two periods
each summer for harvest. These harvest periods can last a week or more, resulting in
significantly reduced availability.
Wheat and barley will typically require large amounts of water early in the program season, and
then pumps will be shut off once for several weeks to allow the crop to dry out for harvesting.
These are tolerant crops that can withstand a couple off-schedule days to participate in load
control events. However payments will be affected by availability.
Potatoes are a water-intensive crop that is often rotated with wheat after a few years of
harvest. Potatoes are significantly more sensitive to irrigation schedule interruptions than wheat
or alfalfa. ILC participants with potato crops will have high availability but likely a reduced
flexibility to participate in load control events. Potatoes will also be particularly sensitive in
drought years, further impacting event participation.
Corn and fields watered for livestock pasture have less consistent or predictable irrigation
schedules, and are mostly found in Utah or on dairy farms.
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Crop rotations further impact pump availability year-over-year. Over the course of the ten-year program
period, most irrigators fall into one of the following four crop schedules:
o LOO% alfalfa;
c 50%wheatl5O%potatoes;r free rotation between alfalfa, wheat, and potatoes; or
o LOOo/o corn or pasture field irrigation.
A pump that waters wheat in year one with high event participation and 50% availability due to
harvesting downtimes may water potatoes in year two. This crop shift would likely result in a shift to
lower participation but95% availability, making it difficult to use single year performance as a predictor
for program fit across the ten-year period.
Impact of irrigation technology and water availability
While pump size is a clear determinant of total availability in the ILC program, irrigation technology and
water availability also impact irrigation pump run-time and thus can affect customer success in the ILC
program. Pivot irrigation systems are operationally easier to manage for load control events than a
wheel line or hand line irrigation system, and thus are favored for participation in the program. lt is
important to note that a potential customer will never be disqualified solely based on crop type or
irrigation technology. Enrollment will be judged based on custome/s willingness to participate.
The majority of large - several hundred horsepower in size - irrigation pumps enrolled in the program
are attached to a deep welland found in regions with low surface water availability. Growers with deep
well pumps have a high level of control over their irrigation schedules and may have greater flexibility to
participate in load control events, but may be more constrained by water resources.
Surface water pumps are generally found in areas with reliable water availability: ldaho Falls, south
ldaho and select areas of Utah. These pumps are generally up to 100 horsepower in size and are used to
move water laterally on demand from canals. Surface water pumps generally operate on a schedule
arranged in advance with the canal company, which can lessen schedule flexibility to participate in load
control events. Lack of coordination can result in flooding. Those growers using surface water pumps
who participate in ILC often have large operations with many pumps that can manage the operational
risk of a load control event.
Geographic segmentation
Based on conversations with irrigators in 2013, EnerNOC's marketing and sales team has characterized
the ldaho and Utah customer territory into regions based on geography and observations of crop type
and operational patterns.
ln ldaho, participation, as measured by load contribution, was predominantly in four regions in 2013:
Mud Lake (Hamer, Mud Lake, Terreton, Monteview, and Dubois), ldaho Falls (ldaho Falls, Firth, and
Shelley), South Fork Snake River (Roberts, Rigby, Menan, Ririe) and Rexburg (Teton, Sugar City,
Clementsville, Rexburg, Newdale). These areas generally have larger, deeper well pumps that are natural
fits for the ILC program. Penetration, as compared to an estimate of the existing non-enrolled potential
load in the region, was also high in these four regions, particularly in South Fork Snake River.
Participation, as measured by load contribution, was highest in three regions in the Utah service
territory: Cedar City Parowan, Paragonah, and Cedar City), South Utah (Enterprise and Beryl Junction),
and Delta (Leamington, Delta, Holden, Lynndyl, and Mccornick). ln general Utah load is made up of
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smaller horsepower pumps than in ldaho and systems are older, making the mechanics of ILC
participation more difficu lt.
Weekly available load reduction
The RMP ILC program is evaluated based upon average available load reduction (kW) during program
hours from 12 to 8pm MT, non-holidays. ln 2013, the portfolio average available load reduction was
120.85 MW with a contribution of 107.1 MW in ldaho and 13.75 MW in Utah.
Available load reduction for the total portfolio varies week over week due to irrigation use as displayed
in Figure 7 below. Enrollment and registration of sites contributed to some of the ramp observed in the
first three weeks of the program period. The other contributing factor was ramp in operation of
irrigation systems for watering. The drastic reduction in available capacity from July 22 through August 4
was driven by the shut-off of pumps for harvest of crops, including grain and alfalfa.
Figure 7: Weekly average available load reduction
<- Total Portfolio <-ldaho .{'-Utah
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180
160
L40
L20
100
80
60
40
20
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Program Week, beginning
lrrigation patterns in ldaho drove total portfolio availability due to the disproportionate amount of
eligibfe and participating load in ldaho. During the week of July 29, ldaho available load dropped to 52o/o
of the 145.39 MW peak available load during the week of July 8. Pumping in ldaho resumed for the last
two weeks of the program season (August 5 through August 15)but did not return to peak levels.
Available load in Utah also varied week over week but was slightly more consistent than in ldaho.
DuringtheweekofJuly22,availableloaddroppedto620/ooftheprogrampeakinUtah. lncontrastto
ldaho, the last program week had the highest available load over the summer in Utah - 18.57 MW.
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The concept of availability and pay-for-performance is new to customers participating in lLC. EnerNOC is
taking the opportunity during discussions about payments, the enrollment process, and periodic check-
ins with customers to explain and answer questions about this concept. Some customers ran entirely off
peak, especially those on Utah's time of use rate, which resulted in significant differences between prior
years' ILC incentives and expectations set during the 2013 enrollment process.
Load control events
ln 2013, there were ten mandatory program events across ldaho and Utah. Actual load reduction was
measured as the difference between actual demand during the event and baseline demand. Baseline
demand was the average demand during program hours (12 to 8pm MT) on the most recent non-event,
program day. Actual Load Reduction (kW), Baseline Demand (kW)and Load Reduction Performance
Factor as reported here correspond to 5-minute interval energy usage measurements from EnerNOC's
equipment at customers'sites. These measurements may not correspond to realized load reduction on
RMP's system. Load reduced but not yet monitored is not included in EnerNOC's reported performance.
This includes sites that were enrolled but not enabled with a monitoring solution, for which RMP
provided a transition year payment.
The 2013 portfolio delivered 115.5 MW on average. Performance factor, the measure of actual load
reduction compared to baseline demand, was 84o/o on average for the portfolio. Performance factor is
designed to measure customers' choices to opt out, or to not participate in events, and is used to adjust
availability payments because of the pay-for-performance nature of the program. Performance factor
should not be confused with any notion of performance against a capacity nomination. Peak delivery of
135 MW occurred during the July 10 event. The portfolio also had maximum potential for curtailment on
July 10 with a baseline demand of 156.5 MW.
Figure 8 summarizes portfolio load reduction compared to baseline. Figure 9 details the actual load
reduction, baseline demand, and performance factor for each state and event. Maximum event
participation was achieved during the first dispatch on Junely 18 with a performance factor of 93o/o.
While Utah load only contributed to about LLoA of average baseline load, Utah participants performed at
87% on average, compared to 84o/o in ldaho.
Figure 10 below provides a detailed list of the ten mandatory events, as well as one program test event
and five canceled events. Several unexpected scenarios occurred during the 2013 event season:
o Canceled dispatches on the day-of (after day-ahead notification to EnerNOC and participants)
were not expected. EnerNOC was able to notify customers of cancelation; however these
instances caused confusion and complaints. EnerNOC and RMP are working to limit future
cancelations to emergency scenarios only.
. Utility power outage outside of events and/or program hours affected custome/s ability to
participate. RMP agreed to compensate irrigators for participation in these instances as a show
of good faith. EnerNOC incorporated this scenario into opt out processes in order to properly
track these instances.
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A utility power outage during an event caused data gaps on EnerNOC's load control devices, and
some pumps resumed normal operations during the event when power was restored. This
resulted in a load increase across the portfolio during the last hour of the event on June 28.
EnerNOC is working to identify a better solution to track this type of exception in the future;
however all systems functioned as designed and expected.
PacifiCorp reguested to exclude a sub-set of customers from already dispatched events due to
changes in system needs or vulnerabilities. EnerNOC was able to respond to such a request on
July 1 by restructuring records and notifying customers. EnerNOC and RMP are working on zonal
dispatch in order to better accommodate such needs in the future.
PacifiCorp requested staggered dispatches after the July 10 event in order to minimize voltage
spikes on RMP's system, EnerNOC implemented staggered dispatches by randomly grouping
participating sites into ten groups with delays of one minute between remote curtailment of
each group. This lead to a slower reduction in load over the course of ten to fifteen minutes
(due to naturalsystem delays).
Figure 8: Load reduction for total portfolio across ldaho and Utah, by event
I Load Reduction (MW) f.!Baseline Demand (MW)
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Figure 9: List of actual Ioad reduction, baseline demand and performance factor, by event and region
*Actual Load Reduction (kW), Baseline Demand (kW) and Load Reduction Performance Factor as reported here
correspond to S-minute interval energy usage measurements from EnerNOC's equipment at customers' sites.
These measurements may not correspond to realized load reduction on RMP's system.
ldaho
Utah
107,42t
7,L35
9304
9Oo/o
ldaho
Utah
L29,758
7t6,987
72,77L
147,734
L32,280
15,455
88%
88%
83%
ldaho
l.Jt..h
Ll,-,L28
97,850
L3,277
129,606
113,845
L5,767
86%
86%
84%
L22,9O3
109,395
13,509
t5L,2U
L34,864
15380
8t%
8L%
82%
ldaho
t trh
110,009
15,151
152,853
135,109
82%
Sto6
go%
ldaho
W.h
115,104
LOz,483
L2,622
156,498
L41-,293
74%
730/,
8g%
ldaho
Utah
135,328
120,806
L4,522
L57,460
142,LsL
15,309
86%
85o/o
gs%
ldaho
l.Jt.h
L16,790
106,339
10,451
134,505
L22,83t
L1"6?4
87ori
87o/o
go%
ldaho
Utah
95,631
85,644
70,987
1L2,630
100,949
11^681
86%
85%
g4,%
ldaho
Utah
96,667
86,765
9,902
tL2,630
100,949
11^581
86%
86%
8s%
ldaho
Utth
tLs,62L
103,661
11,960
L36,972
t23,269
L3,703
84%
84o/o
8r%
Co nfid e ntio I o nd P ro prieto ry Poge 15
e rNERNoc ROCKY MOUNTAIN#s.*
Program
Test
- Pre-season porffolio test to verify EnerNOC
hardware/software and customer notifications.
Mandatory 6lLgl20L3
3:00pm
- EnerNOC system issue prevented "5 MW of load on -40
devices from receiving the curtailment signal. EnerNOC
curtailed these pumps over the first hour of the event.
6127120L3
3:00pm
6/27120L3 - RMP canceled the event due to transmission returning1:50pm to service and wind/other generation levels different than
Mandatory 6128120L3
3:00pm
6128/20t3
7:00pm
- RMP power outage at -5:45pm. Some sites' power
restored prior to event end time and pumps with auto-
Mandatory 7l1-l20tg 7lLl20L3 RMP requested removal of participants on temporary3:00pm 7:00pm transformer from event.
- EnerNOC and RMP worked with participants affected by
r outage on 6128 to compensate appropriately.
Mandatory 7l2l2tt3 7/2/2OL3 Participants cited high temperatures and third
3:00pm 7:00pm consecutive program day of dispatches as primary opt out
reasons.
