20151113Ehrbar Direct in Support of Stipulation.pdf

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DAVID J. MEYER
vrcE ,RESTDENT AND cHrEF couNSEL FoR ,'r'J,?ffi*#|;,hi8u,o*
REGULATORY & GOVERNMENTAL AFEAIRS
AVISTA CORPORATION
P.O. BOX 3727
1411 EAST MISSION AVENUE
SPoKANE, WASHTNGTON 99220-3727
TELEPHoNE: [phone]L6
EACSIMILE: [phone]
DAVI D . MEYERGAVI STACORP . COM
BEBORE EIIE IDNIO PT'BI,IC UITILI.|IIES COMMISSION
IN THE MATTER OF THE APPLICATION ) CASE NO. AVU-E-15-05
OF AVISTA CORPORAT]ON FOR THE ) CASE NO. AVU-G-15-01
AUTHORITY TO INCREASE ITS RATES )
AND CHARGES FOR ELECTR]C AND ) D]RECT TEST]MONY
NATURAL GAS SERVICE TO ELECTRIC ) OF PATRICK D. EHRBAR
AND NATURAL GAS CUSTOMERS IN THE ) IN SUPPORT OF THE
STATE OF IDAHO ) STIPULAT]ON AND
) SETTLEMENT
FOR AVISTA CORPORATION
(ELECTRIC AND NATURAL GAS)
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I. INTRODUCTION
9. PJ.ease state your name, em;rloyer and business
address.
A. My name is Patrick D. Ehrbar and I am employed
as the Manager of Rates and Tariffs for Avi-sta Utilitles
("Company" or "Avista"), at 7411- East Mission Avenue,
Spokane, Washington.
A. Have you previously fiJ.ed direct testimony in
this proceedingr?
A. Yes. My testimony in this proceeding covered
the spread of the proposed electric and natural gas
revenue increases among the Company's electri-c and
natural gas general service schedules. My testimony also
described the changes to the rates within the Company's
electric and natural gas service schedules, as weII as
the Company's proposed electric and natural gas Fixed
Cost Adjustment Mechanj-sms.
A. I[hat is the scope of this pre-fi1ed testimony?
A. The purpose of my testimony is to descrj-be and
support the non-revenue requirement portions of the
Stipulation and Settlement ("Stipulation"), filed on
October 16, 2015 between the Staff of the Idaho Public
Utilities Commj-ssion ("Staff'), Clearwater Paper
Corporation ("Clearwater"), Idaho Eorest Group, LLC
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("Idaho Forest"), the Community Acti-on Partnership
Association of ldaho ("CAPAI"), the Idaho Conservation
League ("Conservation League"), the Snake River AlLiance
("Snake River") and the Company. These entities are
collectively referred to as the "Partiesr" and represent
several- parties in the above-referenced cases.
In my testimony I will explain the following
Settlment components:
1. Rate Spread and Rate Design
2. Fixed Cost Adjustment Mechanisms
3. Other Settl-ement f tems
I wlll also provide an overview of the Company's customer
service programs.
A. Are you sponsoring any e:rhibits?
A. No, I am not. Company witness Ms. Andrews is
sponsoring Exhibit No. L, which is a copy of the
Stipulation and Settlement filed on October 16, 2015,
with the Commission.
II. RATE SPREAD T RATE DESIG,IJI
A. Please e:rplain the settlement terms relating to
cost of service.
A. Eor el-ectric operations, the Company prepared a
cost of service analysls uslng a system load factor
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method of classifying production costs, allocating 1008
of transmissj-on costs to demand, and allocating
transmission costs on a twelve-month basis.For
settlement purposes, the Parties agreed to use a pro-rata
allocation based on the Company's proposed 252 move
towards unity for purposes of spreading the revised
el-ectric revenue requirement, while not agreeing on any
particular cost of service methodology.
Eor natural gas operations, the Company proposed
that all rate schedules be moved approximately 338
towards unity. For settlement purposes, the Partles
agreed to use a pro-rata allocatj-on of the Company's
natural- gas rate spread percentages from its original
filing for purposes of spreading the revised revenue
requi-rement.
C. Hor did the StipuJ.ation address rate desigm?
A. For settlement purposes, the Parties have
agreed that the revenue requirement for each electric
and natural gas service schedule would be applied as a
uniform percentage increase to each volumetric energy
rate, ds shown in Appendix D of the Stipulation provided
as Ms. Andrew's Exhibit No. 1. While there would be no
change to the residential electric Schedul-e 1- monthly
basic charge, the Parties agreed that the natural gas
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Schedule 101 monthly basic charge would
$1.00 per month, from $4.25 to $5.25.
increase by
Appendix D of the Stipulation (Andrews Exhibit No.
