20100611AVU to Staff 71-78, 80-88, 90-91, etc.pdf

Avista Corp.
1411 East Mission P.O. Box 3727
Spokane. Wgshington 99220-0500
Telephone [phone]
Toll Free 800-727-9170
J.~~'V'STA.
Corp.
Zoin ii llJ... l I.V'¡.'; v..,1'l f 10: i i
June 10,2010
Idaho Public Utilities Commission
472 W. Washington
Boise, il 83702-5918
Attn: Donald Howell & Krstine Sasser
Deputy Attorneys General
Re: Production Request of the Commission Staff in Case Nos. A VU-E-1 0-01 and
AVU-G-10-01
Dear Mr. Howell and Ms. Sasser,
ìEnclosed are an original and one copy of Avista's responses to IPUC Staffs production requests
in the above referenced docket. Included in this mailing are Avista's responses to production
requests 071 - 078, 080 - 088, 090, 091, 096, 100 and 101. The production requests are also
being provided in electronic format on the CDs included in this mailing.
If there are any questions regarding the enclosed information, please contact me at (509) 495-
4584 or via e-mail atpaul.kimabll(qavistacorp.coms;:¿
Paul Kimball
Regulatory Analyst
Enclosures
CC (Email): all paries electronic
.
.
.
JUSDICTION:
CASENU:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-1O-01 / AVU-G-10-01
IPUC
Production Request
Staff-071
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/07/2010
Elizabeth Andrews
Jennifer Buss
State & Federal Reg.
(509) 495- 2098
Please demonstrate that investors supply the working capital fuds for the utility to operate durng
the lag period (reference Staff Production Request No. 16).
RESPONSE:
As stated in StaffPR#16, the Company did not perform a lead-lag study (providing support that
investors supply the working capita fuds for the utility to operate durng the lag period), as 45
days is the generally accepted lag days used by FERC. However, since filing our response to Staff
PR#16, the company has contracted with a consultant, Tangibl, LLC to perform studies related to
our working capitaL. The intent of the study is to perorm a lead lag study. When the study has
been completed in approximately 2-3 weeks, the company intends to provide supplemental
information to Staff Production Request No. 16.
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-10-01 1 AVU-G-10-01
IPUC
Production Request
Staff-072
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/09/2010
Kevin Chrstie
Kelly Irne
Gas Supply
[phone]
REQUEST:
In Chrstie's testimony, page 4, lines 18-21, he says "Therefore, a portion of cushion gas is
estimated to be non-recoverable from the facilty and that porton is depreciated over the estimated
life of the facility (account 352.3-Nonrecoverable natual gas)." Please explain how ths cushion
gas is valued (i.e.-original cost over the life of the facility).
RESPONSE:
The cost of cushion gas in the proforma included in Andrews workpapers is valued at the original
purchase cost over the life of the facìlty.
.
.
.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
A VU-E-1O-01 1 A VU-G-I0-0l
IPUC
Production Request
Staff-073
DATE PREPARD:WISS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/09/2010
Kevin Chrstie
Kelly Irne
Gas Supply
[phone]
REQUEST:
In Chrstie's testimony, page 7, lines 20-22, regarding the assignent of Jackson Prairie (JP)
capacity costs to Oregon customers vs. Idaho customers, he says "Ths proportion was based on
forecasted jursdictional sales volumes for the Nov. 2008 - Oct. 2009 perod." Please explain why
you used a sales volume forecast associated with a 2007 deliverabilty expansion (pERC docket
CP06-412-000), instead of using actual sales volumes or a more recent forecast. In your response,
please provide an executable electronic comparson of forecasted vs. actual sales volumes for the
Nov. 2008 - Oct. 2009 period.
RESPONSE:
Attched as StafCPR_073-Attachment A.xlsx is a comparson of forecasted vs. actul sales
volumes for the Nov. 2008 - Oct. 2009 perod as requested.