- EnerNOC and RMP worked with participants affected by
Mandatory 71312013 7/3/2OL3 Participants cited high temperatures and fourth3:00pm 7:00pm consecutive program day of dispatches as primary opt out
reasons.
- EnerNOC and RMP worked with participants affected by
Mandatory 7l9l2or3 719/20L3 - Localized power outage observed prior to event.
of opt outs for ootato
Mandatory 7lt0l20l3 7/L0/20L3 Localized power outage observed prior to event.
Canceled 7llU20t3 - 7lLLl20L3 - RMP canceled due to change in system needs.
Canceled 7ll6l20t3 7ll6l2ot3 - RMP canceled due to change in system needs.
Canceled 7i17l20l3 7lL7l2lt3 - RMP canceled due to change in system needs.
Mandatory 7l1.8l20t3
3:00Pm
7lt8l20L3
7:00pm
- lmplemented staggered curtailment. lt took 15 minutes
into the event window (3:15 pm) for all devices to receive
Canceled 7l22l20t3 - 7122/2Ot3 - RMP canceled event due to major load tap changer
3:00pm 11:00am malfunction. Dispatch could have caused serious voltage
issues for customers.
Mandatory 712512013 7/18/20L3 Potato crops continue to opt out with high frequency.
- Almost 35% of oortfolio load is down for harvest.
Mandatory 712612013 7lL8l20L3 Potato crops continue to opt out with high frequency.
- Almost 35% of portfolio load is down for harvest.
10: List of 2013 event
Co nfide ntio I o nd P ro prieto ry Page 16
OTNERNoc ROCKY MOUNTAIN
PO,VER
Customer satisfaction and issues
EnerNOC sent an end-of-season survey to gauge customer satisfaction via email on October L6,2OL3.
The survey consisted of fifteen questions and comment fields. A small sub-set of customers responded:
twenty-two in ldaho and six in Utah. Eight quantitative questions were asked:
o Overall satisfaction with EnerNOC
o Likely to recommend EnerNOC
o Enrollment and contracting process
o lnstallation process of EnerNOC equipment
o Maintenance of EnerNOC equipment
r Ability to play your irrigation schedule and participate in ILC dispatches
r EnerNOC customer service
o Opt out process
Across these quantitative questions, average customer response was a 7 on a scale of 1-10 where 1
means "very dissatisfied" and 10 means "very satisfied". Responses and comments indicated the
following areas of customer concern:
o Loss of value compared to previous program rules, functionality and/or compensation.
o Delayed device enablement and/or rushed program start.o Ongoing hardware issues with EnerNOC devices.
o Event cancellations were challenging for customers due to needs to plan irrigation schedule.o EnerNOC's call center needs to improve awareness about irrigation and agriculture.
EnerNOC is using customer feedback regarding the enrollment and enablement processes and event
experience from 2013 to set expectations and shape improvements for future program years.
Co nfi de ntio I o nd P ro prieto ry Poge 17
e rNERNoc ROCKY MOUNTAIN
POYIIER
Key lessons learned from 2Ol3
EnerNOC and Rocky Mountain Power identified the following lesson learned for 2013 to apply to 2014
and future years.
Enrollment and retention1. Enrollment Timing
Summory
o Despite EnerNOC's concerted efforts to quickly finalize as many customer contracts and
installations in the short time period between regulatory approval and the program season, it
was not possible to enroll and enable all participating sites in time for the 2013 season.
Customer Feedbock
r Customers generally assumed that if installation had not yet been fully completed at their sites,
they could participate in the program manually without monitoring or remote control.o ln order to address those customers that were enrolled but not enabled with a monitoring
solution, RMP decided to provide a transition year payment.
Approach for 2074
o EnerNOC will continue to enroll customers for 2OL4 and manage the timing of this enrollment
and enablement closely. lnstallations and maintenance from 2013 enrollments continued post-
season through November 2013, and re-started in March 2014.
o EnerNOC is communicating to new customers that sign-ups completed after April 18 are unlikely
to be enabled in time for program start on June 9.r EnerNOC is actively communicating with all customers about the status of their enrollment in
order to ensure proper expectations.
2. Pay for Performance
Summoryo ln 2013, the ILC program changed to a "pay for performance" compensation model where
participants are compensated based on average availability during the program period. This
compensation model differs from the previous ILC program model in which customers were
generally compensated based on pump size and real-time metering was not a requirement.
Customer Feedbocko EnerNOC is working with customers to ensure that they understand how the calculations were
completed in 2013 and to identify any potential errors.
. Many customers' perception is that their aggregate availability for the 2013 season was lower
than expected.
Approach for 2074
o EnerNOC will continue to educate participants on the program model during new sales outreach
and pre-season conversations with current customers.o EnerNOC and Rocky Mountain Power are examining different approaches to calculating site
availability for future program years, but do not intend to make a change for 2014 based on a
single year of historic program data.
3. Site Size
Summoryo ln previous years, ILC participants could enroll and receive compensation for smaller pumps.
Because of the economics associated with installing new technology at each participating site,
Co nfi de ntio I o nd P ro prieto ry Poge 18
OTNERNoc ROCKY MOUNTAIN
POYYER
EnerNOC implemented an enablement fee for customers whose average expected load was less
than 50 kW in order to help pay for installation costs.
Customer Feedbock
o Customer feedback regarding pump size has been similar to discussions and reactions to the pay
for performance compensation model. When customers previously received compensation for a
number of smaller pumps, their overall compensation may have gone down in 2014 if those
pumps were not be enrolled under the new program model.
Approoch for 2074o EnerNOC and Rocky Mountain Power continue to explore ways to maximize cost-effectiveness
for small sites in the program. For 2OL4 account managers will continue to focus discussions
with potential participants on factors that impact availability, specifically crop type, irrigation
schedule, irrigation hardware, and harvesting schedule.o Expected capacity pricing tiers will not change.
Enablement
1. Device Installation Challenges
Summory
o Errors were made during early 2013 installations related to contractor training on the new
hardware.
Customer Feedbocko Some customers expressed frustration with delays to program enrollment and by the multiple
contractor visits required to resolve hardware issues.
Approoch for 2074
r EnerNOC has addressed these process errors and fixed the installs in question.
o Where appropriate, customers received a transition year payment to compensate for the
missing period of program participation caused by the issue.
Z. Maintenance Calls to Customers
Summaryo ln order to verify metering connectivity and device functionality, EnerNOC sometimes called
customers to ask about pumping schedules and inquire about status of EnerNOCs devices
during the 2013 program season.
Customer Feedbocko Particularly for some customers with many sites participating in the program, these calls
became overly burdensome.o Some customers complained that EnerNOC staff was not always familiar with site and pump
configurations or lacked an understanding of the customer's pumping operation.
Approach for 2074o EnerNOC is re-visiting processes in order to reduce the number of maintenance calls placed to
customers.o EnerNOC is exploring the possibility of implementing a remote "power off' signal to report
when power is cut to the ESS. This will provide additional information about the root cause of
issues.
o EnerNOC is conducting training for customer-facing teams about irrigation operations in order
to improve the quality of interactions with ILC participants.
Confide ntio I o nd P ro prietory Page L9
e rNERNoc ROCKY MOUNTAIN
POTI'ER
3. Pivots Running Dry
Summary
. Remote controls on EnerNOC metering devices are designed to shut off and restart water
pumps, but are not always able to also shut down or restart connected pivot irrigation systems,
depending on the configuration. When pumps are shut down but pivots continue to run, these
pivots are said to "walk dry'', moving across fields without watering crops.r Such an occurrence is an operational inconvenience for farm managers, who must manually
reset pivots to the start position at the time of pump shut off.
Customer Feedback
r Some customers asked whether EnerNOC's ILC equipment could provide functionality to include
pivot shutdown and restart.
Approoch for 2074
o EnerNOC is investigating technical solutions. Such requests are being addressed on a case-by-
case basis in order to determine the scope and cost of each individual project to determine
suitability for the RMP program.
4. Load not being captured on enrolled meters.
Summoryo EnerNOC is monitoring load at the pump panel, and therefore does not always capture smaller
pump or pivot load attached to the same utility meter but not directly connected to the primary
pump.
o ln some cases, these loads were curtailed during 2013 events but not included in availability for
compensation due to lack of metering data.
Customer Feedbocko Customers who experienced these unmeasured load reductions would prefer to receive
compensation for all devices that shut down during events, whether measured and metered or
not,
Approoch for 2074o EnerNOC is adjusting training for new installations in 2Ot4 in order to capture as much of this
additional load as possible. Contractors will place CTs prior to the starter on all new installs and
at existing sites when they are visiting the area for maintenance.
o EnerNOC is also currently field testing other CT models which will provide additional flexibility to
enroll sites where previously there were physical limitations to CT size.
Dispatch management
1. EventFrequency
Summaryo ln 2013, Rocky Mountain Power exercised ten of twenty available events (50%) and forty of
fifty-two available event hours (77%1, which amounted to event dispatch during Llo/o of all
program hours.
Customer Feedback
o Feedback from ILC participants suggests a perception that this utilization rate is high even
though there is an understanding of the program rules and variability year over year.
Approach lor 2074
o EnerNOC has communicated custome/s concerns to RMP.
o RMP plans to train the PacifiCorp Front Desk staff about the impacts of events on irrigators.
Co nfi d e ntiol o nd P ro pr ieto ry Poge 20
CTNERNoc ROCKY MOUNTAIN
B*FN*
2. Back-to-Back Event Pattern
Summory
I| -o When multiple events were called in a program week, the event days were always back-to-back.
ln addition, there was a string of consecutive events days from Friday, June 28 through
Wednesday, July 3.
Customer Feedbock
o A back-to-back event pattern is particularly difficult for irrigation DR participants. After two days
of deferred irrigation, it becomes more difficult to catch up on watering and achieve the same
crop yields.
Approach for 2074
o EnerNOC has brought this feedback to RMP to help ensure that PacifiCorp's Front Desk
understands the impact of back-to-back dispatches on irrigators.
3. Day-Of Event Cancellations
Summoryo Event cancellations were a primary source of concern for participants in 2013. There were five
events cancelled, each within five hours of the scheduled event start time.
Customer Feedbock
r Cancellations are most challenging for irrigators who make decisions early in the morning about
their operations and staff resources. Additionally, due to a business model that compensates
participants for availability, if irrigators who had already planned to be shut down for the event
day did not resume normal operations upon receiving the cancellation notification, their
availability and payments were negatively impacted.
o This problem also impacts the day-ahead baseline when an event is called for the day following
a cancellation.o Several participants have communicated that they would like cancellations to count towards
event maximum limitations. lf this were the case in 2013, the program would have been called
in excess of the prescribed fifty-two event dispatch hours.
Approoch for 2074o RMP recognized that day-of cancellations or reserving the program day-ahead is not the
intended use of the program.
o RMP is working to avoid event cancelations unless in the case of a true system emergency.
4. Event Notifications
Summoryo As part of EnerNOC's standard process, participants received day-ahead notifications of event
start and end time, a reminder notification approximately four hours prior to event start, and
event end notifications from EnerNOC. Notifications were delivered via phone call, email, and
SMS.o ln cases of back-to-back event days and/or cancellations, the volume and cadence of
notifications in 2013 was higher than expected for some customers.
Customer Feedbocko While EnerNOC received a feedback from participants about the utility and timing of event
notifications via phone, email and SMS, much of it was conflicting. For example, some providers
did not want to receive the restore/event end notifications, while others appreciated these
messages.