1) provides a sunrmary of the current and proposed rates
and charqes for electric and natural- gas service.
A. Wou1d you please erctrrJ.ain how the StipuJ-ation
addresses the present electric rebate customers are
receiving in 2015.
A. Yes. Through rate Schedule 97 , customers are
receiving a rebate of $0.00091 per kwh for 20L5
(approximately $2.8 million) . This rebate rate was
first approved in the Company's 20L2 general rate case,
Case No. AVU-E-12-08.
As a part of the settlement stipulation approved by
the Commission in Case No. AVU-E-14-05, the rebate was
extended through December 31, 20L5 using the 20L3
electric earnings sharing deferral.
For 2014, Avista deferred approxi-mately $5. 6
million under the electric earnings sharing. The Parties
have agreed to use the $5.6 million deferral balance
from 20L4 and extend the Schedule 97 rebate rate for
2016 and 2071. This information is shown on Appendix E
to the Settlement Stipulation (Andrews Exhlbit No. 1).
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the
in
A. Please e:q>J.ain
present natural gas
hor the StipuJ.ation addresses
rebate cugtomers are receivingr
2015
A.Through rate Schedule 197,customers are
therm throughreceiving a rebate of $0.0L489 per
December 31, 201,5 (approximately $1.2
rebate rate was first approved in the
million)This
Company's 20L2
general rate case, Case No. AVU-G-L2-0'7.
As a part of the settlement stipulation approved by
the Commission in Case No. AVU-G-14-0L, the rebate rate
was extended for 201,5 using the 20L3 natural gas
earnings sharing deferralr Ers well as the Schedule 191
Natural Gas Energy Efficiency funding bafance.
For 2074, Avista deferred approximately $0.2
mil-l-ion under the natural gas earnj-ngs sharlng. The
Parties have aqreed to use the $0.2 million natural- gas
deferral- balance from 20L4 to partially offset the
expiration of the $1.2 mil-l-ion rebate that will occur on
January 7, 2016. This informatlon is shown on Appendlx
E to the Settlement Stipulation (Andrews Exhibit No. 1).
A. What is ttre effect on retaiJ. rates, by rate
schedule, of the proposed settJ.enent?
A. The following table reflects the agreed-upon
percentage increase by schedule for electric service:
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Rate Schedule
Residenthl Schedule I
General Service Schedules 1ll12
Large General Service Schedules 21122
Eltra large General Service Sctreduh 25
Cleanvater Paper Scheduh 25P
Punping Service Schedules 31132
Steet & Area Lights Schedules 4l-48
Overall
lncrcase in Base Increase in
Rates Bi[ins Rates
0.9%
0.5%
0.6%
0.6%
0.4%
0.7%
08%
9'1%
0.9%
05%
0.6%
0.6%
0A%
0.7%
0.8%
9'1Ye
The following table reflects the agreed-upon percentage
increase by schedule for natural gas service:
Incrcase in
Base Rates
Increase in
Billing Increase
Net of New &
I I Rate schedule
lZ General Service Schedule l0l
[,arge General Service Scheduhs llllll2
13 Intemryt. Sales Service Schedules l3lll32
Transportation Servbe Schedule I 46*
14 ovelall
Billine Rates Expirine Rebate
7.7o/o
3.7%
7.5%
s.2%
6S%
4.1%
1.5%
2.7%
5.2%w
5.3%
3.1%
4.8%
3.1%
4.8%
* excludes commodity and interstate pipeline transportation costsl5
16 A. What aae ttre residential. biJ.J. irqracts if the
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Comission approves the SettJ.enent Stipulation?
A. An electric residentia1 customer using an
average of 929 kilowatt hours per month woul-d see a
$0.75, or 0.9?, increase per month for a revised monthly
bill of $85.74.
A natural gas residential- customer using an average
of 6l therms per month would see a $3.19, or 5.42,
increase per month for a revised monthly bill of $62.4L.
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III. FIXED COStr ADJUSIAE}iM MECIIA}IISMS
A. P1ease e:<plain the sett1enent tercms relating to
the Fixed Cost Adjustment ("FClil"'1 Mechanisms.
A. The Stipulation i-ncludes el-ectric and natural
gas FCA mechanisms. The ECA is a mechanj-sm designed to
break the link between a utility's revenues and a
consumer's energy usage. The Company's actual- revenue,
based on kllowatt-hour and therm sal-es, will vary, up or
down, from the level set by the IPUC. This could be due
to changes in conservation, weather or the economy.
