20170727Tatum Direct.pdf

BEEORE THE IDAHO PUBLIC UTILITTES COMMISSION
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CASE NO. IPC-E-17_13
IN THE MATTER OF IDAHO POWER
COMPANY' S APPLICATION FOR
AUTHORITY TO ESTABLISH NEW
SCHEDULES FOR RESTDENTIAL AND
SMALL GENERAL SERVICE CUSTOMERS
WITH ON-STTE GENERATION
IDAHO POWER COMPANY
DIRECT TESTIMONY
OE'
TIMOTHY E. TATUM
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O. Please state your name, business address, and
present position with Idaho Power Company ("Idaho Power" or
"Company").
A. My name is Ti-mothy E. Tatum. My business
address is I22l West Idaho Street, Boise, Idaho 83702. I
am employed by Idaho Power as the Vice President of
Regulatory Affairs in the Regulatory Affairs Department.
O. Please describe your educational background.
A. I earned a Bachelor of Business Administration
degree in Economics and a Master of Business Administration
degree from Boise State University. I have also attended
electric utility ratemaking courses, includj-ng "Practical
SkilIs for The Changing Electrical Industry, " a course
offered through New Mexico State University's Center for
Public Utilities, "Introduction to Rate Design and Cost of
Service Concepts and Techniques" presented by El-ectric
Utilities Consul-tants, Inc., and Edison Electric
Institute's "Electri-c Rates Advanced Course." In 20L2, T
attended the Utility Executj-ve Course (UEC) at the
Universlty of Idaho, and subsequently became a member of
the UEC faculty in 2075.
O. Please describe your work experi-ence with
Idaho Power.
A. I began my employment wlth Idaho Power in 1996
in the Company's Customer Servlce Center where I handled
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1 customer phone caIls and other customer-rel-ated
2 transactions. In 1-999, T began working in the Customer
3 Account Management Center where I was responsibJ-e for
4 customer account maintenance in the areas of billing and
5 metering.
6 In June of 2003, I began working as an Economic
7 Analyst on the Energy Efficiency Team. As an Economic
8 Analyst, I was responsible for ensuring that the demand-
9 side management ("DSM") expenses were accounted for
10 properly, preparing and reporting DSM program costs and
11 activities to management and various external stakeholders,
1,2 conducting cost-benefit analyses of DSM programs, and
13 providing DSM analysi-s support for the Company's Integrated
1,4 Resource P1an.
15 In August of 2004, T accepted a position as a
76 Regulatory Analyst in the Regulatory Affairs Department.
l7 As a Regulatory Analyst, I provided support for the
18 Company's various regulatory activities, incJ-uding tarlff
19 administratj-on, regulatory ratemaking and compJ-iance
20 filings, and the development of various pricing strategies
2L and policies.
22 In August of 2006, I was promoted to Senior
23 Regulatory Analyst. As a Senior Regulatory Analyst, my
24 responsibilities expanded to include the development of
25 complex financial studies to determine revenue recovery and
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Idaho Power Company
1 pricing strategj-es, including the preparation of the
2 Company's cost-of-service studies.
3 In September of 2008, I was promoted to Manager of
4 Cost of Service and, in April of 2071, T was promoted to
5 Senior Manager of Cost of Service and oversaw the Company's
6 cost-of-service activities, such as power supply modeling,
7 )urisdictional separatj-on studies, class cost-of-service
8 studies, and marginal cost studies. In March 2076, I was
9 promoted to Vice President of Regulatory Affairs. As Vice
10 President of Regulatory Affairs, I am responsible for the
1l- overall coordination and direction of the Regulatory
72 Affairs Department, including development of jurj-sdictional
13 revenue requirements and cl-ass cost-of-service studies,
74 preparation of rate design analyses, and administratj-on of
15 tariffs and customer contracts.
1,6 O. What is the scope of this docket?
L1 A. With this case, the Company intends to inform
18 the Idaho Public Utilities Commission ("Commission") that
I9 offering has matured to a point
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its net metering service
where certain aspects of
review and modification.
offering warrant
the information Idaho
Company wil-l- request
customers
the service
22 Power will- present in this
23 that the Commission initiate certain near-term steps to
24 transition from current net metering practices to an
In light of
case, the
25 eventual pricing and compensation structure for
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1 with on-site generation that is both fair and sustainabl-e
2 ::ri-o the future. In support of this eventual transition,
3 the Company wiII also recommend the Commission establish a
4 formal process by which a comprehensive review of the
5 compensation structure for customers with on-site
6 generation can be analyzed and vetted collaboratively with
7 j.nterested parties
I Q. What aspects of the current net metering
9 service does Idaho Power believe warrant review and
10 modification?
11 A. Idaho Power is required to maintain a network
72 of interconnected power plants, transmission poles/wires,
13 substations, and distribution poles/wires to balance the
t4 supply of and demand for el-ectricity in its service area.
15 This complex system of infrastructure, people, and
L6 integrated systems is sometimes referred to as our "power
L1 grid" or "the grid. " Existing retail rate designs
18 currently applicable to residential and smal-1 general
19 service (*R&SGS") net metering customers were structured to
20 collect the costs associated with the grid under the
2l assumption that customers woul-d only need one-way services
22 provided soleJ-y by the utility. Whil-e this pricing
23 structure does not perfectly align costs incurred with
24 prices paid for each individual customer, overall this rate
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1 structure has worked for R&SGS customers who receive one-
2 way services from ldaho Power.
3 However, this pricing structure does not work Eor
4 customers with on-site generation who require some services
5 from Idaho Power (use of the grid and some of their
6 energy), but who also meet some of their own energy needs
7 with an on-site generation system (e.9., rooftop solar).
8 Many within this growing customer segment use the grid
9 every hour of the month, but when the existing rate
10 structure is applied against monthly net consumption,
11 customers with on-site generation may pay l-ess than their
72 fair share for the grid-related services they require whil-e
13 receiving credit for their respective kilowatt-hours
14 (*kwh") of production at the full retail rate energy rates;
15 rates reflective of the cost of utility-provided energy and
16 grid services and not the benefits and costs associated
L7 with customer-owned energy productJ-on. The existing R&SGS
18 rate design does not reflect the costs and benefits of the
L9 transaction between Idaho Power and its customers with on-
20 site generation.
27 O. Why is Idaho Power proposing the Commission
22 review and consider modifylng net metering service
23 practices at this time?
24 A. Net metering is
was implemented in 1983 when
a non-cost based policy that
residential- rate designs were
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Iimited by meters that could only track 1nf1ow and outflow,
and distributed energy resources ("DER") were an expensive
and nascent technology. The circumstances that existed
when net metering policies and practices were originally
established have changed dramatically across the nation,
and more specifically, in Idaho Power's service area.
First, Idaho Power has deployed Advanced Metering
fnfrastructure (AMI) in its service area, enabling the
Company to achieve more precise usage measurement and
facil-itate more sophisticated, cost-based rate designs.
SecondJ-y, the cost of sol-ar photovoltaic (*PV") has
contj-nued to decline resulting in increased adoption.
Thirdly, and arguably most importantly, the Company
believes its net metering service has reached a pivotal
point; that is, Idaho Power has witnessed rapid growth in
its net metering service in recent years and has identified
a quantifiabl-e cost shift occurring between its residential
net metering customers and residential standard service
customers. Considering recent growth, the Company bel-ieves
it can reasonably predict that future cost shifting between
these customer groups will j-ncrease substantially in the
next few years if left unaddressed.
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Incentj-vizing net
needed and resul-ts
metering through
in inappropriate
rate design is no
cost shifting.
must position the
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Company to meet changing customer preferences and offer
services that are
going forward as
and lmprove. For
the time has come
toward establishing rate
structures for customers
fair and sustainable into
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this fiJ-ing?
A.
with on-slte qeneration
establishment of two new
fair and sustainable for al-l- customers
sol-ar panel technology continues to evol-ve
reasons described later in my testimony,
gradual, yet meaningful, steps
designs and compensation
with on-site generation that are
the future.
to take
What specifically is the Company requesting in
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The Company is requesting that the Commission
12 issue an order authorizing the following: (1) closure of
13 Schedule 84, Customer Energy Production Net Metering,
R&SGS customers14 ("Schedule 84") to new service for Idaho
15 after December 31, 2011 , (2)
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cl-assifications of customers
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applicable
request to
to R&SGS customers with on-site generation that
interconnect to Idaho Power's system on or after
January l, 20L8, with no pricing changes at this time, (3)
acknowledgement that smart inverters provide functionali-ty
that is necessary to support the ongoing stabil-ity and
reliability of the distribution system by ordering the
Company to amend its appJ-icable tariff schedul-es to require
the instal-l-atj-on and operation of smart inverters for all
new customer-owned generator interconnections within 60
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days fol-l-owing the adoption of an industry standard
definition of smart inverters as defined by the Institute
of El-ectrical and Electronic Engineers (*IEEE"), (4)
conrmencement of a generic docket at the conclusi-on of this
case with the purpose of establ-ishing a compensation
structure for customer-owned DERs that reflects both the
benefits and costs that DER interconnecti-on brings to the
electric system.
O. Is the Company
10 the customers that woul-d be
suggesting pricing changes for
placed in the newly established
No, not at this time. At this time, the
requesting authority to implement two new tariff
Schedule 6, Residential Service On-Site
("Schedul-e 6") and Schedule 8, Smal1 General
15 Service On-Site Generation,
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classes ?
A.
Company is
schedules,
Generation,
Residential- Service, and
respectively. Under this
Schedule 6 and Schedu]e 8
proposal, the rates under
would continue to mirror the
to serve new
The newly
initially
to Schedule 7,
General Service,
based
L] R&SGS customers with on-si-te
("Schedule 8")
generation.
18 established Schedule 6 and Schedule 8 would
19 contain rates that mi-rror those appllcable
Schedule l, Small
23 rates contained in Schedule I and Schedule 7 until the
24 Commission determines the proper rate design and/or
and Schedule I
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upon appropriate cost of service studies and other
applicable generation valuation studies.