Co nfi de ntio I o nd P ro prieta ry Poge 21
CTNERNoc ROCKY MOUNTAIN#s*
Approoch for 2074
o EnerNOC is working to improve its notification system in order to provide greater flexibility in
2014. EnerNOC expects to be able to provide more explicit communication about which pumps
are involved in a dispatch via email and to condense multiple notices into one message delivery.
5. OptOutand Control ofPumps
Summory
o ln 2013, customers were required to call EnerNOC's support center to opt out of events.o ln previous years, customers could use the legacy system to log in remotely and opt out.
Customer Feedbocko Overall, feedback suggested that the 2013 opt out process worked well for customers and the
event management team.o After the first two events, EnerNOC organized the process around RMP's Site lD which helped to
ensure effective and accurate communication with customers.o A handful of current and potential participants requested that this functionality be provided in
EnerNOC's portal for future program years.
Approoch for 2074o EnerNOC is not able to provide web-service opt out functionality for 2OL4 but will continue to
explore the needs and development of this functionality for future years.
6. Pre-Season Portfolio Test
Summoryo A one-hour portfolio test was held prior to the mandatory program season start on June 4, 2013
for one hour (1:00 to 2:00 pm MDT). Only three sites opted out of the test, two of which were
under construction and the third because the primary contact was out of town.
Customer Feedbock
o The pre-season portfolio test was a common pain point for 2013 ILC participants. Program
participants complained that the pre-season portfolio test was inconvenient and not worthwhile
as they did not receive direct compensation for participation in this test.
Approoch for 2074o While a test was necessary in 2013 due to the new technology platform and business model,
EnerNOC and RMP do not intend to conduct a portfolio-wide test prior to the 2014 season start.
Equipment for existing customers will be tested on an as-needed basis to ensure pre-season
readiness.
o Newly-enabled sites will continue to undergo an acceptance test to verify equipment
functionality after installation.
Co nfi de ntio I o nd P ro pri eta ry
ROCKY MOUNTAIN
POWER
ADtVtStoN oFmoflconP
Appendix 6
Idaho Irrigation Post Peak Report
(P r oprie tary and C onfi de nial)
ROCKY MOUNTAIN
HHIYER,2013 ldaho lrrigation Post Report
-ROCKYMOUNTAIN\ A D|V|STON OF PACTFTCORP
2013 ldaho lrrigation Post Peak Report
Executive Sponsor
Douglas N. Bennion, P.E.
Study Team
Director
Ken Shortt
Principal Authors
Tony Perkins
Mike Anderson
Contributors
Scott Murdock
Bill Comeau
November 2013
Field Engineering Page I of21 I t/2013
ROCKY MOUNTAIN
H*HN-,2013 ldaho lrrigation Post Report
Table of Contents
EXECUTIVE SUMMARY
IRRIGATION LOAD CONTROL PROGRAM DETAILS 11
Load Control Events in 2013 ....................1I
System Concerns with ldaho Inigation ......................13
Harmonic Issues .......................13
Load Control - Voltage lssues Due to Load Control Events. ................13
CONCLUSIONS t7
Harmonic Pollution Details.......
Crops Load
Field Engineering Page 2 of2l I t/2013
ROCKY ]iIOI'Nr:AIN
2013 Idaho lrrigation Post Report
lntentionally left blank
Field Engineering Page 3 of21
ROCKY MOUNTAIN
HSIYE#*"2013 ldaho lruigation Post Report
EXECUTIVE SUMMARY
Rocky Mountain Power conducts an ldaho post peak irrigation system review to understand the impacts
of Idaho irrigation load, and in particular the impact of the Idaho [rrigation Load Control Program. This
annual report communicates the findings, conclusions, and recommendations resulting from the review.
First, the 2013 report analyzes system load data and irrigation load patterns during the 2013 irrigation
season (June I through September l5). It discusses total Rocky Mountain Power Idaho load versus
Idaho irrigation load, and irrigation load control program participants' load versus non-participants'
load. In addition, it discusses how crop rotations and weather affect irrigation, and summarizes the
transmission system load in heavy use irrigation areas.
Second, the report analyzes the demand side management Irrigation Load Control Program and the
effects the program has on the transmission and distribution system. It discusses the details of the
dispatch events for 2013 and some of the system concerns with the program.
Finally, the report identifies conclusions and makes recommendations.
Some of the key informational points from the report are:
o The Rocky Mountain Power Idaho peak demand occurred on July 1,2013 when peak irrigation
usage occurred.
o Irrigation load in Idaho represents 37Yo of the State total peak load.
o Idaho has 4863 irrigation sites with l9% of these sites participating in the Irrigation Load
Control Program.
o The Irrigation Load Control Program was dispatched ten times in 2013. The median estimated
curtailed load dispatch was 135 megawatts. The maximum dispatch event resulted in an
estimated curtailed load of 167 megawattsl.
o Based on work completed in2011 and early 2012,the number of ANSI range A voltage
violations and the severity of the violations were reduced in 2013.
1 See Table 1, Maximum curtailment event occurred on71O3/2OL3
Field Engineering Page 4 of2l il/2013
ROCKY MOUNTAINPOYER 2013 Idaho lruigation Post Report
SYSTEM LOAD DATA ANALYSIS
Idaho lrrigation Load
Irrigated agricultural land in southeastern Idaho served by Rocky Mountain Power is primarily in the
Snake River Plain. This area is an inverted triangle shape from Shelley on the south to Dubois on the
northwest and Ashton on the northeast; Arco on the west to Ririe (northeast of Idaho Falls) on the east.
Other areas in Idaho with irrigated agricultural land served by Rocky Mountain Power are: Preston,
Malad, Marsh Valley, Montpelier, and in the Gem Valley around Grace, Bancroft and Chesterfield.
These other areas have much less irrigation load than the primary area in the Snake River Plain. See
Figure I for a view of the irrigation loads. The green dots represent irrigation customers.
Irrigation water comes from either surface water-rivers, canals, ditches----or groundwater from wells.
Irrigation customers connected to the Rocky Mountain Power system use pumps driven by electric
motors to move water from the source, and pressurize it into an irrigation system. Electric pump motor
sizes reach up to 1000 horsepower.
Field Engineering Page 5 of2l t t/2013
ROCKY MOUNTAIN
POWER 2013 ldaho lrrigation Post Report
Larger pump motors are used for drawing groundwater out of the deep wells in the area.
Irrigation systems can be a center pivot system' lFigure 2), a wheel line3 (Figure 3), or hand iinesa
(Figure 4). A center pivot system will run continuously for the time it takes for a complete cycle. Wheel
lines and hand lines run 8 to 24 hours and then turned off to be moved manually.
Figure 3, Typical Wheel Line - Photograph
courtesv USDA NRCS
Figure 4, Typical Hand Line -
Photocraph courtesy USDA ERS
On July l,2Ol3 Rocky Mountain Power's ldaho loads peaked at 814 megawatts at l0 pm MDT. Using
inigation load control participant data as a proxy, it is estimated6 302 megawatts of Idaho irrigation load
and 512 megawatts of non-irrigation load occurred on July 1,2013. (Figure 5)
ldaho System Loading O7lOtlzOI.S*
I Non iritrtion [o.d I lrritation toed
Figure 5, ldaho System Loading
2 A pipe with sprinklers carried by wheeled towers in an arc around a center point.
3 A pipe with sprinklers attached on large wheels that is moved in a line across a field.a Pipes with sprinklers attached that are laid in a line on the ground.
I taano toad was 14.8% of the Rocky Mountain Power total system load on July 1, 2013tForprrpor"rofthisreport irrigationloadcontrol participantdataindicatesadiversityfactorof65%whichwasusedtoestimatetotalsystemirrigation
impacts.
Figure 2, Typical Center Pivot
Field Engineering Page 6 of2l t 1/201 3
ROCKY MOUNTAIN
Hgl[Es*2013 ldaho Irrigation Post Report
Rocky Mountain Power had 4,863 irrigation sites connected in the State of Idaho in 2013. The
undiversified demand for these 4,863 irrigation sites was 458 megawatts in July 2013. Of these 4,863
sites there were 941, or l9oh, that participated in the company's lrrigation Load Control Program
(Figure 6).
ldaho lrrigation Sites 2013
r Total Number of lnitltion Lord Control Sh6 a Tot.l rcn Lo.d Contrcl lritttion Sit6
Fiture 6ldaho lrrigation Sites
ln July, the total undiversified demand of sites participating in the load control program was l9l
megawatts. On the day of the peak, 115 megawatts of load was curtailed by load control program
participant sites, another 42 megawatts was available to curtail but needed to be excluded from the
dispatch due to system conditions, and 145 megawatts was utilized by non-participating irrigation sites.
This totaled an estimated302 megawatts of irrigation load in ldaho. See Figure 7.
ldaho lrrigation Site Load July 1, 2013
I Totrl Load of Non Lold Control Sit6
r Tdd Load of Load control sh.s
t Lord control not utilired by RMP ducto systcm coMhions
FigweT,ldaho lrrigation Customer Load July 1,2013
Field Engineering Page 7 of2I I t/2013
ROCKY MOUNTAINPO,YER 2013 ldaho lrrigation Post Report
Idaho Weather
Southeastern ldaho weather in 2013 followed a similar pattern as 2012. The growing season
precipitation was less than 2009,2010, and2011. Irrigation of Southeastern Idaho crops is necessary
because the weather during the summer growing season is typically warn and dry. The amount of
spring precipitation in May and June, affects when inigation begins. When there is less precipitation in
May and June, irrigation begins earlier.
June, July and August air temperature and precipitation affect the total summer irrigation electrical load.
Higher air temperatures and lower precipitation lead to higher summer irrigation load, since more
irrigation water will be needed on the crop. Data on precipitation, temperature, and irrigation powerT
demand for April through August of 2013 are shown in Figure 8.
5m
450
400
350
SsmI
f3ltzsoE*t<f,*
150
1@
50
0
April - August 2013 Weather
I 2013 DaiV Preclp., inches
-2013
DaiV High Temp, degrees F N A
-2013,8SUBTOTAT
MVA
fl \I\I
h/\-rA/r Y rl4
Il'\J n
14 rI
t
^^AJ\Nr//\l'rvr t/
N'V
M \^f N
1.1^,nrf*!N .1/--n
,1,
o.40
l-
I :
o.ar $
E
?a
,otsoCododod"p-,{u{*{pd"et{n"{p{*'d
Figure 8, April - August 2013: Weather and Power Use
TSeeldahoTransmissionSystem, pagelO,foradescriptlonoftheeightsubstationsreferencedinFigures
Field Engineering Page 8 of21 I 1/2013
ROCKY MOUNTAIN
HSHY,E*"2013 ldaho lrrigation Post Report
According to Idaho Falls climate reports8, both the summer and spring were waffner and drier than
normal. Average temperatures were warrner in20l3 by 5 degrees in June, 5.8 degrees in July and 4.7
degrees in August.
There were 27 days in July and 23 days in August with the high temperature above 90 degrees and 30
days each month were sunny and clear.
Average precipitation for June and July, and August is 2.22 inches in normal years. The actual
precipitation total for June, July, and August 2013 was 1.08 inches,49yo of normal.
A comparison between 2012 and 2013 summer weather is shown in Figure 9. A higher temperature peak
is seen in2013 than in 2012.The scarcity of growing season precipitation in 2013 can be seen Figure
10.