Because the Company is proposing to bring Jackson Prairie back to the utility in the futue (May
2011), the Company used forecasted demand rather than historical acfuals. When you compare
forecasted demand to actual demand, the percentage difference is inconsequential, as shown in
Attchment A.
It should be noted that ths allocation plan was discussed with the Idaho, Washington and Oregon
Commission staffs in early 2007, as well as in subsequent meetigs. As noted in Company
witness Chrstie's testimony, all thee staffs indicated support of the allocation plan.
.
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.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
DATE PREPARD:WISS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/09/2010
Kevin Chrstie
Kelly Irne
Gas Supply
[phone]
IDAHO
A VU-E-lO-Ol 1 A VU-G-I0-0l
IPUC
Production Request
Staff-074
REQUEST:
In Chrstie's testimony, page 10, lines 10-15, regarding the estimated value of the seasonal Sumas
price spread, he says "Page 1, Schedule 1 of Exhibit No. 11 shows the present monthy forward
prices at Sumas over the next thee years. These forward prices reflect the purchase price today for
gas delivered durng that futue month. As shown, the average seasonal price spread over the next
thee years is $1.79 Dth." Please explai:
a. Why you decided to use monthy forward prices over the next thee years for estimating the
value ofthe seasonal price spread.
b. Why you did not weight the seasonal price spread (including and excluding transportation) of
all the basins used to supply JP storage.
c. Why you did not use a similar weighting factor to figue 1.3 in the recent IR, or in your short
term gas procurement planng, to incorporate the spread (risk margi) built into forward
market prices.
d. Why you did not use historical seasonal prices for estimating the value of the seasonal Sumas
price spread.
RESPONSE:
a) Forward price spreads are what the Company can tranact upon, and in the Company's
opinon are the most representative estimate of the seasonal spread. Whle market prices
are available beyond thee years, that market tends to be iliquid and the abilty to transact
that far out can be diffcult.
b) Sumas is the closest trading hub to Jackson Praie. Its proximity to Sumas enables the
flow of gas with very few pipeline constraints. Other basins may include additional
pipeline charges as well as constraints reducing the physical flow of gas. For these
reasons, Sumas provides the best representative value for Jackson Prairie gas. Sumas is
also the higher priced basin and weighting other, lower priced basins into the spread
calculation would have produced greater spread values. Therefore, the $1.79 is considered
the more conservative valuation. Actual basin weighting and spread values wil be realized
though the PGA process.
c) As noted in par a above, forward price spreads are the most representative estimate of
the
seasonal spread. While market prices are available beyond three years, that market tends to
be iliquid and the abilty to transact that far out can be diffcult. The IR, however,
weights forward prices with fudamental forecasts in order to incorporate curent market
price realities with the fudamental forecaster's view of what the market could be over the
20 year horizon. The IR 's longer term focus necessitates the need to rely more heavily on
fudamental forecasts for natural gas prices. The blending used in the IR is a way to
.smooth in the effects of moving from a market based (transactable) price into the
fudamental forecaster's estimate of what prices could be in the futue. See also the
Company's response to Staff-084.
d) See a. above. Historical prices are one way to estimate the value of the seasonal price
spread; however there are many factors that can influence the natual gas market prices.
Therefore, what has happened in the past is not necessarly a measure of what could happen
in the futuê.
.
.
.
.
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JURISDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-I0-0l 1 AVU-G-I0-01
IPUC
Production Request
Staff-075
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
06/08/2010
Kevin Chrstie
Kelly Irne
Gas Supply
[phone]
Please provide all of the executable electronic workpapers used in Chrstie's testimony to estimate
the value of the seasonal Sumas price spread shown on Exhibit No. 11, Schedule 1, page 1.
. RESPONSE:
Attached as Staff_PR_075-Attachment A.xlsx is an executable electronic copy of Exhbit No. 11,
Schedule 1, page 1. It is being provided in electronic format as requested.
.
.