O. How is the Company's case organized?
A. My testimony will- begin with an overview of
how the continued evolution of customer preferences and
technological advances require that Idaho Power evaluate
and modify the servj-ces it provJ-des to customers. I will
then discuss the cost shifting that exj-sts with current net
metering practices, the need for establishing separate
customer classes, and important considerations related to
existing net metering customers.
Company witness Connie Aschenbrenner wil-l- review the
history of the
an overview of
Company's net metering service and provide
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the associated cases brought
. Aschenbrenner will provide
before the
an update on
and wil-lt6
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net metering participation and growth
discuss the Company's ef forts rel-ated
rates,
to customer and
1B stakeholder engagement prior to
1,9 1n this case. Ms. Aschenbrenner
the Company's
will discuss
application
the Company's
R&SGS20
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request to
customers
new tariff
establish new customer classes for
23 wil-l discuss the Company's efforts related to customer
24 communication of this filing.
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with on-site generation and the implementation of
Schedul-es 5 and 8. Lastly, Ms. Aschenbrenner
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and how the Company's
distribution system. He will
generation util-ize the
then address the questi-on of
DER contribute to the deferralwhether increasing l-evel-s of
of future investment in distri-bution infrastructure.
Lastly, Mr. Angell will present the benefits provided by
smart inverters and explaj-n the Company's request relative
to a smart inverter requirement for customers who
interconnect on-site generati-on to Idaho Power's system.
I. EVOLVTNG CUSTOMER PREFERENCES AIID TECTINOLOGICAI. AD\IA}ICES
o.Has the Company experienced a change in
r with regard to how they take13 customer needs and preferences
L4 service?
15 A. Yes. As technology has evolved, so have
customer preferences and expectations with regard to where
and how their energy 1s produced. Innovation, particularly
advances in sol-ar PV technology and personal views on solar
power, has resul-ted in larger numbers of customers choosing
to install on-site generation.
O. General-Iy, what types of solar PV innovation
has the utility industry witnessed?
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23 A Advances in solar energy, specifically
technology, have 1ed to24 discoveries in the solar panel
Company
explanation of
R&SGS customers
witness Dave Ange11
the electrical grid
with on-site
will provide an
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An articl-e written
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20L1 by EnergySage, attached as Exhibit No. 7, stated that:
"A number of achi-evements by various panel
current recordhave brought us to today's
manufacturers
for sol-ar panel
claimsefficiency:
that, "The
could also
23.5 percent . ."
solar ceII types used
The article also
in mainstream markets
metric that compares
improvements in cost per watt a
rel-ative affordabitity of solar
panels." These reductions in cost have led to growth in
the development of non-utility-owned power. fn fact, ofl
May 10, 2017, USA Today reported that Tesla, best known for
its electric cars, "wi11 begin selling and installing sol-ar
roof tiles for U.S. customers this summer." The article,
attached as Exhibit No. 2, went on to explain that "g1ass
solar roof tiles with embedded solar col-l-ectors" woul-d be
of
see major
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15 "more durabl-e than a typical roof, a third lighter and
L6 cheaper when electricity savings and tax credj-ts are
l7 included. " Developments in power technology in the form
18 on-site or self-generation are becomJ-ng more readily
19 available, affordable, and attractive to customers.
20 O. What type of growth rate has the solar
27 industry witnessed?
22 A. The So1ar Bnergy Industries Association
23 ("SEIA") reports that the solar industry j-s growing at a
24 record pace. In the article attached as Exhibit No. 3,
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SEIA claims that: "In the last decade, solar has
experienced an average annual growth rate of 682."
O. Has Idaho Power experienced growth in 1ts net
metering service conrmensurate with the growth experienced
across the industry?
A. Yes. As more fulJ-y described in Ms.
Aschenbrenner's testimony, the Company has seen similar
growth in its net metering service, most notably in the
last few years. Idaho Power j-nterconnected j-ts f irst
residential customer-owned sol-ar PV system in 1983, and
this remained the only residential customer with self-
generati-on for almost 20 years. fn 2002, the net metering
service was expanded to accommodate two additional requests
for servj-ce. As of the end of June 2011, Idaho Power has
L,287 net metering systems in Idaho taking service under
Schedule 84 and has received 181 applications from
11 customers who intend to i-nstall a system and take service
an artj-cIe pubJ-ished on
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18 under Schedule 84.
79 2017, by the Press, a weekly newspaper
Idaho solar market is
attached as Exhibit No. 4
According
Meridian
to
May 5,
serving Meridi-an f daho: "The
2l exploding." Thls article is
22 II. IIET METERIIIG COST SHTFT
23 O Please describe what is meant by the term
24 "cost shift" i-n the context of this case.
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A. Currently, the Company's R&SGS customers are
billed two types of charges: (1) a flat monthly service
charge of $5.00 and (2) per kWh energy charges that vary by
season and total- monthly consumption. Due to the limited
billing
most of
through the
associated
from investment
volumetric energy
with all components
in generation
requirement is col-l-ected
rates. This includes costs
of the electrical system,
resources to the meters
components associated with these rates classes,
the Company's revenue
10 instal-Ied on customers' premises. Consequently, energy
11 rates for R&SGS customers refl-ect not only the energy-
72 related components of the revenue requirement, but fixed
13 costs associated with generation, transmlssion, and
L4 distribution as wel-l-.
15 For this type of rate design, recovery of fixed
76 costs from an individua] customer declines with any
1,7 reductj-on in net energy usage. This creates a potential
18 inequity between net metering customers and standard
L9 service customers as net metering customers, who stil-I rely
20 heavily upon the grid to both purchase power and transfer
2t excess generation, are provided the opportunity to unduly
22 reduce col-l-ection of class revenue requirement by reducing
23 a portion or even all of their net kWh usage while other
24 residential- customers are left to compensate for the fixed
25 costs that transfer to them through this revenue shortfall-.
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o.
cost shifting
that collects
How does the industry perceive the concept of
caused by net metering under a rate design
the majority of fixed costs through a
volumetric rate?
A. Cost shifting is generally accepted and
regulators nationwide have attempted to address it. In
November 20L6, the National Association of Regulatory
Utility Commissioners (*NARUC") Staff Subcommittee on Rate
Design lssued the Distributed Energy Resources Rate Design
and Compensation manual ('NARUC Manual"). The NARUC Manual
states "DER customers who supply most, if not all, of their
own needs annually, but not necessarlly daiIy, may be
undercompensating the utility under certain [Net Energy
Meteringl rate designs for the generation, transmlssion,
and distribution investments that were made on behal-f of
the customer. "1
Others in the industry have concluded that the net
metering policy is also regressive j-n nature. An October
2016 Public Utilities Fortnightly article, "Rethinking
Ratj-onale for Net Metering, Quantifying Subsidy from Non-
Solar to Solar Customers" (attached as Exhibj-t No. 5)
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23 regressive wealth transfer from l-ower-income customers to
1 NARUC Manual, P. 89. http: / /pubs.naruc.orq/pub/19FDE48B-AA57-
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higher-income customers." Idaho Power shares this concern.
The Company does not believe it is fair for its customers
without the financial ability or desire to install solar to
subsidize those who do.
0. Has the potential for cost shifting caused by
rate design been discussed in a case in front of this
Commission?
A. Yes. As explained more fu11y in Ms.
Aschenbrenner's testimofly, the potential for cost shifting
was acknowledged by this Commission as earJ-y as 2002 and in
subsequent cases in front of the Commission. In a 2002
order, the Commission stated it recognized that in the net
metering program it approved for R&SGS customers, "the ful1
cost of the program may not be borne by participants."2 In a
20L2 order, the Commission acknowledged, "net metering
customers do escape a portion of the fixed costs and shift
the cost burden to other customers in their class. "3 In
that same order, the Commj-ssion stated, "dramatic changes
. should not be examined i-n isolation but shoul-d be
fully vetted in a general rate case proceedirlg."4
O. Does the Company bel-ieve, in light of the
Commission language cited above, that the Commission shoul-d
2 Case No. IPC-E-01-39,
3 Case No. IPC-E-1,2-21 ,
4 rd. aL 72.
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Order No.
Order No.
28951, p
32846, p
72.
13.
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authorizel the Company to establish separate customer
classes for R&SGS customers with on-sj-te generation at this
time?
Yes. The Commission's statement from Order
No. 32846 was made in reference to the Company's proposed
pricing modifications in that case, which were specific to
R&SGS net metering customers, and included a request to
increase the service charge, introduce a new basic load
capacity (*BLC") charge, and reduce the energy charge. In
the current proceeding, Idaho Power i-s only requesting that
the Cornmission approve the formation of two new rate
schedul-es on a prospective basj-s with no proposed
modifications to rate design or compensation. The Company
belie'zes its relatively limited request in this case does
not contradict the Commisslon's order issued i-n Case No.
IPC-E-72-27. Establishing separate customer classes now
will position the Company to utilize its class cost-of-
servj"ce process to allocate revenue requi-rement to the
newly established customer classes and also inform the
Company as to what rate design makes sense for the
residential customer class in a future rate proceeding
absent the inclusion of the net metering customers.
Eurtherr dS described more fully in Ms.
Aschenbrenner's testimony, the level of adoption of net
25 metering in Idaho Power's service area has grown
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substantially since the conclusion of IPC-E-L2-21 and does
not show si-gns of slowing. As stated in the NARUC Manual,
rate design incentive may not be necessary as adoption
rates increase: 5
Rate design and compensation decisj-ons
made in one year will lj-kely need to be
reviewed, modified, or changed over time
as technologies continue to develop, as
customers adopt DER at greater (cr
slower) rates, and as needed to support
economics. Eor example, a decision to
adopt net energy meteri-ng (NEM) as the
compensation methodology may be
appropriate if a regulator decides to
incentivize adoption rates of solar PV;
however, dS adoption rates increase, it
may not be necessary to continue to
provide such an incentive.