Sum mer 2012-2013 Weather Com pa rison
1@
90
80
70
60
.s-,)u4
5F
40
30
20
10
o
A["v
/t
I 2013 DaiV Precip., inches
2012 DaiV High Temp, degrees F
-2013
DaiV High Temp, degrees FLli
0.4
oE:
0., $oa
Ia
1-May 8-May 15-May22-May29-May sJun 12Jun 19-,un 2GJun 3Jul lGJul 17-Jul 2+.,u1 31-rul 7-Aug 1+AuB21-Aug 2&Aug
Figure 9, Summer 2OL2 and 2013: Weather Comparison
8 Weather data is shown for ldaho Falls by the Pocatello area branch of the National Weather Service for the summer of 2013
Field Engineering Page 9 of2l I t/201 3
ROCKY MOUNTAIN
HSIYE#*,2013 ldaho lruigation Post Report
Rain Accumulation
from June 1st to Aug6t 31st
5
4.5
4
3.5
3
o! arc
2
1.5
1
0.5
0
Figure 1Q rain accumulation in southeastern ldaho
Page 10 of2lField Engineering
ROCKY MOUNTAIN
POA'ER 2013 Idaho lrrigation Post Report
Idaho Transmission System
Most of Rocky Mountain Power's southeastern ldaho irrigation customers are served by circuits that
originate at one of the eight major transmission substations in the area. These transmission substations
and the lower voltage distribution substations and circuits function as a system to supply power to about
9lYo of all irrigation loads in ldaho. The transmission substations, all in the Snake River Plain in
southeastem Idaho, are Amps, Scoville, Big Grassy, Bonneville, Cinder Butte, Goshen, Jefferson and
Rigby. Similar to2012, the eight substation 2013 composite loading started earlier in the summer and
set a slightly higher peak than 201 I . The 201 3 load peak was slightly higher than 2012 and 201I . See
Figure 1 1.
Most of the variability portrayed in the graph is due to weather and the maturation period of the crops
grown, each individual year may fluctuate drastically.
Figure 11,8 substation composite loading
8 substation composite loading for ldaho
2011 DalV Pealc
-2012
Daily Peaks
-2013
Daily Peaks
o 2013 Lord Control Days
eBeietr33i$$f f f f,i E i i = ; i i E f, * i E rgg$g
Field Engineering Page I1 of2l I 1/201 3
ROCKY MOUNTAIN
HSIYER,2013 ldaho lrrigation Post Report
IRRIGATION LOAD CONTROL PROGRAM DETAILS
Irrigation Load Control is offered to irrigation customers receiving electric service on Schedule 10,
Irrigation and Soil Drainage Pumping Power Service. Participants allow the curtailment of their
electricity usage by working directly with a third party administrator, EnerNoc. Participants' irrigation
equipment is set up with a dispatchable two-way control system giving the Company the ability to
dispatch load control events. Participants are provided a day-ahead notification in advance ofcontrol
events and may opt-out of dispatch events as needed. The 2013 curtailment events were not in response
to limitations on Idaho's substations or transmission systems. Capacity exists to serve all connected
irrigation customers in [daho. Rather, the curtailment events are due to other factors affecting the
broader system.
Load control events in 2013
The 2013 Irrigation Load Control Program was available for 52 hours from June lOth to August 16th.
Rocky Mountain Power dispatched ten irrigation load control events and one test event on June 4,2013.
Idaho load control events for 201 3 ranged from 79 megawatts to 167 megawatts as recorded by
Company SCADA data. The median curtailed load dispatch was 135 megawatts.
Table 1, Load Control Event Dates and Data *Amps and Camas Subs excluded from dispatch
The program is estimated to have curtailed I I 5 megawatts of load on July I , 201 3, between 3 p.m. and 7
p.m. Mountain Standard Time, the peak day (See Figure l2). Due to some isolated system concerns,
irrigation load control participants served from the Camas and Amps substations were excluded from the
load control curtailment event on the peak day. It is estimated an additional42 megawatts (157 total)
would have been curtailed if all participating customers were included in the load curtailment dispatch.
Date
opt-outs
(MW)
Times (MPT)
Reductions
(MW)Dispatch Factors
6h8120L3 2.6 3pm-7pm 135 High temp, system balancing
6128120L3 6.5 3pm-7pm 163 High temp, system balancing
71112073*11.9 3pm-7pm 115 High temp, system balancing
71212073 20.5 3pm-7pm 150 Hieh temp, system balancing
713120t3 22.5 3pm-7pm L67 Hieh temp. svstem balancins
7lel20t3 22.5 3pm-7pm L54 High temp, system balancing
7l70l2OL3 9.3 3pm-7pm L62 High temp, system balancing
7lL&l2OL3 15 3pm-7pm L45 High temp, system balancing
7lzsl20L3 13.8 3pm-7pm 79 High temp, system balancing
7126120t3 L2.8 3pm-7pm 82 High temp, system balancing
Field Engineering Page 12 of21 I t/2013
ROCKY MOUNTAIN
H*YER.2013 Idaho Irrigation Post Report
710U2013 Curtailment*
====>==>=>== == E= =====E==EEBE EEBE EEEE EE EEEE EEEEEA; ri'6 {,i.i 6 F. rii oi g i S J ri'd t,ri,ij F. dd oi 3 i S
Projected load without load control
Figure 12, July 1st load curtailment profile
*Data from Hourly Data of System Loading for RMP summer 2013.
Field Engineering Page lj of2l r r/2013
ROCKY MOUNTAIN
PrO\ lER 2013 Idaho lrrigation Post Report
System Concerns with Idaho Irrigation
Harmonic Issues
Harmonic pollution continues to be a problem. Since 2008, Rocky Mountain Power has actively worked
to mitigate harmonic pollution in Idaho. The largest contributors to the harmonic pollution on Rocky
Mountain Power's irrigation feeders are unfiltered variable frequency drives used on large irrigation
pumps. Non-linear loads used in potato storage or processing also contribute to harmonic pollution.
The number of pivots adversely affected by harmonic pollution increased in2013. See Figure 13.
Pivot system problems
I Number of pivob that walked off their intended paths
L4
L2
10
8
6
4
2
0
Figure 13, Pivot system problems
A detailed discussion about harmonic pollution can be found in Appendix I.
Load Control - Voltage Issues due to Load Control Events
Since change in load on the power system affects the system voltage, an irrigation load control event
that reduces load affects system voltage. Load reduction causes the power system's voltage to increase,
sometimes above the prescribed range of ANSI C84.1. Although equipment with automatic controls is
used to adjust voltage, it does not react instantly to changes in voltage on the system, and may take up to
several minutes to adjust the voltage to the proper range in response to severe changes.
The following factors contribute to the number of ANSI range A voltage violations:
Field Engineering Page l4 of21 I t/2013
ROCKY MOUNTAIN
Po\A'ER
2013 ldaho lrrigation Post Report
o Irrigation loads are often geographically concentrated in particular areas of the network.
o Curtailing large blocks of participating inigation load concentrated on a single circuit or a single
substation at the same time increases the magnitude of the voltage change.
o Circuits serving predominately irrigation load with a high percentage of Irrigation Load Control
Program participants will magnify the voltage rise on the circuit during an irrigation load control
event.
Metering at an irrigation customer site shows the voltage levels during a typical load control event
where the entire block of load is curtailed at the same time. See Figure 14.
710312013 load control event
Customer voltage on Hamer 11
530
520
510
6gr*
490
480
470 InFor$$$t{ t-.1 F{
F{ arl ln F (,.| t{ ar') rJl f\ Crl r-{ an utrfl ra u.l rn u.'| o o o o o r{ r{ r<.t lf ti <' st rJ'l lj.t lJt tn rJ) st r.r1 rJ)r-{ d r{ F{ r-{ Fl F{ r-{ r-l Fl r-{ F{ Fl
Hour
- -ANSI Range A Max
-Voltage
NominalVoltage
Figure 1d Typical load controlled event on Hamer Sub
Early in the 2013 growing season voltages in excess of the ANSI C84.1 Range A parameters occurred
and resulted in damage claims from customers due to high voltage failures of their equipment. The
condition was corrected upon discovery. EnerNoc altered the load curtailment events to drop load in
stages over a 10 minute period instead of the entire load instantaneously. Demand Side Management's
objective is to reduce load in large blocks simultaneously in order to minimize system peaks and to
maximize the energy available to market. Operation's objective is to maintain system voltage in the
proper range without excursions, which is difficult to do when load is reduced in large blocks. The
adjustment to the load curtailment implemented by Rocky Mountain Power successfully mitigated the
voltage excursion seen in the early part of the 2013 growing season.
Field Engineering Page l5 of2l t t/20t 3
ROCKY MOUNTAIN
PolAIER 2013 Idaho Iruigation Post Report
During the past few years Rocky Mountain Power has completed the following activities to address
voltage issues related to irrigation load control switching:
o Installed a 3-step capacitor bank on the 69 kilovolt bus at Big Grassy substation before the 201I
irrigation season;
o Replaced manual capacitor banks with automatic sensing capacitors that switch automatically to
maintain acceptable voltage levels. e
o Forty Six automatic switched capacitors were installed and 59 manual capacitors were
removed.
o This work was completed on 14 circuits before the start of the 2012 irrigation season.
o Installed metering inside seven different substations and on four different customer accounts on
irrigation circuits to understand and monitor voltage issues
The stepped capacitor bank and automatically switched capacitor banks are working well. Voltage
swings on the 69 kilovolt bus at Big Grassy substation were less after this work than in the years before
it was done. See Figures 15 and 16.
Figure 15, Big Grassy Voltagg 3-step capacitor was installed before 2011 season
s Part of a settlement reached in 2011 with the ldaho Commission staff, the ldaho lrrigation Pumper Association, and Rocky Mountain Power
Transmission Voltage at Big Grassy Sub 2fi)9, 2010 and 2011
-Mey 8-M.y 15-May 22-M.y 29-M.y s-Jun 12-Jun
16
74
72
70
E*"g
56
64
62
60
1 31Jul 7-AuI 1,|-Aur 21-Aus 28-Aus
Field Engineering Page l6 of2l I t/201i
ROCKY MOUNTAIN
POTTER
2013 ldaho Irrigation Post Report
76
74
72
70
IC*..t
56
64
52
50
TransmissionVoltage at Big GrassySub 201.2 and 2013
c=-========rp!p!f'df i i E f t f t f f t ; i ii i 1 i I i i : ; i ; i E I i i i g I r i i i i i i i i
Fiture 16 Big Grasry Voltage after line-type controlled capacitors were installed
Field Engineering Page I7 of2l il /2013
ROCKY MOUNTAIN
FTOWER 2013 ldaho Irrigation Post Report
CONCLUSIONS
The report analysis leads to these conclusions:
o Idaho's overall peak load was 814 megawatts on July 1,2013 at l0 pm MST of which302
megawatts was from irrigation customers. The irrigation load control program shifted the peak to
a later time period in the evening.
The Idaho irrigation load represents a significant percentage of Idaho's peakload,3To/o.
The trrigation Load Control Program was dispatched ten times in 2013. The median estimated
curtailed load dispatch was 135 megawatts.
The distribution system improvements that were added prior to the 2012 irrigation season
continue to minimize the voltage swings on the 69 kilovolt bus at Big Grassy substation.
Voltage excursions have occurred during load control events. However, the capacitor bank
mitigation efforts from previous years and the staged load dropping implemented this year
minimized the number of voltage excursions.
Harmonic pollution is a growing problem on Rocky Mountain Power's irrigation distribution
circuits.
Load curtailment must be managed in small increments rather than large blocks. This allows
voltage control equipment time to react to the change in loading and adjust the voltage to stay
within ANSI C84.1 Range A parameters.