The Parties have agreed upon a Revenue-Per-Customer
FCA for electric and natural gas operations. The FCA
will compare actual ECA revenues to allowed ECA revenues
determined on a per-customer basis, wj-th any differences
deferred for later rebate or surcharge. Customers in the
FCA will be segmented into Rate Groups (Residential and
Non-Residential), and further categorized as either
"Existinq Customers" or "New Customers. "
9. Wtrat is the term of the FCA Mechanisms?
A. The Parties agreed to an initial FCA term of
three years, with a review of how the mechanisms have
functioned conducted by Avista, Staff, and other
interested parties following the end of the second fuII-
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year. Avista may seek to extend the term of the
mechanism prior to its expiratj-on.
A. You mentioned that customers wiJ.J. be combined
into Rate Groups. Please oq>J.ain.
A. The Parties have agreed to combine customers
into Rate Groups. For the Electric FCA, customers would
be inc1uded in one of two Rate Groups:
1. Residential - Schedule 1
2. Commercial Schedules L1, 12, 2\, 22, 31, and
32
For the Natural Gas ECA, customers would be included
in one of two Rate Groups:
1. Residential - Schedule 101
2. Commercial - Schedules 111 and 112
A. Why were certain customers excluded fron ttre
agreed-upon mechanisms?
A. For the electric ECA, Street and Area Lighting
customers served on Schedul-es 41"-49 were excluded because
the fixed costs to serve them are recovered in their flat
monthly rates, and therefore fixed cost recovery is not
dependent upon customer usage.Extra Large General
Service Schedule 25 and Extra Large Generaf Service to
Clearwater Paper Schedule 25P were excluded from the
mechanism primarily because these customers tend to be
higher load factor customers. With a higher load factor,
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the Company bel-ieves that the recovery of fixed costs
from these customers is less volatile versus the other
schedules, and as such inclusion in the FCA at this time
is not necessary.
In addition, for these large-use customers, Avista
has more direct contact with these customers regarding
future plans that may increase or decrease their Ioads.
These changes in retail 1oad, whether they be related to
energy efficiency measures or for other reasons, are
easier to identify and reflect in a qeneral rate case,
than for other rate schedules that have a large number of
lower-usage customers .
For the natural gas ECA, the Parties have agreed to
remove Schedules 131 and 132 from the mechanism because
only one customer was served on these schedules in the
test year.'EinaIly, Schedule 1,46 transportation
customers were not included in the design of the FCA
because, like Schedule 25 customers, they tend to have
l-ess vol-atile usage (higher l-oad factor) , and future
changes in their usage are more easily identified and
reflected in general rate filings.
1 The one Schedule 1,32
servi-ce to firm service
customer recently moved from interruptible
under Schedule 112.
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A. Have you prepared a siryJ.ified cal.cuJ.ation
stroring hor the FCA mechanisa works?
A. Yes. While the components of the electric and
natural gas FCA mechanisms are il-lustrated in Appendices
B and C of the Settl-ement Stipulation (Andrews Exhibit
No. 1), Tab1e No. 1 below is an ill-ustrative example of
how the electrj-c mechanism works. The example is for
only January 20L6, and provides the base authorized
values as well as the calculation of the monthly deferral
usj-ng an illustrative number of customers, energy usage,
and actual monthly revenue.
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a
b
c
d
e
trab1e No.
January 2016 Authorized Values
January FCA Revenue per Customer
Basic Charge
Load Change Adjusfrnent Rate
January # of Customers
January # of kWh Sales
January 2016 Actual Resufts
Actual January # of Customers
Less New Customers*
Actual January # of Existing Customers
FCA Revenue Per Customer (Authorized)
FCA Revenue (Authorized)
Actual January Existing Customer Revenue
Actual January kWh Usage
Basic Charge Revenue
Variable Production/Transmission Revenue
FCA Revenue (Actual)
p January Surcharge/@ebate)
Revised November 23, 2015
Electric Fked Cost Adjustment Mechanism -
Sample Calculatio n fo r Residential Customers
f
oE
h
Source
Appendix B, P.3, L.15
Appendix D, P. 2
Appendix B, P.l, L.5
Appendix B, P.2
Appendix B, P.3, L.3
Source
Illustrative
Illustrative
: f-s
:h*i
Illustrative
Illustrative
--b*h
--l*c
:k-m-n
:j-o
January 2016
Authorized
$81.83
s5.25
s0.02281
102,923
131,9&,665
January 2016
Example
103,300
175
103,125
$81.83
$8,438,719
s12,000,000
132,000,000
$541,406
s3,010,920
$8,M7,674
($8,955)
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n
o
* New custonrcrs will be tacked using a differerf FCA Revenue Per Customer as agreed to in ttre Stipulation
The illustrative example provided above would be
simil-ar for natural gas customers. The components for
the natural gas FCA are provided in Appendix C to the
Stipulation (Andrews Exhibit No. 1).