O. trlhy does the Company believe it should address
cost shifting now rather than waiting untj-I the number of
DER install-ations reach higher levels?
A. The Company believes that the most appropriate
time for the Commission to begin to address cost shifting
caused by the combination of net metering and current rate
design j-s now, before DER penetration reaches higher
leve1s. Many state utility regulatory commissions have
recently faced challenges when addressing modifications to
net metering policy at higher levels of DER penetration.
Customer dissatisfaction has been a significant driver in
high profile, contentious proceedings across the high DER
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5 NARUC Manual, p. 61.
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penetration
and Utah.
stakeholders to
states of California, Arizona, Hawail, Nevada,
Idaho Power believes that positioning
address the cost shift with separate
4 customer classes, coupled with customer education from DER
5 providers and utilities alike, wiII provide j-ncreased
6 transparency and certainty for a greater number of
7 customers as they consj-der investments and will likely lead
8 to increased customer satisfaction in the Iong run.
9 Consistent with this notion, the NARUC Manual emphasized
10 the lmportance of price signals:6
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A very important factor in customers'
decisions on DER installation is theprice signals sent by the rate design.
If those price signals do not
appropriately reflect a jurisdiction's
policies on cost-causation, the result
will like1y be an economically or
socially inefficient amount of DER.
Whil-e the Company provides its customers with
information that rates are subject to change, some
customers may be investing 1n DER systems under the
assumption that rate design changes or compensation for
excess net energy will- never occur; that misunderstanding
may negatively impact the economics of their investment.
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III. ESTABLISHMENT OF SEPAR;ATE CUSTOMER CI,ASSES
o. why
customer classes
generati-on?
A. The
customer classes
generation
between net
customers.
o.
is the Company proposing to establish new
for R&SGS customers with on-site
Company believes that establ-ishing new
for R&SGS customers wi-th on-site
is a first step toward addressing the cost shift
metering customers and standard service
10 Why not wait to create new customer classes
11 for R&SGS customers with on-site generation until the
12 future rate proceeding that considers or evaluates pricing
13 changes?
14 A. The establishment of similarly situated
15 customers or customer classes has been a long-standing and
16 j-mportant first step in the ratemaking process. Taking
1,'l this important first ratemaking step now will position the
18 Company to study this segment of customers, provl-ding the
19 data necessary to understand how this customer segment
20 utilizes the Company's system. The data quantifying the
2L usage of the system will j-nform what costs (revenue
22 requirement) are approprlately al-Iocated to the newly
23 established customer classes in a future rate proceeding
24 (cl-ass cost-of-service process) .
25
TATUM, DI
Idaho Power
t9
Company
1 This approach will limit the j-ssues presented in a
2 future rate proceeding to the evaluation of what an
3 appropriate rate design and compensation structure is for
4 R&SGS customers with on-site generation. In addition,
5 establishing new customer cl-asses will provlde increased
6 transparency for customers as they consider making
7 investments in self-generation systems.
8 The Company believes thls first step is also
9 consistent with guidance contained in the NARUC Manual
10 which acknowledges that the "important point is that a
11 jurisdiction be situated to analyze, p1an, and be prepared
12 for its next steps before the market and customer adoption
13 rates overtake 1ts ability to respond. "T
74 The Company's filing is intended to facilltate the
15 expansion of on-site generation in a way that is both
16 scalable and sustainable into the future. The current net
11 metering rate design and service provisions are neither
18 scalable nor sustainable.
t9 o What do you believe
the cost shift
should be the next step
20 toward addressing
standard service
between net metering and
22 Idaho Power believes that the next step would
23 be to determine the benefits and costs of an on-site
2t customers?
A
TATUM,
Idaho
D]
Power
20
Company
7 rd. at 62
1
2
3
4
tr
6
7
I
9
generation system through a collaborative process where
stakeholders and other utilities can participate. Before
the Company can propose an appropriate rate structure or
compensation methodology for R&SGS customers with on-site
generation, the Company would need to understand the unique
benefits and costs these customers may add to the overall
system.
o Why doesn't
costs before
Idaho Power first establish those
benefits and proposing to establish separate
net metering customers?
separate customer classes for
10 customer classes for R&SGS
11 A.Establishing
1,2 R&SGS customers with on-sj-te generation is not dependent on
13 what benefits of DER may exist. Idaho Power bel-ieves that
L4 the logical first step is to ask the Commission to decide
15 whether the nature or type of load for a customer with on-
!6 site generation is distinctly different from their current
l7 customer classification. Then, it is appropriate to study
18 this segment of customers to determine what utility costs
79 are appropriately assigned to them (c1ass cost-of-service
20 process) and what benefits these unique customers may bring
21 to the system that a customer wj-thout on-slte generation
22 doesn't.
23 O. Please describe the Company's request of the
24 Commission in this proceeding as it relates to determining
25 the benefits and costs of DER.
TATUM,
Idaho
DI
Power
2t
Company
1
2
3
4
5
6
1
I
9
A. The Company requests that the Commission open
a generic docket at the conclusion of this case with the
purpose of establishing a compensation structure for
customer-owned DERs that reflects both the benefits and
costs that DER interconnection brings to the electric
system.
as the
Because the Company bel-ieves that decisions such
determlnation of appropriate benefits and costs are
10 forum to determj-ne what those impacts
docket, that could
most appropriate
would be.
72
O. When does the Company anticipate it will
propose pricing changes for the newly established Schedul-es
6 and 8?
A. The Company anticipates that j-t will request
to modify the pricing structure and compensation
methodology as part of a future rate proceeding. The
Company believes this approach also aligns with previous
Order No. 32846, where the Commission stated:8
13
L4
15
76
t1
18
not unique to
include other
11
Idaho Power, a generic
utilities, would be the
To the extent the Company wishes to
increase the monthly customer charge, ox
implement a BLC for the residential and
small general service customer classes,
it shall raise that issue 1n a general
rate case.
8 Case No. IPC-E-12-27, Order No. 32846, p. 19.
19
20
21
22
23
24
25
TATUM, Dr 22
Idaho Power Company
7
2
3
4
5
6
a
8
9
o.Does the Company currently communicate to its
prospective net metering customers that the current rate
structure and
change?
A.
application,
af f irmativeJ-y
rates do not
(included as
the Company
acknowledge
represent a
Exhibit No.
interconnection requJ-rements are subject to
Yes. When a customer submits a net metering
10 reminds customers of this
requires that customers
an understanding that the current
guarantee of future pricing
6). In addition, the Company
provision when Idaho Power
11 notifies them via email or letter that their on-site
72
13
74
15
1,6
77
1B
79
20
2t
22
23
generation system has met all-
service will be transferred to
requj-rements and their
a net meterj-ng account.
as Exhibit No. 1. The
A
copy of the
Company al-so
Idaho Power
l-etter is attached
distributes a brochure at trade shows where
is represented that incl-udes information about
net metering and the potential for future price changes.
This brochure is attached as Exhibit No. 8. Eurther, the
Company maintains a l-ist of Frequently Asked Questions
(FAQs) on Idaho Power's net metering landing page that
includes information about net meteri-ng and the potential
for future price changes.
IV. IMPACT TO EXISTING NET METERING CUSTOMERS
24 O. Will the Company's filing impact existing
25 R&SGS net metering customers?
TATUM, Dr 23
Idaho Power Company
1
2
3
4
5
6
7
8
9
A. No, not immediatefy. The Company's request to
establish new customer cl-asses in this proceeding will not
impact existing R&SGS net metering customers. The Company
proposes that existi-ng R&SGS net metering customers remaj-n
on Schedule 84 for a period of time, under the same rate
structure and compensation method, and transition in the
future to the proposed new schedules over some perj-od of
years.
O. Has the Company calculated what the payback
period for an average residential net metering customer is?
A. Yes. While the payback period for an
individual customer can vary depending on variabl-es such as
cost to instal1, customer usage, and system orlentation,
using the normal-j-zed average monthly usage per residential-
customer (954 kwh) for 201,6, the payback period is
approximately 15 years for a customer living in Boise,
Idaho who instal-l-s a 6 kW PV system.
O. Is the Company proposing to establ-ish the time
10
11
t2
13
t4
15
L6
77
1B
L9 frame over which
20 customers as part
27 A. No.
22 transition period
23
the
part
that
of a future rate
24
to transition existing R&SGS net metering
of this case?
The Company recommends that the term of
be determined by the Commission as
proceeding. The Company belleves
informed in the context of a general
TATUM, DI
Idaho Power
24
Company
25
decision is best
1 rate case when it is also known what rate design changes
2
3
4
5
6
1
8
9
will- be taking pIace.
O. What does this mean for existing R&SGS net
metering customers?
^Under the Company's proposal,
wil-l- remai-n on Schedul-e
the existing net
metering customers 84 and their
rates will conti-nue to mirror those in Schedule 1 for
residential net metering customers and Schedule 7 for small
10
general
proposes
Schedule
service net meterj-ng customers.
that the length of time these
The Company
customers remain on
11 84 be determj-ned by the Commission as part of a
are proposedL2 future rate proceeding, when dj-fferent rates
13 for R&SGS customers with on-sj-te generation taking servj-ce
14 under Schedul-es 6 and 8.