RECOMMENDATIONS
o Continue efforts to make irrigation load control events a win-win for customers, the State of
Idaho, and the power company.
o Distribution circuit and voltage monitoring is required to ensure proper system operation.
o Continue efforts to educate irrigators about variable frequency drives, harmonic pollution
mitigation and customer's responsibility for their own systems.
a
a
Field Engineering Page 18 of21 I t/2013
ROCKY MOUNTAIN
Hgmfu"2013 ldaho lrrigation Post Report
APPENDIX I
Harmonic Pollution
Harmonic pollution is unrelated to the Idaho's Irrigation Load Control Program. However, it is related
to irrigation systems and is briefly discussed here. The company's mitigation effort to significantly
reduce harmonic pollution appears to be working as irrigation systems modified to minimize harmonics
are not creating problems for the customers or the power company. However, harmonic issues in the
area continue to be a concern to Rocky Mountain Power.
Twelve different pivot systems on six different circuits walked off of their intended paths in 2013. A
graphical view of the offending pivots is shown in Figure A-1. Many of the pivots left their intended
path multiple times. One of these pivots broke a 3-phase tangent pole on Moody #12 and caused a 6.9
hour outage to I 7 customers on June I I th, 20 I 3.
O Rrd rpot rhowr locrtlon of phrot3 that wrlkcd off of lnt.nd.d p.th
/'!\l-f:-'Y'" i ,,' !t- j
Figure A-1, Pivot systems that walked off their intended path
a?
^
7t
Field Engineering Page l9 of2l 11/2013
ROCKY MOUNTAIN
POIA'ER 2013 lduho lrrigotion Post Report
Harmonic pollution caused by unfiltered variable frequency drive pump loads leads to the irrigation
center pivot swing arms steering away from their pre-determined paths of travel. An electrically charged
trace wire is buried in the ground that provides the sensors in the center-pivot swing arrns a path to
follow. The signal on the trace wires is similar to the l3th, l7th, and l9s harmonics currents produced by
unfiltered variable frequency pump motor drives. The antenna anay used by the pivot system can be
influenced by the elevated harmonic levels. This can cause the swing arm to steer away from the desired
path. Figure A-2 shows a typical antenna array system that is used to follow the buried trace wires.
Efforts to mitigate the issues from harmonic pollution included several strategies. First, Since 2008
Rocky Mountain Power has provided feedback and education to irrigators and electrical contractors
regarding the importance and application of filtering for variable frequency drives to insure IEEE 5 l9
compliance.
Second, in 201l, Rocky Mountain Power reviewed susceptibility issues with center-pivot system
designers and manufacturers. According to the center-pivot manufacturers, the designs have successfully
worked for the last 30 years with very few problems and they were thus unwilling to change their swing
arm tracking design. Further, the incompatibility of harmonic guidance systems and harmonics from
variable frequency drives has not been well understood since variable frequency drives were not widely
used in irrigation systems until recent years. In the future GPS tracking swing arrns are expected to
replace current technology which will help alleviate the existing guidance problem.
Third, Rocky Mountain Power monitors the status of distribution line capacitor banks. Capacitors act as
frequency sinks for higher order harmonics. Thus, if a capacitor bank is not working correctly, there is a
greater chance the harmonic pollution levels on the system could affect tracking of the center-pivot
swing arm.
Last, Rocky Mountain Power is working towards installing GE KV2C meters for irrigation customers in
2014. These meters are capable of measuring and storing harmonic pollution data and downloading the
data for evaluation to determine compliance with harmonic levels. Roughly 780 irrigation revenue
meters will be replaced with the GE KV2C meter over the next three years. The proposal to install these
Figure A-2, Typical Center Pivot Antenna Array
Field Engineering Page 20 of2l I t/201i
ROCKY MOUNTAIN
HgxE#*2013 Idaho Iruigation Post Report
meters is still in the planning stage, but should begin implementation before the start of the 2014
growing season.
Rocky Mountain Power will continue to monitor harmonic issues and address customer complaints in a
prompt and efficient manner. The company expects its mitigation efforts along with effective customer
participation will reduce harmonic pollution. A growing company/participant parbrership is needed to
provide reliable electric service and improved customer satisfaction.
Idaho Crops Load Detail
The primary crops grown in the Rocky Mountain Power service territory in southeastern Idaho are
alfalfa, barley, potatoes, and wheat. Wheat, barley, and other grains are watered typically in late May,
June and July. Watering stops in late July or early August to allow the grains to dry for harvest. Potatoes
are watered through the whole summer. Alfalfa is also watered through the entire summer except during
intervals where it is cut, dried, and harvested. These dates vary each year, but generally occur in mid to
late June and late July to early August.
Figure A-3 represents the periods of highest load potential using ten-year historical data from the
watering periods of the most common crops in the program. The 2010,2011,2012, and2013load data
for the Big Grassy substation which primarily serves inigation load is included to denote the variability
for any given year.
rLrbrrD(t)
-A[.f.|o(L]rwlldrO('.l
-pol.lGIr(ilJg crsry so!'to (ra)
-llg6rary9b'lt
{rl
-8ts
Grasil Sub .r2 ltl
-ari8
6r5.y
'|D'13 fil
rOAt
Flgure A-3, ldaho Crop Detail
Field Engineering Page 2I of2l
1r.at
I t/2013
ROCKY MOI..hTTAINffi*2013 ldaho Inigation Post Repofi
Most of the variability porhayed in the gaph is due to weather and the maturation period of the crops.
Alfalfa, accounting for 5l%6 of the crop within the Idaho lrrigation Load Control program, is one of the
crops that contribute to this variability since watering discontinues two to three times for hanesting.
Although average crop and weather pattems provide a good indicator of what may occur, each
individual year may fluotuate drastically.
Field Engine*ing Page 22 of2l I I/2013
ROCKY MOUNTAIN
POWER
ADN'EOI{ OFRAOR@RP
AppendixT
Idaho Measure Installation Verifications
Idaho Measure Installation Verifications
Low Income Weatherwation
All projectso All measures are qualified through US Department of Energy approved audit tool.o 100 percent inspection by agency inspector of all homes treated, reconciling work
completed and quality (corrective action includes measure verification) prior to invoicing
Company.o Community Action Partnership Association of Idaho (CAPAI) and state inspector follows
with random inspections.
o Company program manager joins CAPAI and state inspectors during their monitoring
session.
Home Energy Savings
Site inspections by Program Administrator staff for the following retrofit measures (> 5 percent)
o Duct sealing and insulationo Duct sealingo Gas fumace with electrically commutated motor (ECM)o Heat pump best practices installation and proper sizingo Heat pump tune-upso Heat pump water heaterso Insulationo Windows
Pre and post site inspections of 100 percent by Program Administrator staff of all multi-family
projects.
No site inspections are conducted for the following measures. However all post-purchase
incented measures undergo a quality assurance review prior to the issuance of the
customer/dealer incentive and recording of savings (i.e. proof of purchase receipt review) and
eligible equipment review. Additionally, customer account and customer address are checked to
ensure the Company does not double pay for the same measure or double count measure savings.o Air conditionerso Clothes washerso Dishwashero Ductless Heat Pumpo Evaporative coolerso Ground Source Heat Pumpo Heat pump upgrades/conversionso Light fixtureso Refrigerators / Freezerso Water heaters (excluding heat pump water heaters)
Other measureso CFLs and LED's - retail channel, manufacturer agreements and program administrator sales
record reviews of qualifying equipment. Invoicing and retail pricing is administered by
program administrator.
Refrigerator Recycling
Company hires an independent inspector to phone survey > 5 percent program participants and to
site inspect > 5 percent of program participants in order to verifying program participation,
eligibility of equipment, that vendor pick-up procedures are followed (equipment is disabled at
site, kits distributed, etc.) and to survey customer experience.
FinAnswer Express
For projects delivered by third party program administrator
Lighting projects
o Retrofits - 100 percent pre- and post-installation site inspections by third party consultant
of all projects with incentives over a specified dollar amount. Project cost documentation
reviewed for all projects.o New construction - 100 percent post-installation site inspections by third party consultant
of all projects with incentives over a specified dollar amount.o A percent of post-installation site inspections by program administrator of projects with
incentives under a specified dollar amount.
Non-lighting projects (typically upgrade/listed measures, custom measures)o 100 percent of applications with an incentive that exceeds a specified dollar amount will
be inspected (via site inspection) by program administrator.o A minimum of a specified percent of remaining non-lighting applications will be
inspected, either in person or via telephone interview, by program administrator.
For Company project manager delivered projects (lighting and non-lighting)
Lighting and non-lightingo 100 percent pre/post-installation site inspections by third party consulting engineering
firms, invoice reconciled to inspection results.
Energy FinAnswer
All projects
o 100 percent pre and/or post-site inspections by third party engineering consultant,
inspection is reconciled with project invoice for energy efficiency retrofit measures
provided by customers. No pre-inspection for new construction.o Most projects have a commissioning requirement.
All Programs
As part of the third-party program evaluations (trvo-year cycle) process, the Company is
implementing semi-annual customer surveys to collect evaluation-relevant data more frequently
to cure for memory loss and other detractors such as customers moving and data not be readily
available at evaluation time). This will serve as a further check verifying customer participation
and measures installed.
Additional record reviews and site inspections (including metering/data logging) is conducted as
part of the process and impact evaluations, a final verification of measure installations.
ROCKY MOUNTAIN
POWER
A Dtvtstot{ 0F moEcoRP
Appendix 8
Idaho Program Evaluation
Recommendations and Responses
Idaho 2013 Evaluations
Program Evaluation Recommendations and Company Responses
Evaluation reports provide detailed information on the process and impact evaluations performed
on each program, summarizing the methodology used to calculate the evaluated savings as well
as providing recommendations for the Company to consider for improving the process or impact
of the program, as well as customer satisfaction.
Outlined below is a list of the programs, the years that were evaluated during 2013 and the third
party evaluator who completed the evaluation. Program evaluations are available for review at
www.pacifi corp.com/es/dsm/idaho.html
Program Years Evaluated Evaluator
See ya later, refrigerator 20tt-2012 The Cadmus Group
FinAnswer Express 2009-2011 Navigant Consulting Inc.
Inigation Energy Savers 2009-2011 Navigant Consulting Inc.
Energy FinAnswer 2009-2011 Navigant Consulting Inc.
Company responses to the program recommendations contained in the 2009 - 201 I evaluations
are provided below.
The third party evaluator's recommendations and Company's responses are provided in the
below Tables:
Table 1
See ya later, refrigerator@ Evaluation Recommendations
Evaluation Recommendations Rocky Mountain Power Action Plan
Rocky Mountain Power should consider adjusting
its expected per-unit savings for future program
years to reflect the evaluated per-unit gross savings
values of 1,022 kWh for refrigerators, 1,033 kwh
for freezers, utd 47 kWh for kits, as found in this
evaluation.
Refrigerator and freezer savings were updated for
2014 reporting based on the evaluation results. Kit
savings were updated using hours ofuse, in-service
rates and waste heat factor from the evaluation and
further modified based on EISA lumen equivalency
for a oer kit savinss of 30.23 kWh.
The program administrator and Rocky Mountain
Power should continue with improved tracking of
Kit tracking was implemented at the beginning of
2013.
Evaluation Recommendations Rockv Mountain Power Action Plan
enerry-savings kit delivery, including recording
whether or not a kit was delivered. This change has
already been implemented beginning in 2013.