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A. IIould you please describe how Existing
Custoners and Ner Customers rould be treated in the FCA
meehanisms?
A. Yes. The Parties have agreed that revenue
related to certain items discussed bel-ow would not be
included in the FCA for new customers. The result is
that the Fixed Cost Adjustment Revenue-Per-Customer for
new customers will be less than the Eixed Cost Adjustment
Revenue-Per-Customer for existing customers. For new
electric customers added after the test period, recovery
of incremental revenue related to fixed production and
transmissi-on costs would be excl-uded f rom the electric
FCA. For new natural- gas customers added after the test
period, recovery of incremental- revenue related to fixed
production and underground storage facillty costs would
be excluded. These modifications are inc]uded in
Appendices B and C to the Stipulation (Andrews Exhibit
No. 1) .
A. PJ.ease describe how Avista wiJ.J. report on ttre
mechanisms.
A. Avista will file, wJ-thin 45 days of the end of
each quarter, a report detaiJ-ing the FCA actlvity by
month. The reporting wilI afso inc1ude information
related to the deferrals by rate group, what the
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deferrals would have been if tracked by rate schedule,
use and revenue-per-customer for existing and new
customers, and other summary financial information.
Avista will provlde such other information as may be
reasonably requested, from time to tj-me, in the future
quarterly reports.
A. Please provide information related to when
the Company would fiJ.e for a rate adjustnent under the
proposed FGA.
A. On or before JuIy 1-, the Company wil-1 fil-e a
proposed rate adjustment surcharge or rebate based on the
amount of deferred revenue recorded for the prior January
through December time period. The rate adjustment would
be calculated separately for each Rate Group, with the
applicable surcharge or rebate recovered from each group
on a uniform cents per kwh or per therm basis. The
proposed tarlff (Schedule 75 for el-ectric and Schedule
1,15 for natural- gas ) included with that filing would
i-nclude a rate adjustment that recovers/rebates the
appropriate deferred revenue amount over a twel-ve-month
period effective on October 1 for el-ectric (to match with
Power Cost Adjustment and Residential Exchange annual
rate adjustments time period), and November l-st for
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natural gas (to match with the annual Purchased Gas Cost
Adjustment rate adjustment time period).
The deferred revenue amount approved for recovery or
rebate would be transferred to a balancing account and
the revenue surcharged or rebated during the period would
reduce the deferred revenue in the bal-ancing account.
After determining the amount of deferred revenue that can
be recovered through a surcharge (or refunded through a
rebate) by Rate Group, the proposed rates under Schedules
'75 and L15 would be determined by dividing the deferred
revenue to be recovered by Rate Group by the estimated
kWh sales (Electric FCA) or therm sales (Natural Gas FCA)
for each Rate Group during the twefve-month recovery
period.
Any deferred revenue remainj.ng in the balancing
account at the end of the amortization period would be
added to the new revenue deferrals to determine the
amount of the proposed surcharge/rebate for the following
year.
A. Wou1d you describe the accounting for the
proposed eJ.ectric and natural. gras FCA?
A. Yes. Avista will record the deferral- in account
186 - Miscellaneous Deferred Debits. The amount approved
for recovery or rebate would then be transferred into a
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Regulatory Asset or Regulatory Liability account for
amortization. On the income statement, the Company would
record both the deferred revenue and the amortization of
the deferred revenue through Account 456 (Other Electric
Revenue), or Account 495 (Other Gas Revenue), j-n separate
sub-accounts. The Company would fil-e quarterly reports
with the Commission showing pertinent information
regarding the status of the current deferral. This
report wouLd include a spreadsheet showing the monthly
revenue deferral- calculation for each month of the
deferral period (January - December), as well as the
current and historical monthly balance in the deferral
account.
A. Yes, interest will be accrued on the
unamortized balance in the FCA balancing accounts at
the Customer Deposit Rate.2
A. Is there an agreed-upon limitation as to the
a.mount of an FCA surcharge?
A. Yes. An FCA surcharge, by rate group, cannot
exceed a 3? annual rate adjustment, and any unrecovered
a. wi].].
ba].ance?