15 O. Please summarize the Company's request in this
l6 proceeding.
l7 A. The Company i-s requesting that the Commission
18 lssue an order authorizing the following: (1) closure of
19 Schedule 84, Customer Energy Production Net Meterj-ng, to
20 new service for R&SGS customers with on-sj-te generation
2l after December 31, 2077, (2) establlshment of two new
22 classifications of customers applicable to R&SGS customers
23 with on-site generation that request to interconnect to
24 Idaho Power's system on or after January 7, 2018, with no
25 pricing changes at this time, (3) acknowledgement that
TATUM, Dr 25
Idaho Power Company
1 smart inverters provide functionality that is necessary to
2 support the ongoing stability and reliabil-ity of the
3 distribution system by ordering the Company to amend its
4 applicable tariff schedules to requi-re the installation and
5 operatj-on of smart inverters for all new customer-owned
6 generator interconnections within 60 days foll-owj-ng the
7 adoption of an industry standard definition of smart
8 inverters as defined by the IEEE, (4) commencement of a
9 generic docket at the conclusion of thls case with the
10 purpose of establishing a compensatj-on structure for
11 customer-owned DERs that reflects both the benefits and
72 costs that DER interconnection brj-ngs to the electric
13 system.
L4 O. When is the Company requesting a Commission
15 determination regarding its proposal 1n this filing?
16 A. The Company is requesting that the Commission
L7 issue an order approving its proposal by December 31, 2017.
18 O. Does this conclude your testimony?
79 A. Yes.
20
2t
22
23 it tt'n .ti
t
iI
t
i-I..\ tlaa
,rt]t.S
24
';i"oaa
TATUM, DI
Idaho Power
26
Company
25
)
)
)
1
2
3
4
5
6
7
U
9
ATTESTATION OF TESTIMONY
STATE OE IDAHO
SS.
County of Ada
I, Timothy E. Tatum, having been duly sworn to
testify truthfully, and based upon my personal knowledge,
state the following:
I am employed by Idaho Power Company as the Vice
President of Regulatory Affairs j-n the Regulatory Affairs
Department and am competent to be a witness in this
proceeding.
I decl-are under penalty of perjury of the laws of
the state of Idaho that the foregoing pre-filed testimony
and exhibj-ts are true and correct to the best of my
information and belief.
DATED this 27th day of July 2011.
Timothy Tatum
SUBSCRIBED AND SWORN to before me this 27th day of
JuIy 2017.
10
L2
13
74
15
16
L1
18
79
20
27
22
11
23
24
25
26
21
28
29
30
31
r.aaart
YK.
No ry Publ-l or Idaho
s€, IdahoResidlng at l_
My commission expires:L2/20/2020
TATUM, Dr 21
fdaho Power Company
$oTatr
r-a-
Pug11c
4
op tD
{
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-17-13
IDAHO POWER COMPANY
TATUM, DI
TESTIMONY
EXHIBIT NO. 1
Solar Panel Technology: What's the Latest Breakttrough? | EnergySage
Sign In
Page I of7
< NEWS FEED
New solar panel technology: learn about
advances in solar energy
The Newest Technologies
in Solar
-ai-
Solor power wos in o constont stote of innovotion in 2016, with new odvonces in solor ponel
technology onnounced olmost every week. ln the post yeor olone, there hove been milestones in solor
efficiency, solor energy storoge, weoroble solor technology ond solor design tech. Reod on to get the
complete updote on oll the breokthroughs you should know obout in the world of new solor ponel
technology.
Ready to compare solar quotes now? Click to find installers near you
Solar panel technology: what's new in2O17?
Exhibit No. 1
Case No.|PC-E-17-13
T. Tatum,IPC
Page 1 of4
7lt4l20r7http://news.energysage.com/solar-panel-technology-advances-solar-energy/
Solar Panel Technology: Whafs the Latest Breakthrough? | EnergySage
There ore two moin types of solor technology: photovoltoics (PV) ond concentroted solor power
(CSP). Solor PV technology coptures sunlight to generote electric power, ond CSP hornesses the
sun's heot ond uses it to generote thermol energy thot powers heoters or turbines.
With these two forms of solor energy comes o wide ronge of opportunities for technicol innovotion.
Here ore some of the lotest emerging solor ponel technologies for 2OL7:
Solar skin design
One mojor borrier for the solor industry is the foct thot o high percentoge of homeowners
consider solor ponels to be on unsightly home oddition. Luckily, one new venture hos o
Page2 of7
f
o
o
o
solution. Sistine Solor, o Boston-bosed design firm, is moking mojor strides with the concept of
oesthetic enhoncement thot ollow solor ponels to hove o customized look. The MIT stortup hos
creoted o "solor skin" product thot mokes it possible for solor ponels to motch the oppeoronce of o
roof without interfering with ponel efficiency or production. Sistine Solor's skin product is expected to
hit U.S. morkets in 2077 ond will help to rebrond solor ponels os o luxury product, not just o home
efficiency upgrode.
Solar powered roads
This post summer poved the woy for tests of on exciting new PV technology - solor
powered roods. The sidewolks olong Route 66. Americo's historic interstote highwoy, were
chosen os the testing locotion for solor-powered povement tech. These roodwoys ore herolded for
their obility to generote cleon energy. but they olso include LED bulbs thot con light roods ot night
ond hove the thermol heoting copocity to melt snow during winter weother. The next stop following
sidewolk tests is to instoll these roodwoys on designoted segments of Route 66.
Wearable solar
Though weoroble solor devices ore nothing new (solor-powered wotches ond other
godgets hove been on the morket for severol yeors), 2016 sqw on innovotion in solor
textiles: tiny solor ponels con now be stitched into the fobric of clothing. The weoroble solor products
of the post, like solor-powered wotches, hove typicolly been mode with hord plostic moteriol. This
new textile concept mokes it possible for solor to expond into home products like window curtoins
ond dynomic consumer cleon tech like heoted cor seots. This emerging solor technology is credited to
textile designer Morionne Foirbonks ond chemist Trisho Andrew.
Solar batteries: innovation in solar storage
The concepts of off-grid solor ond solor plus storoge hove goined populority in U.S.
morkets, ond solor monufocturers hove token notice. The industry-fomous Teslo
Powerwoll, o rechorgeoble lithium ion bottery product lounched in 2015, continues to leod the pock
with regord to morket shore ond brond recognition for solor botteries. Teslo offers two storoge
products, the Powennroll for residentiol use ond the Powerpock for commerciol use, ond the cleon
outo behemoth is expected to lounch its Powerwoll 2.0 product in weeks to come. Solor storoge is still
o foirly expensive product in 2016, but o surge in demond from solor shoppers is expected to bring Exhibit No. 1
significontly more efficient ond offordoble botteries to morket in2OL7. Case No. tpC-E-17-13
T. Tatum, IPC
Page 2 ot 4
htB://news.energysage.com/solar-panel-technology-advances-solar-energy/ 7ll4l20l7
Solar Panel Technology: Whafs the Latest Breakthrough? | EnergySage Page 3 of7
The latest solar tcchnology helps homeowners save even more money
Try our Solar Calculator and see for yorrrself
-ffi
Advances in solar energy: the latest solar panel technology
breakthroughs
Solar tracking mounts
As solor storts to reoch moinstreom stotus, more ond more homeowners ore considering
solor - even those who hove roofs thot ore less thon ideol for ponels. Becouse of this
e
o
exponsion, ground mounted solor is becoming o vioble cleon energy option, thonks in port to trocking
mount technology.
Trockers ollow solor ponels to moximize electricity production by following the sun os it moves
ocross the sky. PV trocking systems tilt ond shift the ongle of o solor orroy os the doy goes by to best
motch the locotion of the sun. Though this ponel odd-on hos been ovoiloble for some time, solor
monufocturers ore truly embrocing the technology in 2016. GTM Reseorch recently unveiled o recent
report thot shows o mojor upword trend in the populority of trocking systems. GTM projects o 254
percent yeor-over-yeor increose for the PV trocking morket this yeor. The report stoted thot by 2021,
olmost holf of oll ground mount orroys will include solor trocking copobility.
Advances in solar panel efficiency
The post few yeors in the solor industry hove been o roce to the top in terms of solor cell
efficiency, ond 2016 wos no different. A number of ochievements by vorious ponel
monufocturers hove brought us to todoy's current record for solor ponel efficiency:
23.5 percent, held by premium ponel monufocturer SunPower.
The solor cell types used in moinstreom morkets could olso see mojor improvements in cost per wott
- o metric thot compores relotive offordobility of solor ponels. Thonks to Swiss ond Americon
reseorchers, Perovskite solor cells (os compored to the silicon cells thot ore used predominontly
todoy) hove seen some mojor breokthroughs in the post two yeors. The result will be o solor ponel
thot con generote 20+ percent efficiency while sfil/being one of the lowest cost options on the
morket.
Exhibit No. 1
Case No. IPC-E-17-13
T. Tatum, IPC
Page 3 of4
7tr4D0t7htp://news.energysage.com/solar-panel-technology-advances-solar-energy/
C.f l.-'-: i.t:. : - ";,: .., --ir.,.Ir.-l =
Solar Panel Technology: What's the Latest Breakthrough? | EnergySage Page 4 of7
Of course, the work doesn't stop there, os MIT reseorchers reminded us in Moy when they onnounced
new technology thot could doublethe efficiency of solor cells overoll. The MIT lob teqm reveoled o
new tech concept thot coptures ond utilizes the woste heot thot is usuolly emitted by solor ponels.
This typicolly releosed ond non-hornessed thermol energy is o setbock ond opportunity for
improvement for solor technology, which meons this innovotion could help the cost of solor to
plummet even further.
Solar thermal fuel (STF)
There is little debote when it comes to solor power's ultimote drowbock os on energy
source: storoge. While the post decode hos seen incredible growth of the PV industry, the
3
a
poth forword for solor involves on offordoble storoge solution thot will moke solor o truly sustoinoble
energy source 24 hours o doy. Though solor botteries (mentioned obove) ore o storoge option, they
ore still not economicolly vioble for the moinstreom. Luckily, MIT Professor Jeffrey Grossmon ond his
teom of reseorchers hove spent much of the post few yeors developing olternotive storoge solutions
for solor, the best one oppeors to be solor thermol fuels (STFs).