Rocky Mountain Power should consider revising
the measures provided in the kits, as the Enerry
Independence and Security Act of 2007 (EISA)
standards in20l4 will lead to decreased savings for
60-watt replacement CFLs. If kit measures are
revised, Rocky Mountain Power should update
expected per-unit savings for kits accordingly.
Refrigerator and freezer savings were updated for
2014 reporting based on the evaluation results. Kit
savings were updated using hours of use, in-service
rates and waste heat factor from the evaluation and
further modified based on EISA lumen equivalency
for a per kit savings of 30.23 kWh.
For future cost-effectiveness calc ulations, Cadmus
recommends that Rocky Mountain Power update
measure lives to align them with the values adopted
in the most recent Regional Technical Forum
(RTF) measure workbooks:
Refrigerators: 7 years
Freezers: 5 years
CFLs (kits): 6 years
Technical Reference Library has been updated
based on evaluation recommendations for measure
lives.
Table2
FinAnswer Express Evaluation Recommendations
Evaluation Recommendations Rocky Mountain Power Action Plan
Recommendation 1. Review marketing messages
and channels to engage commercial
andindustrial customers who are not aware of
efficiency opportunities. Half of participants and
three-quarters of non-participants did not believe
there are additional opportunities to improve
electric efficiency at their firm. Marketing
collateral that educates and challenges customers to
reevaluate their position may be necessary to reach
these customers. Reaching new customers is
essential to ensure long-term success ofthe
program in cost-effectively meeting energy savings
soals.
The Company is increasing its efforts to reach
small and mid-sized business customers and this
evaluation feedback is informing the effort and
customer communications.
Recommendation 2. Continue to nurture and
develon the trade allv network. Vendors are a
The Company continues to invest in nurturing and
developing the trade ally network.
Evaluation Recommendations Rockv Mountain Power Action Plan
critical program delivery mechanism for post-
purchase incentive progr€rms, like FinAnswer
Express. Third-party program administrators,
serving as Trade Ally Coordinators, should
continue their efforts to develop and nurture strong
vendor relationships and to build additional vendor
relationships. Strong relationships encourage trade
ally vendors to take the time to market the program
effectively.
Table 3
Irrigation Energy Savers Evaluation Recommendations
As a result of the evaluation recommendations, the Company filed an Application to revise
Schedule 155, lrrigation Energy Savers program. To see the details of the recommendations,
please refer to the program evaluation report using the web link above.
Iable 4
Energy FinAnswer Evaluation Recommendations
Evaluation Recommendations Rockv Mountain Power Action Plan
Recommendation 1: Consider revised marketing
strategies to increase lead generation. More than
three-quarters of eligible industrial non-participants
did not believe there were further actions they
could take to improve efficiency at their firm.
Customers who do not believe there are actions that
they can take may not respond to traditional
approaches promoting energy efficiency programs.
Project managers, program managers, and enerry
engineers understand the potential for cost-
effective improvements across industries. Data
from previous projects can be used to identi$ cost
savings and operational improvements from
common efficiency efforts in particular industries
in order to interest more eligible customers.
Increasing participation is important to ensure
continued Drosram success.
eBlasts" were added to the marketing stratery in
2013. eBlasts emailed to Rocky Mountain Power
business customers included the following:o February 2013 - eBlast on linear fluorescent
lighting upgrades. July 2013 - eBlast on reducing cooling costso October 2013 - eBlast on food service
equipment incentivesr November 2013 - eBlast on improving heating
system performance
In addition, the company newsletter, Enerry
Connections, is distributed quarterly via email and
includes articles on energy efficiency.
Recommendation 2: Closely track project status.
Closely tracking the status of projects should alert
the project and program managers when savings
goals may not be met by existing projects. The
Drosrarn staff could then determine altemative
Updated tracking and reporting system has been
implemented to more closely track projects and
provide automated follow up items on open
projects.
Evaluation Recommendations Rockv Mountain Power Action Plan
strategies to meeting savings goals. Depending on
the projects in the pipeline at the time, the approach
may be to seek out new participants, to encourage
project completion, or to encourage customers to
take action on measures identified in their EARs
that were not currently being addressed. Ensuring
that projects are completed as expected decreases
uncertainty and risk for projects where Rocky
Mountain Power has already invested time and
resources.
Recommendation 3: Clarify baseline conditions,
particularly for lighting projects. There were two
lighting projects in the Energy FinAnswer program
impact evaluation sample which did not include
any description of baseline equipment. Project files
simply stated that premium efficiency T8s were
being installed, and no calculations were provided.
Without information on any removed fixtures, or
baseline assumptions in the case of new
construction, it is not possible to accurately
determine how savings were calculated for the
projects.
Both of the identified project were new
construction projects as such an industry standard
or energy code baseline was applied , additional
documentation of baseline will be provided for
new construction projects to more readily identiff
baseline used for reported energy savings.
Recommendation 4: Include energy and demand
savings calculations in a spreadsheet format. By
providing this information in one consolidated
location, future evaluation efforts will be more
efficient and reduce the potential for comparing
verified savings to incorrect or outdated project
assumptions.
o Although each project properly documented the
reported energy and demand savings estimates, the
absence of savings calculations (particularly for
demand savings) reduces the transparency of
reported savings, along with the efficiency of
evaluation efforts. Providing both the input
assumptions and savings calculation methodologies
will ensure the comparability and accuracy of
reported and evaluated savings and will reduce
associated evaluation costs.
o Include the clearly identified final Energy
Savings table in project files for the evaluation. The
data should include both baseline and current
enerry and demand usage as well as savings
estimates. Utilizine consistent formats based on the
This recommendation has been reviewed and found
to be non-cost effective by the company, complete
files will be provided as a standard practice.
Additional summary reports will not be added for
third party evaluation purposes only.
Evaluation Recommendations Rockv Mountain Power Action Plan
FINAL numbers is important for all follow up
activities, and will provide decision makers the key
information needed to quickly assess the situation
and take appropriate action relative to the
inspections conducted. It is noted that the key
elements are included in the documentation for
each project, but it is often difficult to identify the
final set ofparameters used because the project
files capture multiple changes/revisions to the
application process.
ROCKY MOUNTAIN
POMIER
AOR |STON Of mOHOORP
Appendix 9
Idaho Low Income Weathenzation
The Income Criteria for Idaho is set at 150% of the Department of Health and Human Services
Poverty Guidelines, and is shown below.
150% of Poverty Guide lnes
iamily Size
Vlonthly
ncome
-imit
) Month
ncome Limi
I I ,436 $ 4,309
,939 s 5,817
12,442 $ 7,325
12,944 $ 8,833
13,447 $10,341
[3,950 $l1,849
14,452 $13,357
[4,955 $14,865
lach
\dditional
vlember
0503 $ I,508
These income levels were effective as of July 1,2013.
ROCKYMqJNTAIN
POiIER
AON'EEilOFNNOHCORP
Trade Ally's
Energy Efficiency Al I iance VROCKY MOInITAIN
\PowER
The fullowing is a list of contractors, distributors and other businesses participating in Rocky Mountain Power's Energy Efficiency Alliance
displayed in random order (unless sorted by the useo based on the search criteria selected. This listing is provided solely as a convenience
to our customers. Rocky Mountain Power does not wanant or guarantee the work performed by these participating vendors. You are solely
responsible for any contrac{ with a participating vendor and the pericrmance of any vendor you have chosen.
An asterisk (*) indicates Rocky Mountain Power Outstanding Contribution Award winning trade allies in 2006, 2007,2008, 2009, 2010, 2011
andlot 2012
Searc[ Criteria:
ldaho
Lighting
HVAC - unitary
HVAC - evaporative
Motors and VFDS
Conlrols
Building envelopeAppliancss
O,ffice EquipmentFood Service
Compressed Air
Farm and Dairy
lnigation
Other
-ANY_
Search Resulfs.' 92 - Date and Time: 0411/2014 10:28:50 AM
Selected State(s):
Speclaltles:
Businers Type:
Restaurant and Store EqulpmentCompany
230 West 700 South
Salt Lake City, UT
Phone: [phone]
Website: rescoslc.com
244 W 300 N
Suite 200,
Salt Lake City, UT
Phone:[phone]
Platt Electrlc Supplf
919 Pancfieri Street
ldaho Falls, lD
Phone: [phone]
Electrlcal Wholoeale Supply Co., lnc.
- BlacKoot
560 Jensen Grove Rd.
Blackfoot, lO
Phone: [phone]\ /ebsite: www.ewscoinc.com
Bateman*lall, !nc.
1405 Foote Drive
ldaho Falls, lD
Phone: [phone]'l
\Abbsite: www. bateman-hall.com
Preclslon.Paragon IP2]
23281 La Palma Ave
Yorba Linda, CA
Phone: [phone]
Website: www.p-2.com
Specialties
Appliances
Food Service
Specialties
Controls
Lighting
Motors and VFDS
Specialties
Other: Other Specialty
Specaalties
Lighting
Join Date Projects101'1512013 Completed
Business Type
Distributor
Business Type Join DateContractor 0211812014
Business Type
Manufacturer - Rep
Other: Manufacturer
Business Type
Distributor
D.W. Electric Specialties
4s65 E. Tsth N. Lighting
Rigby, lD
Phone: [phone]
Colvln EngineerlngAssociates, lnc. Specidties
Business Type
Confac'tor
HVAC - evaporative
HVAC - unitary
Other: Other Specialty
Business Type
Architect
Engineering Firm
9peclalties Business TypeLighting Distributor
Join Date Proiects05n1nfl1 Completed
1
Join Date Projects0412912013 Completed
Joln Date Projects0110112009 C,ompleted
Join Date Proiects09t22t20't2 Cofrpleted
null
Projects
Completed
Join Date Projects0A13nU3 Completed
O2Ol2 Rcly louffiln Pffi, . dlvl.lon d P.clflcap .d tsn of XtdAmdqn En.{!, Hotdlnga Cffilf,ny
Energy Efficiency Alliance ROCKY MOUNTAIN
FOTT'ER
Town & Country Electrlc, lnc.
1223 'l'lth Ave. North
Nampa, lD
Phone: [phone]
Website: town-and-country-electric. com
Electrlcal Wholesale Supply Co., lnc.
- Rexburg
899 Jetstream Dr.
Rexburg, lD
Phone: [phone]
Website: www.ewscoinc.com
Tlrrell's Electrlc, lnc.
770 E. Sunnyside Rd.
ldaho Falls, lD
Phone:[phone]
Wheeler Electrlc
469 West 16th St.
ldaho Falls, lD
Phone: [phone]
Website: wheelerelectric.com
RealWlnWn, lnc.
1926 Arch Street, 4F
Philadelphia, PA
Phone:[phone]
Website: www. realwinwin. com
Amerlcan Mechanlcal Sysytoms
Servlce, LLC
7530 South State Street
Midvale, UT
Phone: 80'l-428-0400
Website: www. ams-ut. com
HC Doslgn & Consultlng
P.O. Box 10545
Bozeman, MT
Phone: [phone]
Gase, Lowe & Hart, lnc.