2 Based on Order No.
rate for 2015 is 1.0%.
interest accrue on the unanortized
33187 in Case No. GNR-U-14-12, the deposit
The rate is updated annua11y.
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balances
recovery.
rebate.
wil-l- be carried forward to future years
There is no limit to the l-evel of the
for
ECA
IV. OTHER EI,EDIEIITS OF TIIE SIIIPT'I,ATION
A. P1ease e:q>J.ain the settlement ter:ms relating to
the PCA authorized leve1 of e:<penses.
A. The new level- of power supply revenues,
expenses, retail l-oad and Load Change Adjustment Rate
resulting from the January 1-, 2016 settfement revenue
requirement for purposes of monthly PCA mechanism
calcul-ations are detailed in Appendix A of the
Stipulation (Andrews Exhibit No. 1).
O. P1ease e:qrJ.ain the customer service-related
issues agrreed upon in ttre Settleuent Stipulation.
A. The Parties have agreed upon two customer
service-rel-ated issues. First, the Company and interested
parties will meet and confer prior to the Company's next
general rate case in an effort to identify low income
customers served by the Company, quantify the number of
customers so identified, and determlne those customers'
usage patterns. An initial- meeting shall occur no later
than June 30, 20L6, with follow-up meetings to occur as
the attendees may deem approprJ-ate.
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Second, the Company and interested parties will meet
and confer prior to the Company's next general rate
filing in order to assess the Low Income Weatherization
and Low Income Energy Conservation Education Programs and
dlscuss appropriate levels of cost-effective, low-income
weatherization funding in the future. An initial meetingr
shaII occur no l-ater than June 30, 2016, with follow-up
meetings to occur as the attendees may deem appropriate.
V. CUSTOMER SERVICE PROGRN4S
A. Does the Coryany have prograns in place to
mitigate ttre impacts on customers of the proposed rate
increases?
A. Yes. We have a history of making it a priority
within our Company to maintain meaningfuJ- programs to
assist our customers that are l-east able to pay their
energy bi1ls. Vie also have programs to assist our entire
customer base, L.e., not just our low-income customers.
Some of the key programs that we offer or support are as
follows:
o DStrvI Energy Efficieney Prograns and Ftrnding. The
Company offers a broad array of energy efficiency
program measures that provide customers with
increased opportunity to manage their energy bil-ls.
fn 201,5, Avista has hosted two Energy Fairs, one in
Lewi-ston, and the other in Post Falfs. Over 500
customers were in attendance and received energy
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efficiency tips and kits that included l-ow cost/no
cost ways to reduce energy consumption.
Project Share. Project Share is a voluntary program
allowing customers to donate funds that are
distributed through community action agencies to
customers in need. In the 201,4/201,5 heating season,
Avista Utilities' customers, employees and Avista
Corp donated $1,23,528 which was directed to Idaho
Community Action Agencies.
o Comfort Level Bi].].ing.The Company offers the
option for all customers to pay the same bill amount
each month of the year by averaging their annual
usaqe.Under this program, customers can avoid
unpredictable winter heating bill-s.
Payrment Arrangements. The Company's Contact Center
Representatives work with customers to set up
payment arrangements to pay energy biIIs.
C.ARES Progra'n. Customer Assistance Referral and
Eval-uation Servj-ces provide assistance to speclal-
needs customers through access to specially trained
(CARES) representatives who provlde referrals to
area agencJ-es and churches for help with housing,
util-ities, medical assistance, etc.
Senior Energy Outreach: Avj-sta has developed
specific outreach efforts to reach our more
vulnerable customers (seniors and dlsabled
customers) with bilI paying assistance and energy
efficiency information that emphasizes comfort and
safety. Some examples of this effort are as follows:
. Senior Publications: Avista has created a
one-page advertisement that has been placed
in senj-or resource dj-rectories and targeted
senior publications to reach seniors withj-nformation about energy efficiency, Comfort
Level- Billing, Avista CARES and energy
assistance.A brochure with the sameinformation has also been created fordistribution through senior meal delivery
programs and other senior home-care programs.
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Senior Energy Workshops: With the help of
the Avista Conservation Energy EducationTeam, 5 Energy Workshops have been
faciLitated in 20L5, with more to come later
thls year. Approxj-mate1y, 150 seni-ors and
l-ow-income individual-s were reached and given
Home Energy Saving kits along with learning
about 1ow-cost/no-cost ways to reduce energy
use.
tftis concJ.uds your pre-fiJ.ed direct
A. Yes,it does.
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