The technology ond process behind STFs is comporoble to o typicol bottery. The STF con horness
sunlight energy, store it os o chorge ond then releose it when prompted. The issue with storing solor
os heot, occording to the teom's findings, is thot heot will olwoys dissipote over time, which is why it
is cruciol thot solor storoge tech con chorge energy rother thon copture heot. For Grossmon's teom,
the lotest STF prototype is simply on improvement of o prior design thot ollowed solor power to be
stored os o liquid substonce. 2016 sow the invention of o solid stote STF opplicotion thot could
be implemented in windows, windshields. cor tops, ond other surfoces exposed to sunlight.
Solar water purifiers
Stonford University reseorchers colloboroted with the Deportment of Energy this yeor to
develop o new solor device thot con purify woter when exposed to sunlight. The
minuscule toblet (roughly holf the size of o postoge stomp) is not the first solor device to filter woter,
but it hos mode mojor strides in efficiency compored to post inventions. Prior purifier designs needed
to horness UV roys ond required hours of sun exposure to fully purify woter. By controst, Stonford's
new product con occess visiblelighl ond only requires o few minutes to produce relioble drinking
woter. As the technology behind solor purifiers continues to improve, expect these chiclet-sized
devices to come to morket with hikers ond compers in mind os on ideol consumer oudience.
What new solar panel technology means for homeowner$ in2Afl
For those considering solor ponels systems, this long list of solor ponel technology innovotions from
2016 is nothing but good news. Efficiency upgrodes, storoge improvements ond equipment
copobilities oll contribute to more effective power output for solor ponels ond lower costs for systems.
Mony of the products mentioned in this orticle, such os trocking mounts ond solor botteries, ore
ovoiloble in the EnergySoge Solor lrlarketploce - oll you hove to do is indicote your preference for
porticulor equipment options when you register your property. To get on instont estimote for your
home's potentiol solor costs ond sovings, try our free Solor Colculotor.
Exhibit No. 1
Case No. IPC-E-17-13
T. Tatum, IPC
Page 4 of 4
7n412017http://news.energysage.com/solar-panel-technology-advances-solar-energy/
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
cAsE NO. IPC-E-17-13
IDAHO POWER COMPANY
TATUM, DI
TESTIMONY
EXHIBIT NO.2
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Case No. IPC-E-17-'13
T. Tatum, IPC
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Exhibit No. 2
Case No. IPC-E-'|7-'13
T. Tatum, IPC
Paoe2 ol 2
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC.E.17.13
IDAHO POWER COMPANY
TATUM, DI
TESTIMONY
EXHIBIT NO.3
II
Solar Industry Data I SEIA Page I of8
S,:lcrr Energy
lndustr ies
Assc.:ciolionCI
Research I Resources
Solar Industry Data
Solar Industry Growing at a Record Pace
Solar energy in the United States is booming (http://www.seia.org/smi) . Along with our partners at GTM
Research and The Solar Foundation, SEIA tracks trends and trajectories in the solar industry that
demonstrate the diverse and sustained growth acrcss the country.
Below you will find charts and factoids that summarize the state of solar in the U.S. SEIA Members
have access to presentation slide decks ftttp://www.seia.org/membership/member-benefits/members-only-
presentations) that contain this data and much more. Not a SEIA Member? Join today!
(http ://www2. seia.or gl ll 13923 I 120 I 6 -02 -23 I n%z)
Solar Growth and the ITC
The Solar Investment Tax Credit (ITC) has provided industry stability and growth since its initial
passage in 2006. In the last decade, solar has experienced an average annual growth rate of 68%. To
learn more about the ITC and its impact on the solar industry, visit our ITC Policy Page
(http://www.seia.orglpolicy/finance-ta:rilsolar-investment-tax-credit) .
Exhibit No. 3
Case No. IPC-E-17-'13
T. Tatum, IPC
Page 1 of8
7n4/2017http : //www.seia.org/research-resources/solar-industry -data
Solar Industry Data I SEIA Page 2 of8
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e 2017 gtmresearch SEnH
(http://www.seia.org/sites/default/fi1es/Figl-SolarGrowthWithlTC-20l7YIR.png)
Solar as an Economic Engine
Nearly 260,000 Americans work in solar (http://www.thesolarfoundation.org/solar-jobs-census/) - more than
double the number in20L2 - at more than 9,000 companies in every U.S. state.
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Growth in Solar is led by Falling Prices
The cost to install solar has dropped by more than70o/o since 2010, leading the industry to expand into
new markets and deploy thousands of systems nationwide.
Exhibit No. 3
Case No. IPC-E-17-13
T. Tatum, IPC
Page 2 of 8
http://www.seia.org/research-resources/solar-industry-data 7ll4l20l7
\
Solar tndustry Data I SEIA
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Exhibit No. 3
Case No. IPC-E-17-13
T. Tatum, IPC
Page 3 of 8
7n4t20r7
o
lo11 lot{l0r5 2016
o20t7 gtfirffiarch ltnmx:
(http://www.seia.org/sites/default/filesffi93-GrowthSolarFallingPrices-2017YIR.png)
Solarrs Share of New Capacity has Grown Rapidly
In 2016, Solar installed39Yo of all new electric generating capacity, topping all other technologies for
the first time. Solar's increasing competitiveness against other technologies has allowed it to quickly
increase its share of total U.S, electrical generation- from just 0.lo/oin20l0 to l.4Yotoday. By 2020
solar should surpass 3Yo oftolal generation is expected tohit5yoby 2022.
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Solar Industry Data I SEIA Page 4 of8
U.S. Solar Market Through Ql 2017: Key Takeaways
. 2,044 MW installed in Ql 2017. 6th consecutive quarter over 2 GW. Down ZYofromQl 2016. Nearly 45 GW of total solar capacity now installed
o Average Annual Growth Rate of 68% over last l0 years
" Generates enough electricity to power 8.7 million homes. Solar accounted for 307o of all new capacity installed in Ql 20f 7
" Second to only Natural Cas which accounted for 4l%o
" Builds upon strong 201 6 in which Solar accounted for 39o/o of all new capacity, ranking I st. Solar prices dropped l9o/o oyer the last 12 months. Price drop is seen across all market segments, led by reduced hardware costs. Prices have dropped 63% over the last 5 years. Utility-scale PPAs now signed for $0.03 - $0.05/kWh. There are now nearly 1.4 million solar installations in the U.S.
" After reaching I million in2016,2 million should be hit in 2018 and 4 million by 2022
Solar PV Price Breakdown
The biggest cost-decline opportunity in the solar industry exists in soft costs, including labor, supply
chain and overhead considerations. The U.S. Department of Energy (http://energy,gov/eerelsunshot/sunshot-
initiative) is leading the charge on reducing soft costs, and SEIA and The Solar Foundation are working
with cities and counties (http://www.seiaorg/act-now/help-your-community-become-solsmart) to streamline
permitting processes and reduce local barriers to going solar.
(H 2015 Quoted PV Prlc:s
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: .'r)l 7
The U.S Solar Industry is a 50 State Market
While Califomia has traditionally dominated the U.S. solar market - with 35o/oma*et share in 2016 -
other markets are continuing to expand, including Minnesota, Utah, Florida and Texas. As the price of
solar continues to fall, new markets will grab an increasingly large share of the market. Exhibit No. 3
Case No. IPC-E-17-13
T. Tatum, IPC
Page 4 of 8
http ://www. seia.org/research-resources/solar-industry-data 7lt4/2017
I
L___l
Solar Industry Data I SEIA
201. lolt tor6 lot?f
Page 5 of8
Exhibit No. 3
Case No. IPC-E-17-13
T. Tatum, IPC
Page 5 of 8
g 20t7
Cumulrtive Solrr Crpacity by Stctc, through 0l 201?
|.....1 II1.000. > t8.m0 MtY< 20 MW 20- tm t00 - 999
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gtnuesearch 'sGtA:.*:
(http://www.seia.org/sites/defaulUfilesffig6-SolarGrowingCoasttoCoast-20l7June.png)
New Market Opportunities for Distributed Solar
After years of 50o/o+ annual growth, the residential market $owth has slowed in a handful of mature
markets as installers trial new sales techniques. But growth in emerging markets like Utah, Texas,
South Carolina and Florida should help the national residential market grow in 2017. Meanwhile, the
rapid rise of community solar has boosted the non-residential segment in20l6 md20l7, coupled with
increasing numbers of both off-site and rooftop corporate procurement by such companies as Walmart,
Apple, Target and Amazon (http://www.seia.org/solarmeansbiz) .
Yearly U.S. lolar Photovohak (PVl lnstallatlonl
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(http://www,se ia.org/sites/default/files/Fig7-NewMarketOppsforDG-20 l TJune.png)
http ://www. seia.org/research-resources/solar-industry-data 7n4t20t7
t_l
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1 CA: 18,963 MW
2. NC: 3,288 MW
3 AZ: 3.151 MW
4 NV: 2,269 MW
5, NJ 2.1l4 MW
5 MA: 1.592 Mw
7 UT: I,527 MW
8 GA: 1,478 MW
9 TX, 1,228 MW
10. NY:1,0I2 MW
I
0
Solar Industry Data I SEIA Page 6 of8
Utility-Scale Solar Pipeline
ln2016,72Yo of all solar capacity installed was utility-scale, and this segment should account for at
least two-thirds of all solar capacity again in 2017. While more than a third of the contracted pipeline
will be completed in2017, procurement is again ramping up and will lead to a resumption of utility-
scale growth by 2019.