2484 Washington Blvd.
Suite 510,
Ogden, UT
Phone: [phone]
Website: www. clhae. com
Lowls Corporatlon
15136 Hunziker
Pocatello, lD
Phone: [phone]
Website: lcorp.com
3M Company
3M Center Bldg 235-2S-27
St Paul, MN
Phone: [phone]
Website: www.3m.com/windo\,vfilm
Concolldated Electrlcal Dlstrlbutors'
- Logan, UT
636 N. 600 W.
Logan, UT
Phone: [phone]
Business Type Join DateContractor 0110112009
Business Type
Distributor
Projects
Completed
Join Date Projects0912212012 Completed
6
Specialties
Controls
Lighting
Motors and VFDs
Business Type
Contractor
Business Type
Contractor
Join Date
03/01/2009
Join Date
01to1t2007
Projects
Completed
1
Projects
Completed
5
Projects
Completed
Specialties
Appliances
Building envelope
Controls
Food Service
HVAC - evaporative
HVAC - unitary
Lighting
Motors and VFDs
Office Equipment
Specialties
Controls
HVAC - unitary
Motors and VFDs
Specialties
Food Service
Specialties
Building envelope
Compressed Air
Controls
HVAC - evaporative
HVAC - unitary
Lighting
Motors and VFDS
Specialties
HVAC - unitary
Specialties
Building envelope
Specialties
Farm and Dairy
lnigation
Lighting
Business Type Join Date
10114t2013
Other: Energy
Efficiency lncentive
Administration and
Consultation
Business Type
Contractor
Join Date Projects11t30t2012 Completed
Business Type
Manufacturer - Rep
Business Type
Architect
Engineering Firm
Business Type
Contractor
Business Type
Manufacturer - Rep
Business Type
Distributor
Join Date
07t01t2013
Join Date
05t17t20't3
Join Date
08/01/2008
Join Date
04t25t2013
Join Date
0312612005
Projects
Completed
Projects
Completed
Projects
Completed
Projects
Completed
Projects
Completed
42
O2O l2 Rocky tounbln PoFr, . dlvl.lon of P.cifiCon lnd p.d ot Iltu.d{n Energy Holdl.gt cmPrny
Energy Efficiency Alliance ROCKY MOI.INTAIN
POUVER
L&KMetcoElectric
P.O. Box 7964
Boise, lD
Phone: [phone]
Felt Lighting lnc.
1220 East 3300 South
Salt Lake City, UTPhone: 801.484-8571
Website: www.bltlighting.com
LEPCO (Leonard Petroleum
Equipment )
P.O. Box 170219
Boise, lD
Phone: [phone]
Codale Electrlc Supply - Gasper
3131 Wood Court
Casper, \MY
Phone: [phone]
Website: www. codale.com
Kaman lndustrial Technologies
525 S. Utah Circle
ldaho Falls, lD
Phone: [phone]'l'1
Website: kaman.com
YESCO LLC - Salt L.ke City, UT
1605 S. Gramercy Road
Salt Lake City, UT
Phone: [phone]
Website: www.yes@.@m
DesignTek Consulting Group, LLC
1600 w. 2200 s.
Salt Lake City, UT
Phone: [phone]
Website: www.designtekconsulting.com
Verismic Software lnc.
65 Enterprise
Aliso Viejo, CA
Phone:[phone]
Website: www.verismic.com
PVE, lnc
1040 North 2200 West, Suite 100
Salt Lake City, UTPhone: 801 -359-31 58
TreoFrog LED, lnc.
7594 North Swansea Court
Eagle Mountain, UTPhone: 801-372-8720
Website: www.treefrogled. com
Cooper Llghtlng
1121 Highway 74 South
Peachtree, GA
Phone: [phone]
Website: www. cooperlighti ng.com
Johnson Controls, lnc.
2255 Technology Parl$ay
WestValley City, UTPhone: 801-946-4059
Specialties
Lighting
Specialties
Controls
Lighting
Specialties
Lighting
Specialties
Motors and VFDs
Specialties
Controls
Lighting
Specialties
Controls
HVAC - evaporative
HVAC - unitary
Motors and VFDS
Join Date Projects10t01t2011 GompletedI
Join Date Projects1'112712013 Completed,|
Business Type
Contractor
Business Type
Distributor
Business Type
Contractor
Business Type
Distributor
Business Type
Distributor
Join Date
09n4t2012
Projects
Completed
1
Join Date Projects0612712013 Completed
Join Date Projects09/01/2006 Completed
Specialties
Appliances
Controls
Lighting
Motors and VFDS
Specialties
Compressed Air
Controls
HVAC - evaporative
HVAC - unitary
Motors and VFDs
Specialties
Offce Equipment
Other: Other Specialty
Specialties
Controls
HVAC - evaporative
HVAC - unitary
Lighting
Motors and VFDS
Specialties
Lighting
Business Type Join Date ProjectsConfactor 0912212012 CompletedManuhcturer - Rep 40
Business Type Join Date ProiectsContractor 1111112013 CompletedEngineering Firm
Business Type
Confactor
Distributor
Manufacturer - Rep
Other
Business Type
Engineering Firm
Business Type
Distributor
Business Type
Manuhcturer - Rep
Business Type
Contractor
Manufucturer - Rep
Join Date
0'U16t2013
Join Date
07129t2013
Join Date
07t29t20't3
Join Date
12,13t2012
Join Date06n1n007
Projects
Completed
Projects
Completed
Projects
Completed
Projects
Completed
Projects
Completed
@2012 Rocly mounbln Pomr, . dlvblon o, P.cltlcorp .nd p.d of tiilm.den Enrly Holdlng. Compeny
Energy Efficiency Alliance ROCKY MOUNTAIN
POWER
Electrical Wholesale Supply Go., lnc.
- Home Lightlng
650 W Sunnyside Rd.
ldaho Falls, lD
Phone: [phone]
Website: www.ewserinc.@m
DlVl Energy, LLC
68 S Main St., Ste 800
Salt Lake City, UT
Phone:[phone]
Bradley Engineerlng
382 Walnut Street
ldaho Falls, lD
Phone: [phone]
Website: www. bradleyengineering.com
West€rn Heatlng & Flreplaces
4980 W. Bradley Street
Boise, lD
Phone: 208-680-'1296
Allred's lncorporated
1410 Gibson Avenue
Ogden, UT
Phone: [phone]
Website: www.allreds. net
Alloway Commercial Llghtlng
1420 Grove Street
Boise, lD
Phone: [phone]
Website: www. allowaylighting.com
Valley lmplement
213 West 8th North
Preston, lD
Phone: [phone]
Website: valley-implement.com
Lennoxt
I 008 w 2780 S
Salt Lake City, UT
Phone:[phone]
Website: lennoxcommercial.com
ePlusGreen lnc.
7951 SW6th Street, Fort Lauderdale
FL33324
Suite 208,
Ft Lauderdale, FL
Phone: [phone]
Website:
http:/,vww.eplusgreen.convpro/index. ht
ml
APC Salee and Servlce Corp.
132 Fairgrounds Road
West Kingston, Rl
Phone:[phone]'l
Website: www.schneider-eleclric.com
GenPro Energy Solutlons LLC
13261 Timberline Plaza
Suite B,
Piedmond, SD
Phone: [phone]
Join Date Projects09t22t2012 Completed
null
Join Date Projects
0112312013 Completed
18
Join Date Projects09t22t2012 Gompleted
7
Join Date Projects09/01/2008 Completed
Specialties
Controls
Lighting
Motors and VFDs
SpecialtiesControls
lrrigation
Motors and VFDS
Specialties
HVAC - unitary
Business Type
Distributor
Business Type
Manufacturer - Rep
Other
Business Type
Engineering Firm
Business Type
Contractor
Business Type Join DateDistributor 0511112011
Business Type
Distributor
Business Type
Contractor
Business Type
Distributor
Join Date
09t26t2012
Join Date
o1t10t2013
Join Date
03101t2012
Join Date
07t29t2013
Projects
Gompleted
Projects
Gompleted
1
Projects
Completed
Projects
Completed
Proiects
Completed
Join Date Projects12105t2012 Completed
null
Join Date Projects1'110'112005 Completed
Specialties
Office Equipment
Other: Other Specialty
Specialties
Lighting
Business Type
Contractor
Distributor
Engineering Firm
Other
Business Type
Other
Business Type
Distributor
Manufacturer - Rep
Specialties
Controls
Farm and Dairy
lrrigation
Lighting
@2012 Rdky MounEin Pmr, a divicion d P.clflcorp .nd pid ot Mlffm.dc.n En.Oy Holdlng. C6np.ny
Energy Efficiency Al ! iance ROCKY MOTJNTAIN
FOWER
Northom Llghts Electrlc LLG*
3473 E.20th N. UnitA
ldaho Falls, lD
Phone: [phone]
Harrls Alrcraft, lnc.'DBA Harris
Llghtlng Products
1405 W. 800 N.
Preston, lD
Phone: [phone]
Thurgood llechanlcal Servica, lnc.
4245 E. 653 N
Rigby, lD
Phone: [phone]
Hon6!twell lntematlonal
2371 S. Presidents Way Suite A
Salt Lake City, UT
Phone: [phone]
Website: honeywell. com
Energy llanagemont Corporatlon'
501 West 700 South
Salt take City, UT
Phone: [phone]
Website: emcsolutions.com
Eco Safe Llghting
4600 NW Camas Meadows Drive,
Suite 210
Camas, WA
Phone: [phone]
Website: http:/
^,ww.
est-
lights.com/aboutus/
Norbryhn Equlpmsnt Company
3711 E. Newby St.
Nampa, lD
Phone: [phone]
ttrrebsite: norbryhn.com
JRW & Associates, PLLC
1 152 Bond Ave
Rexburg, lD
Phone: [phone]
Valley lmplement
2570 N Main
Logan, UT
Phone: [phone]
lA/ebsite: valley-implement.com
1355 FremontAve
ldaho Falls, lD
Phone: [phone]
lAlebsite: www.ews@inc.@m
qatest
2324 amy street
fostercity, CA
Phone: [phone]M x 3434
Busineas Type Join DateContractor 0410112009
Total Energy Electrlcal/FullSpectrum Servlces
'121 E. 38th, #106
Boise, lD
Phone:[phone]\ bbsite: www.fu llspecservices.com
Ehcfical Wholesale Supply Co., Inc. Spocialties- Corporate Cirntols
Specialties
Controls
HVAC - unitary
Motors and VFDs
Specialties
Controls
HVAC - evaporative
HVAC - unitary
Motors and VFDs
Specialtles
HVAC - unitary
Motors and VFDS
Business Type
Distributor
Manufacturer - Rep
Business Type
Contactor
Manufacturer - Rep
Business Type
Contractor
Distributor
Manufacturer - Rep
Buslness Type
Distributor
Join Date
0410112007
Joln Date
06t0'u2007
Join Date
05/01/2006
Join Date
05t01t20M
Join Date
02t11t2013
Join Dateo't01t2012
Join Date
't0t2'U2013
Join Date
12,0512012
Join Date
10t11t20't2
Joln Date09mno12
Join Date
04loz2013
ProJects
CompletedI
Projects
Completed
22
Projects
Completed
Projects
Gompleted
Projects
Completed
Projects
Completed
Projects
Gompleted
Projects
Completed
ProJects
Completed
null
Projects
Completed
null
ProJects
Completed
null
Projects
Completed
22
Specialties
HVAC - unitarv
Motors and VFDs
Specialties
Building envelope
Specialties
Conhols
Farm and Dairy
lnigation
Motors and VFDs
Specialties
Lighting
Lighting
Motors and VFDS
Specialties
Appliances
Business Type
Distributor
Business Type
Distributor
Business Type
Architect
Business Type
Contractor
Business Type
Contractor
Business Type
Distsibutor
Business Type
Architect
Energy Efficiency Al I iance VROCKY Mq,JNTAIN
XPou,ER
Coolerado Corporatlon
4700 W 60th Ave., Ste. 3
Arvada, CO
Phone: [phone]
Website: coolerado.com
Maintenance Englneering, Ltd.