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(http://www.seia.orglsites/default/files/Fig8-USUtilityScalePipeline-2017June.png)
U.S. Solar PV Growth Forecast
While 2017 installations are expected drop slightly from a record-shattering 2016, the 12.6 GW
expected still almost doubles 2015, the second largest year on record. After rapidly completing a record
buildout in 2016 and20l7, developers will be looking to procure new projects with completion targets
moving into the next decade.By 2021there will be over 100 GW of solar installed in the U.S., with
annual totals approaching l8 GW in2022.
sIIIt
Exhibit No. 3
Case No. IPC-E-17-13
T. Tatum, IPC
Page 6 of 8
7lt4l20l7http ://www. seia. org/research-resources/solar-industry-data
..ESl
Solar Industry Data I SEIA
grrmlBsesrch '5A=
Page 7 of8
Exhibit No. 3
Case No. IPC-E-17-13
T. Tatum, IPC
Page 7 of 8
7tr4l20t7
I U,S. Solar PV Deployncnt Forecfft
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Solar Helps Fortune 500 Companies Save Money
Data from SEIA's annual Solar Means Business (http://www.seia.org/solarmeansbiz) report show that major
U.S. corporations, including Target, Walmart and Apple are going solar at an incredible rate. The top 25
corporate solar users in America have installed nearly 1,100 MW of capacity at 2,000 different facilities
across the country as ofOctober 2016.
Other key takeaways:
. The amount of solar installed at U.S. corporations and businesses is enough to offset I .l million
metric tons of carbon dioxide emissions each year. Commercial prices have fallen by 58% since 2012 and by l6Yo in the last year
http ://www. sei a. org/research-resources/solar-industry-data
Solar Industry Data I SEIA
(http://www.seia.org/map/corporate-solar-projects. php)
Click on the image above to view the map full screen. Zoom in to view the projects via satellite imagery
Topics Tags
Page 8 of8
Solar Energy Industries Association
2A2-6t2-0556 1600 l4th Street, N\il, Suite 400,
Washington, DC 20005
Exhibit No. 3
Case No. IPC-E-17-13
T. Tatum, IPC
Page 8 of 8
7lr4l20t7http //www. seia. or g/re search-resources/solar- industy-data
Irh
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-17-13
IDAHO POWER COMPANY
TATUM, DI
TESTIMONY
EXHIBIT NO.4
Auric Solar movcs from Boisc to largcr Meridian spoce I Ncws I mymcridianpress.corn Pagc I of 2
trttp:ll*rru.mymcridianprcs.com/ncm/auric-toaar+norcg"from{oir+{olargcr-meritlian-
3pdarlkh_d6E5E0dd-d6cd-56d-9aab553ec6l51 a8 I .hm
Auric Solar moves from Boise to larger Meridian space
Company CEO says the rolar irdustry in l&bo ir exploding
By Moidlan Pcaa *att norr(omlmsidspratc.com ttlay 5.2017
Aric Sdtr h3trb .oh pafiir! on honaa. erch ar tiL on ln ilortdl$. and qnrurdd lic$Uts. Tho co.npdt
o{fic. tun &i!. b M.rid.n sd pa.m to grw itr rl.ll by 10 b t2 anpbyccc h 2017.
C,owlay d Leign Glnon
Auric Sobr has moved into a new 14,(M-squarc,foot o6ns in Meridian * a building moro
tlrran 10 Xmes tha sizc of the company's frst o'ffrce in thc Treasure Valley, The new ofrce
ie at 3568 E. Lanart St.
The solar company was founded in Utah in 2010 and expanded to ldaho wilh a residential
6i2612017hrp:#www,
Exhibit No. 4
Case No. IPC-E-17-13
T. Tatum, IPC
Page'l ol2
t L- - *;3.'I
C: ,-..
'" "1'
Auric Solsr moves from Boise to larger Meridian space I News I mymeridianpress.com Pagc 2 of 2
solar sales division in ?014, amptoying threa people.
Noltr, Auric has 39 ldaho employees and plans to add 10 to 12 more this year, acoording
to company spokeswornan Leigh Gibson.
Along with expanding its office spaca in ldaho, Auric ie also atarting a commercial sales
division here. The expansion reflecE the grflrlh of the solar indusfy overall in ldaho,
according to a press release,
ln the first quarter of 2A17 , Auric Solar sold rnore kilowatts of energy than all of 2016.
'The ldaho solar market is exploding,'A*lric Solar CEO Jass Phillips said in a pross
release. That's because people see how afiordable solar really is. Home and business
ownerE sec the value in producing thair orvn power, inslead of paying a local power
company to rent energy.'
Auric installa solar panels lor customara ranging from srnall medical offcas to massive
operations. The company installed a Z.l-megawatt system on Major League Socce/s Rio
Tinto Stadium in Utah. according to a pres$ release.
http:li www.mymcridianprc*s"com/nclvs/auric-.golar-moves-liom-boise-to-largcr-meridian-... 6i26l20lV
Exhibit No. 4
Case No. IPC-E-17-13
T. Tatum, IPC
Page2of 2
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-17-13
IDAHO POWER COMPANY
TATUM, DI
TESTIMONY
EXHIBIT NO.5
t ntn n
a
n
M
r
nt
Quantifyr"g Subsidy from
Non-Solar to Solar Customers
Exhibit No. 5
Case No. IPC-E-17-'13
T. Tatum, IPC
Page 1 of5
Bv BensnRe A AsHr-Ev BnowN RNo AuuRo
28 PulucUflurrEs Fonililellrtv 0croBEB 2016
e have written this anide to make the case that the net metering policy that many sates adopted to
support and subsidize rooftop and community solar programs is, in today's contoft, too expensive. It's
unfair to most consumers who are compelled to pay more than their fair share of costs, and socially
regressive.
'We are not opposed to renewable energy or solar enerry.'We support the need to pursue them to
rhe ortent that they are a cost-effecdve me:ms of mitigating the impact of climate change. These resources are impomant
to the nationt future energy supply and they should be encouraged by appropriate federal and sate policies.
Howwer, net metering is now causing an unfair shift ofcosts to non-solar customers. This policy is unfair because
it is too expensive, because it shifts essential elecricity service costs to rhose who cannot afford or install solar on their
roofs, and because its justificadon to jumpsart a nascent industry is no longer applicable. Initially, most states capped
the amount of solar capacity available for the net metering subsidy. These caps are no\il being expanded and increased,
to the detriment of non-solar customers.
Net metering gives solar customers a credit on their bill when their rooftop panels generate orcess po\Mer and sell it
back to the udliry. This subsidy means that solar customers pay a tiny electric bill to their electric utiliry or none at dl.
This subsidy primarily supports the solar industry and obvi-
ously provides an important marketing tool for these companies.
But there is no free lunch, since these subsidies to solar customers
are paid for by other non-solar customers.
The end result is that it burdens non-solar cusromers
with higher electric bills. That creates an avoidable but often
invisible inequity.
As shown below, subsidies per net metering customer range
from several hundred dollars a year to values in excess offif-
teen hundred dollars a year. There is a median value of some
eight hundred dollars a year in the publicly-available studies we
summarize below.
fu rooftop solar penetration continues, these subsidies are
projected to run into the billions of dollars a year in the U.S.
These numbers do not include tax-based subsidies, nor are they
refective of all of subsidies inherent in net metering. Rather,
they are derived only from the specific rate impacts we have
identified in the article.
Net metering is not only too expensive. It is unfair. Under
net metering, solar customers avoid paying their share of the
costs of operating and maintaining the electric grid. Non-solar
owners pick up the tab.
Under current rate designs, which are largely volumetric in
nature, net metering essentially credits solar cusromers for each
unit of power that they produce at the full retail electric rate.
Barbara R. Alexander is an independent consultant who repre-
sents state and nationalconsumer advocates. Ashley Brown is the
executive director of the Harvard Electricity Policy Group. Ahmad
Faruqui is an economist and principle with the Brattle Group. The
views expressed in this article are those of the authors and not of
the organizations of which they are affiliated of, or of their clients.
Subsidies per
net metering
customer range
from several
hundred dollars
a year to values
in excess of
fitteen hundred
dollars a year.
Thus, non-solar customers are
obliged to pay retail prices for
energy that is readily available
at substandally lower wholesale
prices. This includes more effi-
cient or less expensive large-scale
solar and wind generation.
The utility's retail rates
include the cost ofgenerating
electricity. They also include
the cost of the transmission and
distribudon lines that deliver that
electriciry to customers. Finally,
these rates reflect the metering and billing system that solar
customers as well as all customers rely on, including call centers
and customer services performed by utilities for all customers.
'W'hen a customer installs solar panels on their rooftop, this
reduces the utiliryt cost of generating electricity. The customer
should be compensated for the value ofthat avoided energy.
However, the customer still requires a connection to the grid
for those hours when the solar panels are not generating all ofthe
electricity required on premises. An example of this is at night,
or on cloudy days. The connection is also required to export and
sell any excess energy that the cusromer may produce.
Solar customers benefit from having enough power plants
being built to provide adequate backup when the sun is not
shining. It is important to note that often the customert demand
for electriciry exceeds the capaciry of the solar panels. That makes
solar energy an intermittent and unpredictable power source.
Additionally, its energy production is generally not coincident
with peak demand of most utilities in the United Srates.
The customer still requires a meter, a call center to answer
questions about monthly bills, and other vital services. It is only Exhibit No. 5
Case No. IPC-E-17-13
ocroBER 2016 PuBLrc UfluflEs FoBrr{rcrrry ,rt I:lP 5:
Nrr MrrrRms Susslov EsrrmnrrsFre. 1
$2,000
$1,800
$1,600
$1,400
$1,200
$1,000
$800
$600
$400
$200
$0 PG&E- E3-NV
lowerrange estirnale
$1,600
(2016)
$1,7s2
(2020)
SDG&E PG&E_
upper range
$1,m0
(201 6)$1,(E1
(2020]|
6o
oo6
.goct
$471
(201 5)
$51 1
(2015)
NV Energy
(sPPC)
$620
(201 s)
NV PUC
(NPC)
$661
(201 s)
NV Energy
(NPC)
E3_CA
estimate
$865
(201 5)
Arizona
$958
(201 s)
Hawaiian
ElectricPublic
NV PUC
(sPPC)
ldaho
Power
Service
Notes:
Year indicates date of cost-shift estimate, which is sometimes a forecast.
ln some cases, reported estimates were connected to annual dollars per net metering customer for comparison purposes.
The PG&E ranges are calculated using assumptionsfrom the California Public Utilities Commission's Public Modeling Tool.
SPPC and NPC refer to Sierra Pacific Power company and Nevada Power Company service territories respectively.
equitable that the solar customer should pay the utility for a
share of those services. However, net metering policy prevents
this from happening.
Net metering is also regressive in nature. The subsidy, in the
aggregate, consdtutes a regressive wealth transfer from lower-
income customers to higher-income customers. Solar power is
rypically installed by higher-income customers.
customers. This contributes to the dangpr ofunaffordable electric-
iry for those most in need. It is not the udlities that pay for this
ffansaction, but the customers who don't have solar equipment.
Quantifying the Subsidy
To illustrate the magnitude of the subsidy to solar customers, it
might be helpful to consider a hypothetical utiliry
This utility has a residential retail rate of
ten cents per kilowatt-hour. This includes
generation supply costs ofsix cents per
kilowatt-hour. And delivery or distribution
system costs offour cents per kilowatt-hour. 2
A solar customer receiving full retail
rate compensation of ten cents per kilo-
watt-hour for generation sold back to the
grid would receive a subsidy of four cents
per kilowatt-hour.
\Jf'hen the solar customer sells energy
back to the grid, it allows the utiliry to avoid
incurring variable costs related to ggneration
supply. However, the utiliry still incurs fixed
and variable costs related to maintaining the electric grid, ensur-
ing reliability of service, providing customer services, and more.
A four cents per kilowatt-hour subsidy can translate to an
annual subsidy of two hundred fony dollars per solar customer.
This is assuming a retail rate of ten cents per kilowatt-hour,
and a monthly average offive hundred kilowatt-hours ofexcess
generation sold back to grid' ."." *". =,JllJl,l):i3
T. Tatum, IPC
Page 3 of 5
They can afford to buy the system outright, or have the credit
ratings to finance it or lease it. They also own their homes. It is not
available to those who rent or reside in multi-unit housing. It's also
not available to those who do not have the disposable income or
credit ratings to enter into loans, leases or purchase agreements. I
As a result, net metering typically transfers the cost of the
unpaid utility services from solar customers to lower-income
customers can afford
to buy a solar system
outright, or have the
credit ratings to
finance it or lease it.
55 Higner-income
I
E
- Barbara R. Al.exander
30 PuBrrc UiluflEs FoRTilTGHTLv ocroBER 201 6
$740
(201 5)Iw4
(201s)I
))I
This subsidy is in addition to the lack of revenues from a solar
customer using less electricty when the solar system is gpnerating
power for the customert own use. Of course, the total amount
of a net metering subsidy will vary according to how many solar
customers are on the system.
It will also vary according to the volume of excess kilowatt-
hours exported by the solar customer. Finally, it will vary due
to the differendal berween the utilityt fixed distribution service
costs and the generation supply costs avoided.
Several utilities, regulators, and consultants have quantified
the subsidy per net metering customer in dollars per year.
These subsidy estimates have been derived through different
methodologies. They apply to different service areas, and assume
billion dollars in net present value terms for all s,ptems installed
in the 2017 -2025 timeframe. {
Path Forward
Solar customers are a distinct class of residential customers that
should be treated separately from other non-
solar residential customers. Theywill have an
obligation to pay their fair share.
This will mean that their payments for
the electricity they are selling back to the grid
under net metering should reflect the market
price for their gpneration supply service. These
should not be arbitrarily-determined high
prices, and certainly not the full retail rate.
There are a variety of ways to ensure that
solar customers pay their fair share of the
costs ofboth back up generation capacity
and the grid, and dont end up being overly
subsidized by non-solar customers. However,
the fundamental poliry should require solar customers to pay
their share of the common costs.
These costs are necessary to support and maintain the distribu-
tion or delivery systems and to ensure that adequate capaciry is
available when needed for all customers.
This payment can be structured as a higher 6xed charge, a
demand charge, or a combination of both. It will pay for the cost
of being connected to the grid, along with a time-oFuse rate for
the energy consumed.different forecasts of solar penetration.
'$7ith those caveats, a summary of net
metering subsidies is presented in Figure l.
Even the lower numbers amount to
several hundred dollars a year. The higher
numbers exceed fifteen hundred dollars a
year. The median is around eight hundred
dollars a year.
Additionally, there are rwo studies that did
not lend themselves to inclusion in the figure.
In New York, the investor-owned electric
utilities filed comments with the New York
Public Service Commission. These com-
ments sought to either end or make significant
changes to the current policy. The utilities
included a graphical presentation of the impact of net metering
penetration on residential customer bills.
Theystated, "ln fact, atjust a l0 percent residential kilowatt-
hour penetration level, the average subsidy paid by a non-partici-
pating customer increases their delivery bill by about 6.9 percent
and their total bill by about 3.6 percent." t
In January 2016, Southern California Edison estimated that
net metering would result in a total lifetime subsidy of seventeen
The end goal of pricing is that solar customers pay for the
essential system-wide services that are being provided to them.
These are vital to the essential nature of electric service that is
provided to all customers.
Furthermore, the compensation for excess generation by solar
customers could vary by time-of-day. These costs are higher than
average during the afternoon and evening hours, and lower than
average during nighttime hours'
case No.
t,JiT):ii
T. Tatum, IPC
Page 4 of 5
55 tnvestment in centralized
r,i.,, utility-scale solar could
lower cost and without
- Athlry Brown
IL ubsidv. 2g
!l
achieve the same
mental benelits
T I
LT,e
32 Pu8uc UilunEs Fonrilcflrry ocroBER 2016
g,"1 6e;1P
.r'
1
(( ttis time to bring
net metering in
Iine with sound
ratemaking and
consumer-0riented
policies. ))
- Altmad Faruqui
r
Subscribe today:
fortni ghtly. com/su bscri be
or sign up for a
no obligation trial at
fortn i g htly. co m/f ree-trial
or call 1-800-368-5001.
PUBLIC UTILITIES
FORTNIGHTLY
Your best source lor unbiased
and insightlul coverage ol the critical issues
lacing the energy industry.
ght
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NS
and ana ys
PUErn UT|IrTES t s
FORTNIGHTLY E:
I
I^,k*mcrs assocraiioilgoaru'[teer[gl
This time-of-use differentiation would
provide rooftop solar owners with a fairer
compensation for their contribution to
the system needs. Unfortunately, such
distinctions are almost never made in
prevailing net metering pricing schemes.
Some energy experts have argued
that solar, as a clean source ofelectric-
ity, should be compensated for avoid-
ing harmful emissions associated with
conventional generation sources.
Vhile this might be a legitimate
benefit, current net metering policy is
overly generous in this regard. If this
was the key purpose of the policy, it is
unfair to create rooftop and community
solar as a most favored form of renewable
and clean energy.
Other renewable energy resources
are less expensive, with often more cost-
effective non-polluting results. These
include wind and energy efficiency. In
fact, investment in centralized utility-
scale solar could potentially achieve the
same environmental benefits.
These options will come at a lower
cost and without the cross-subsidy
penalty to non-participants. Further-
more, there are also very substantial
economic risks associated with imposing
technology-specific hedges against future
environmental mandates as refected
in net metering.
Two important issues have been lost in
the debate. First, there has to be a care-
ful accounting ofthe true costs ofthe
current policy and its impact on other
customers. Second, it is time to bring net
metering in line with sound ratemaking
and consumer-oriented policies.
Net metering should not be pursued to
support the solar industry and its ability
to make a profit. Rather, policymakers
and regulators should focus on ensuring
that solar customers pay their share of
the grid costs.
Non-solar customers should not end
up paying the solar customers' share of
grid costs. Renewable energy policies
should be designed to allow all forms of
non-polluting resources to compete on a
level playing field. EE
Endnotes:
l. A report for the Louisiana Public Service
Commission found thar net merering custom-
ers within the commissiont jurisdiction had
median household income of60,460 dollars
rclative to the statewide median household
income of only 44,673 dollars. David Dis-
mukes, Estimating the Impact of Net Metering
on LPSC Jurisdictional Customers, Draft, Feb-
rvry 27,2015. Other studies in Arizona,
Nwada, and California have con-
6rmed this result.
2. While electriciry prices and mtes ury widely in
the U.S., this retio berween genemtion supply
and distribution seryie is typicd.
3. Commens of theJoint Utilitia, Reforming
Encrgy Vision, Case 14-M-1010, Track Two
Commcns. The New York commission lifud
the six percent peak encrgy ep on net metoing
6r all New York utilities in December 2014, in
Cuc 15-E-0407.
4. Southun California Edison Companyt U 338-E
Amended Comments on Propored Drcision
Adopting Successor to Net Enagy Metering
TariffJanuary 11, 2016,R14-07-002. Exhibit No. 5
Case No. IPC-E-17-13
T. Tatum, IPC
ocToBER 2016 PuBUcUfluflEsFonrucllTry 33 page 5 of s
I
Ii
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t
a
Ex
every rssue
\
L"-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
cAsE NO. IPG-E-17-13
IDAHO POWER COMPANY
TATUM, DI
TESTIMONY
EXHIBIT NO.6
Net Meter Application
Maximum Size:25 kW Residential/1@ kW Commercial
This Net Metering application is an interconnection request for existing accounts to apply for Net Mct€ring Jt-
tJ;
Idaho Power Conrpany's Rate Schedule 84 within the States ofldaho and Oregon.A complaed application and deposit will initiate thc procass for ldaho Power to review the physicat location and existing ldaho Power
facilitics to deliver the customer's excess energy (wind" solar, hydro, biomass and fuel cell tcchnologics) from the customer met€r.