P.O. Box2123
Fargo, ND
Phone: [phone]
Website: www. me-dtc. com
Compressor - Pump & Servlce, lnc.
3333 W. 2400 S.
Salt Lake City, UT
Phone: [phone]
Website: www.compressor-pump.com
LilS - Lightlng Ualntenanco Service*
663 West 4330 South
Salt Lake City, UT
Phone: [phone]
Website: lmslighting.com
Wes LED Technologles, LLC.
1181'l North Freeway, Suite 181
Houston, TX
Phone: [phone]
Website: www.wesled.com
Midgley-Huber, lnc.'
2465 Progress Drive
Salt Lake City, UT
Phone: [phone]
Website: Migley-huber.com
Real Green LED
4280 W.200 N.
Cedar City, UT
Phone: [phone]
Website: www. realgreen.net
Petroleum Equlpment Co
1 174 So. 300 W
Salt Lake City, UT
Phone: [phone]
Website: www. petro-equip.net
Network Consuttlng Sorvlces, lnc.
563 West 500 South
Suite 245,
Bountitul, UT
Phone: [phone]
Website: http:/Alww. ncsi. us
Royal Wholesalo Eloctrlc - Logan
917 W600 N Ste 101
Logan, UT
Phone. [phone]
Website: royalutah.com
Aspen Engineering and
Envlronmental LLC
'140 Aspen Circle
Park City, UT
Phone: 435-565-'1 535
Website: www. a2e.llc. com
Specialties
HVAC - evaporative
HVAC - unitary
Specialties
Lighting
Specialties
Compressed Air
Business Type
Distributor
Manufacturer - Rep
Business Type
Other: Manufucturer
Business Type
Distributor
Join Date
03t01t2007
Join Date't0t05t2012
Join Date
10t21t2013
Join Date
10t0212002
Join Date07n1nu1
Join Date
05101t2007
Join Date
09t0'U2012
Join Date
10t03t20'13
Join Dateo4t29t20't3
Join Date
0't/09/2008
Join Date$n8nu3
Projects
Completed
Projects
Completed
null
Projects
Completed
Projects
Completed
396
Projects
Completed
Projects
Completed
Projects
Completed
Projects
Completed
Projects
Completed
Projects
Completed
12
Projects
Completed
Specialties
Controls
Lighting
Motors and VFDS
Specialties
Lighting
Business Type
Contractor
Business Type
Distributor
Specialties
HVAC - evaporative
HVAC - unitary
Specialties
Lighting
Business Type
Manufacturer - Rep
Business Type
Distributor
Specialties
Lighting
Specialties
Office Equipment
Specialties
Lighting
Business Type
Distributor
Business TypeArciitect
Contractor
Engineering Firm
Manufacturer - Rep
Business Type
Distributor
Specialties Business TypeBuildingenvelope EngineeringFirm
Controls
HVAC - evaporative
HVAC - unitary
Motors and VFDS
@20'12 Rocky tounhln Po6., . dlvlalon of P.cffiCorp .nd Fd of tltudon En.r!, Holdlngt ComP.ny
Energy Efficiency Alliance VzROCKY MOLNTAhI
\Forffi
Van Boerum & Frank Assoclates
330 South 300 East
Salt Lake City, UT
Phone: [phone]
Website: www.vbfa.com
Englneerlng Economaca, lnc.
780 Simms Street Suite 210
Golden, CO
Phone: [phone]
Consolldated Electrical Dlstrlbutoru'
- ldaho Falls
865 Pancheri
ldaho Falls, lD
Phonei 208-523-2022
HanitaTek Wndow Fllm
4010 La Reunion Phry, #100
Dallas, TX
Phone: 80066G5559
\Alebsite: www. HanitaTek.com
ESL Vislon LLG
P.O. Box 58565
Salt Lake City, UT
Phone: [phone]
Website: www.eslvision.com
Englneered Systems Acaoc., lnc.
1355 E. Center Street
Pocatello, lD
Phone: [phone]'l
Electrical Wholesale Supply Co., lnc.
- Pocatello
220 West Maple
Pocatello, lD
Phone: [phone]
Website: www.ewscoinc.com
Elecirlcal Wholesale Supply Co., !nc.
- ldaho Falb
3140 McNeil Dr.ldaho Falls, lD
Phone: [phone]
\A/Ebsite: www.ews@inc. com
Skyvlew Electrlc lnc
2299 WOmni Dr
ldaho Falls, lD
Phone: [phone]
Allred'c lncorporated
642 North 1000 West Unit # 104
Logan, UT
Phone: [phone]
\A/ebsite: www. allreds. net
Electrical Wholesale Supply Co., lnc.
- Drlggs
83C Rocky Road lnd Lp.
Driggs, lD
Phone:[phone]
Website: www.ewscoinc.@m
Specialties
Building envelope
Controls
HVAC - evaporative
HVAC - unitary
Lighting
Motors and VFDs
Speclaltles
Building envelope
Controls
HVAC - evaporative
HVAC - unitary
Specialties
Lighting
Specialties
Building envelope
Business Type
Distributor
Manufacturer - Rep
Specialties
Controls
Lighting
Specialties
Controls
I-IVAC - evaporative
I-IVAC - unitary
Motors and VFDs
Specialties
Controls
Lighting
Motors and VFDs
Specialties
Lighting
Business Type Join DateDistributor 0111312013
Manufacturer - Rep
Specialties
Lighting
Speclaltles
HVAC - unitary
Specialties
Controls
Lighting
Motors and VFDs
Business Type
Contractor
Business Type
Distributor
Business Type
Distributor
Business Type Join Date
Engineering Firm 0U10nU4
Business Type
Architect
Engineering Firm
Other
Business Type
Engineering Firm
Business Type
Distributor
Join Date
0'U0'U2012
Join Dateu/20r2u4
Join Date
09t2412012
Join Date
091o912013
Join Date
09122t2012
Join Date09mnu2
Join Date
02t01t2009
Joln Date
05t't1t2011
Join Date
09122t2012
ProjecG
Completed
Projects
Completed
Projects
Completed
8
Projects
Gompleted
Projects
Completed
Projects
Completed
Projects
Completed
null
Projects
Gompleted
13
Projects
Gompleted
ProJects
Gompleted
Projects
Completed
7
Business Type
Distributor
Business Type
Disbibutor
@Ol2 Rely lounbh Pffi, . dM.bn d P.ctrlcorp .nd Fail ot lldAmdon En.liy Holdlngtr Cmilny
Energy Efficiency AIIiance JzROCKY MOt NTAIN
xPor{ER
ilountaln West Xlechanical
2336 W. 5200 S.
Rexburg, lD
Phone: [phone]
Website:
ww\,v. mountai nwestmechan ical. com
Utah Yamas Controls lnc.
13526S.110W
Draper, UT
Phone: 801 -990-'l 950
Website: www. utahyamas.com
All American Lighting lnc.
P.O. Box 2996
ldaho Falls, lD
Phone:[phone]
Gustavs A. Lamon Company
'1395 Northgate Mile
ldaho Falls, lD
Phone:[phone]
Website: galarson.com
Electrica! Equlpment Company
540 W. 20th St.
ldaho Falls, lDPhone:208-522-4732
Website: electricalequipment.com
HD Supply Facilities ltlaintenance,
Ltd.
10641 Scripps Summit Court
San Diego, CA
Phone: [phone]
Website: www. hdsupplysolutions.com
Larsen Etec'tric, LLC
P.O. Box 2871
Pocatello, lD
Phone: [phone]
Clark's Quality Roofing, lnc.
334 W. Anderson Avenue
Salt Lake City, UT
Phone: [phone]
Website: clarkroof.com
Pete's Llghtlng
227 S. Johnson Ave.
Pocatello, lD
Phone:[phone]
Energy lndustries
425 W. Pueblo St.
Boise, lD
Phone: [phone]'13
Website: energy-industries.com
Slka Sarnafll lncorporated
2881 South 900 West
Salt Lake City, UT
Phone: [phone]
Website: usa.sarnafi l.sika.com
Trane*
2817 S. 1030 W
Salt Lake City, UT
Phone: [phone]
Website: www.trane-com
Specialties
Building envelope
Controls
HVAC - evaporative
HVAC - unitary
Lighting
Motors and VFDs
Other: Other Specialty
Specialties
Lighting
Specialties
HVAC - unitary
Motors and VFDs
Specialties
Lighting
Other: Other Specialty
Specialties
Appliances
HVAC - evaporative
HVAC - unitary
Specialties
Lighting
Specialties
Building envelope
Specialties
Lighting
Specialties
Lighting
Specialties
Building envelope
Specialties
Controls
HVAC - unitary
Motors and VFDs
Business Type
Contractor
Distributor
Engineering Firm
Manufacturer - Rep
Business Type
Distributor
Business Type
Distributor
Business Type
Contractor
Business Type
Distributor
Business Type
Contractor
Business Type
Contractor
Business Type
Distributor
Business Type
Other
Business Type
Contractor
Business Type
Distributor
Manufacturer - Rep
Join Date Projects09/0'l/2008 Completed
Projects
Completed
Join Date
o1t2112013
Join Date
03t01t2010
Join Date
01t01t20't2
Join Date
01122t2014
Join Date
09122t2012
Join Date
09t19t2012
Join Date
09i01nuo
Join Date
05/30/2006
Join Date
11tO1t2011
Join Date
03t01t2005
Projects
Completed
ProjecG
Completed,|
Projects
Completed
1
Projects
Completed
Projects
Completed
1
Projects
Completed
null
Projects
Gompleted
1
Projects
Completed
2
Projects
Completed
Projects
Completed
Specialties Business Type Join DateHVAC - evaporative Contractor 0311712014
HVAC - unitary
@2012 R@ky tounbln Potr., . dlvl.lon ol P.cfrCorp .hd p.il ol llilmden En.,!y Holdlnga Cffip.ny
Energy Efficiency Alliance vRocKY Mott$rAlit
\POT'ER
tcKlnstry Ellendon, LLC
112 N. Rubey Dr.
Suite 200,
Golden, CO
Phone: [phone]
\Alebsite: www. mckinsfry.com
Gr6en Crratlve LLC
533 Airport Blvd., Suite 212
Burlingame, CA
Phone: [phone]
Website: www. gc.lighti ng.com
LED lndustrlec lnc
3001 N. US Highway 12
Spring Grove, lL
Phone: 80'l-801-5959
D&S Electrlcal
363 West Chubbuck Road
Chubbuck, lDPhone: 208-731-3701
Hartls liechanlcal lntermountaln
1925 South Milestone Drive
Suite E,
Salt Lake City, UT
Phone: [phone]
lAbbsite: www.hm@.com
Specialtles
Building envelope
Compressed Air
Controls
HVAC - evaporative
HVAC - unitary
lnigation
Lighting
Motors and VFDs
Other Other Specialty
Specialties
Lighting
Specialtles
Lighting
Specialties
Lighting
Motors and VFDs
Specialties
HVAC - evaporative
I-IVAC - unitary
Business Type
Manufacturer - Rep
Buslness Type
Manufacturer - Rep
Business Type
Distributor
Businesa Type
Conbactor
Buslness Type Joln Date
Engineering Firm 0211?J,2014
Projec{s
Completed
Join Date
06t2512013
Join Date12t$r2U3
Join Date\ZUn008
Joln Date
01D7Do',t4
Projects
Completed
Prolects
Gompleted
Projects
Completed
36
ProJects
Completed
02012 iety loufiln Pffi, . dlybbn ot P.clf,Cdp and pd of f,ftl^mrlen En.O, Holdrgs Cmp.ny