For additional information, go to lrtto://wrvw.idatrooower.cornlnc*net$ing.* Requircd Fields
1.lnformatlon
,r:llDu0
N!FO'I'ER"
a. Account Holdef h. Project Size kW'
b. Account Numbed
c. Project Name
d. Pnoposed ln-Service Date (mm/dd/yyyy)'
e. Total Name-Plate Rating (in kW) of Existing Projects at this Site,
if any:*
i. Proiec{ Type'
fl Sotar EIwino E other(describe):
EN ENE EIs EsE Esw Ee Ew
tf fixed, apprcimate tilt fom hodzontal _
Tracker? [Ves [Ho
lf wlnd:
Number of Turbines: _
Turbine Manufacturer:
lf solar:
Number of Modules:
Orientation:
f. Existing Meter Numbef
lnverter Model Number:
lnverter Size (watts):
ls inverterUL 1741or lEEEl54T listBd? EIyes E ruo
lf no, what prctection type
j. lnvertef
lnverter Manufacturer:
g. Please indicate if proposed system is single phase or three
phase:'
2.Location
3. EIO0 non-refundable appllcatlon fee enclosed. E
4.Contact
5. Aceount Holder
City-zlP*Slate*
Company*
lContact'
Mailing Address City State zlP
Phone (xxr) xxx-xxxx*
lraxtxlm-uxx ]e-ruair
- E I ertiry that the information provided in this application is conecl to the best of my knowledge.
* E I underEtand lhat the net metering service - including the curent rate structure and interconnection requircments - is subjec{ to
change and that cunent rates do not represent a guarentee of future pricing.
' fl I give my permission br ldaho Power to disctss my project with the Project Contact listed above.
flype or Print)r
Phone (xru) xxx-xxxxr E-Mailt
loate
{mmluaryryvY
Once completed, please mail thls
form and tlre non-rofundable
3't00 appllcatlon feo to:
U.S. Postal delivery:
ldaho Power Company
Attn: lnterconnection Application
Load Serving Operatlons
P.O. Box 70
Boise, lD 83707
Express delivery:
ldaho Power Company
Attn: lnteronnection Application
Load SeMng Operations
1221 West ldaho Street Boise, lD
83702
lf you have any queetions, please call 20&38&2559 or e-mail nsltletstlpg&f{.hgpqr.{rcom.
oEL 326 (12lr8)
Exhibit No. 6
Case No. IPC-E-17-13
T. Tatum, IPC
Page 1 of 1
rPc
lSiSnatue'
BEFORE THE
IDAHO PUBLIG UTILITIES COMMISSION
GASE NO. IPG.E.17.13
IDAHO POWER COMPANY
TATUM, DI
TESTIMONY
EXHIBIT NO.7
From: [e-mail] Imailto:[e-mail]
Sent:
To:
Cc: Net Mete ring <[e-mail]!>
Subject: Net Metering lnstallation
ldaho Power is providing written confirmation of your compliance with the current applicable requirements of
Schedule, 84, Schedule 72 and the Generation lnterconnection Process.
As of 6/6/2017, ldaho Power Company confirms the Net Metering installation located at _ has
completed the cunent requirements of these schedules and is authorized to begin operations. Please check
with your installer for instructions on how to energize your system.
Within Schedule 84 and T2there are various ongoing requirements that must be maintained. These include:. Providing access to ldaho Power for ongoing inspections. Notifoing ldaho Power of any system changes or closure.. Submitting a new application for system expansions or relocation.
These schedules can be found at idahopower.com/netmetering. Any lapse in these ongoing requirements
may result ldaho Power exercising its right to disconnect the Net Metering lnstallation as specified within
these schedules.
Schedules 84 and 72have been approved by the ldaho Public Utilities Commission and the Oregon Public
Utility Commission (Commissions). Tariff schedules (including rates and system requirements) are subject
to change pursuant to a Commission order. ldaho Power will notify the customer of record of any future
modifications to the schedules that may impact the customer.
lf you have any questions, please contact us at [phone] or email us at
netmeterinq@idahopower. com.
Sincerely,
ldaho Power Net Metering Team
1
Exhibit No. 7
Case No. IPC-E-17-'13
T. Tatum, IPC
Page 1 of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-17-13
IDAHO POWER COMPANY
TATUM, DI
TESTIMONY
EXHIBIT NO.8
Net
tvletering
What You
Need to Know Exhibit No. 8
Case No. IPC-E-17-13
T. Tatum, IPC
Page 1 of6
/
,/ ,/
/
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!
ldaho Power welcomes
your interest in solar and
renewable generation.
Under our net metering tariff,
customers can install their own
renewable generation source"
(commonly solar panels)to offset
their use.
When customers generate more
than they consume, the electric
meter "spins" backwards, providing
a kilowatt-hour (kWh)credit for
energy produced, offsetting energy
consumed. Systems connected
to the grid are referred to as
"interconnected."
Whp Can Apply?
Residential (Schedule 1) and small
commercial (Schedule 7) customers
may connect up to 25 kilowatts (kW)
of generation. All other rate classes may
connect up to 100 kW of generation.
ResidentialTime Of Day customers (Schedule 5)
may not participate in net metering.
,t
'T
T. Tatum, IPC
Page 2 of 6
I
Under net metering, customers generate their ovrin
electricity, com monly with solar. Wind, hydropower,
geothermal and fuel cells may also be used.
The power is first consumed by the home. Any
excess is fed back to ldaho Porrver s electrical grid.
lf your home requires more electricity than your
system is generating, you'll still draw electricity from
ldaho Power.
For customers that generate more than they use
in a given month, a kWh credit will appear as a
line item on their bill. Credits do not expire and can
be rolled over month to month. Even if you eam a
credit, you will still receive a bill for monthly service
fees and other charges not tied to energy use.
Please note, the rules for net metering, credits and
rates are subject to change. Any changes to the
tariff require approval from the state public utilities
commission.
The nameplate capacity of your system - multiplied
times the hours pu expect it to operate - will give
pu a rough idea how much the s)6tem can produce.
The chart below gives you approximate annual
outputs for various sized s)6tems. For comparison,
register for myAccount at idahopower.com to find
out horru many kWh your home uses in a year.
lkW
3kW 4,366 kWh/year
5kw
7kW
10 kw
*Data shown for Boisg lD based on PVWatts using default parameters.
Assumes ideal conditions forfixed anay, anaytilt 20'; Anay Azimuth 180",
system losses 14%; lnverter efficiency 96%; DC to AC Size Ratio 1.1.
To understand horyour home
uses energy, visit myAccount, ldaho
Power's online portalto manage
your energy [Ise.
Wth myAccountyou can payyour
bill, get account information and under-
stand your use. A benchmarking tool
allous pu to enter information about
pur home and compare itto similar
homes throughout our service area.
Tip are prwided on ways to save.
We encounge you to registertoday.
l
1,455 kWh/year
7,276 kWhlyear
10,187 kWh/year
14,552 kWh/year
System Size Solar Output
Exhibit No. 8
How Does it Work?How Much Will I Produce?
I e
t
b
!
-1
T. Tatum, IPC
Page 3 of 6idahopower.com/netmeteri ng
I
Step 1: Although not required, a great first step is to
find an installer familiar with ldaho Powe/s processes
to help you determine what type and size of system
you want and what the best configuration for it is.
ldaho Power recommends getting at least three bids.
A good installer should be able to help you:
o Estimate your annual energy needs and
select a system to meet those needs.
. Explain what to expect from your system
in terms of output throughout the year.
. Understand ldaho Poruer's process for
interconnection including the set up,
paperuvork and timelines.
Step 2: Submit a net metering application and
$100 application fee. This application asks for details
about your proposed system, including system size
and inverter type. ldaho Porruer will review it within
10 business days and let you know if any service
upgrades are needed to accommodate your system.
Any upgrades are at the expense of the customer.
Step 3: lnstallyour system. Systems must be
installed according to all applicable codes and rules,
and they must pass a state electrical inspection.
Step 4: Submit final papenruork to ldaho Power.
Once received, within 10 business days, ldaho Power
will conduct a site visit to ensure the system meets
the company's tariff requirements.
After the inspection, ldaho Pornrer will install a
new meter and change your account over to a net
metering rate within 15 business days.
Exhibit No. I
What are the Steps?
T. Tatum, IPC
Page 4 of 6
I
{
I
II
II,IVEIIER USCONNKT BRTAKER MEIER
The rules for net metering have been designed for
your safety and the safety of ldaho Porruert crews
and equipment. They indude:
. An inverter that meets the IEEE 1547
standards. lnverters with a UL 174'l
generally meet this standard.
. A disconnect on the customer side of
the meter. This disconnect must be
accessiblg visible and lockable.
. Successful completion of a state electrical
inspection.
For complete rules, applications and more, visit
idahopower.com/netmeteri n g.
PV ARRAY
General Requirements
a
r
Green Power
_..r.1i,:,1,,.., ,.'Ao
solar lalnlschools
Whether you're ready to install solar or not, you can
still support renewable energy. ldaho Power's Green
Power program is a voluntary program for customers
wishing to offset their electrical use with renewable
energy.
Participants designate a monthly purchase amount,
which is used to buy certified renewable energy
certificates (RECs)from large norfrwest wind farms.
RECs represent one megawatt hour of renewable
energy delivered to the regional porrver pool (the grid)
on your behalf. For the average customer using
1,000 kwh a month, it costs just $8.50 to purchase
1,000 kwh of Green Power. This reduces green-
house gas emissions equivalent to 1.54 cars driven
for one year.
The Green Power funds are also used to support
Solar 4R Schools. ln partnership with the Bonne-
ville Environmental Foundation, Solar 4R Schools is
designed to educate K-12 students about renewable
energy by placing solar PV installations on school
properties throughout our service area. The installa-
tions come with a weather station, data monitoring
and classroom cuniculum designed to meet state
education standards. As of April 2016, lTschools
in ldaho Powert service area have been
awarded installations.
For more information
about the Green Power
program, visit our
website.
nr l5-nr
lttlL*r-ir @FY"-"r-
fU|
I
-l=rtllire<rsrr
T. Tatum, IPCidahopower.com/g reenpovuer Page 6 of 6