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JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-lO-Ol 1 AVU-G-I0-0l
IPUC
Production Request
Staff-076
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/08/2010
Kevin Chrstie
Kelly Irne
Gas Supply
[phone]
In Chrstie's testimony, page 12, lines 11-15, regarding the operational benefits storage provides,
he says "Ths flexibilty is critical to maintang mandated tolerances on pipelines and allows for
active supply management durng pipeline entitlements and operational flow orders. This level of
management reduces the likelihood of incurng pipeline penalties." In executable electronic
format, please provide the number, date, and duration of entitlements and operational flow orders
over the last 10 years. As par of your response, explain how storage has been utilzed in these
situations to avoid pipeline penalties
RESPONSE:
Attached is a schedule of Nortwest Pipeline's notices of entitlements and operational flow orders
back to 2007 (see StafCPR_076-Attachment A.xlsx). In discussions with Nortwest Pipeline,
data prior to 2007 was not readily available, if at all.
As stated in Chrstie's testimony, page 12 lines 6-15, "Operationally, storage provides the
flexibility to adjust supply either up or down durng the actual day. Normally gas is scheduled one
day in advance. Jackson Praie storage allows Avista the flexibilty to increase or decrease the
supply several times durng the actual gas day. Ths flexibilty is crtical to maintaing mandated
tolerances on pipelines and allows for active supply management durng pipeline entitlements and
operational flow orders. This level of management reduces the likelihood of incurg pipeline
penalties. "
.
.
.
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.
.
.
Entitlement Notices
Source: Norlhwest PipelineDate Called Date Ended Location
1/9/2007 1/18/2007 Wennatchee Lateral
1/9/2007 1/18/2007 Kemmerer north
1/10/2007 1/17/2007 Grants Pass, Spokane Lateral
1/1712007 1/18/2007 Grants Pass
1/19/2007 1/20/2007 Kemmerer north
1/18/2008 1/25/2008 Kemmerer north
4/412008 4/18/2008 Kemmerer north
10/25/2008 10/31/2008 Plymouth north
11/15/2008 11/18/2008 Kemmerer north
12/13/2008 12/20/2008 Plymouth north
112112009 215/2009 Plymouth north
216/2009 2118/2009 Plymouth north
6/27/2009 7/712009 Kemmerer north
1219/2009 1211212009 Kemmerer north
12/12/2009 12/15/2009 Plymouth north
% Over/Under
8% overtakes
13% overtakes
8% overtakes
13% overtakes
13% overtakes
8% overtakes
8% overtakes
8% overtakes
5% undertakes
8% overtakes
8% overtakes
13% overtakes
5% undertakes
3% overtakes
13% overtakes
StafCPR_076-Attachment A.xlsx
Type
General
General
General
General
General
General
General
General
General
General
General
General
General
General
General
Page 3 of 3
.
.
.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
DATE PREPARD:WISS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/09/2010
Kevin Chrstie
Kelly Irne
Gas Supply
[phone]
IDAHO
AVU-E-1O-01 1 AVU-G-1O-01
IPUC
Production Request
Staff-077
REQUEST:
In Chrstie's testimony, page 15, lines 15-20, regarding how the cost of injections durg the pro
forma period are estimated, he says "Injections into storage are priced at the 'forward' gas price for
that month, i.e., the price at which gas can be purchased at today for delivery in a futue month. In
estimating the cost of injections during the pro forma period, the Company used a 60-day average
of forward prices from November 5, 2009 to Februar 1, 2010." Please explain why a 60-day
average of forward prices was used to determine the cost of injections instead of a 30-day average,
and why November 5, 2009 to Februar 1, 2010 was selected instead of some earlier timeframe
when the majority ofinjections are actually taking place (i.e.-sumer or early fall).
RESPONSE:
A 60-day average of forward prices was selected to help mitigate the potential to over-emphasize
one day's price when estimating the cost of injections. Since the Company is pro-forming in an
adjustment for storage which we are proposing to brig back to the utility in the futue, forward
prices are a relevant means of valuing the injections. The Company selected the November 5,
2009 to Febru 1, 2010 timeframe as it was the most recent pricing information at the time the
rate case was developed.
.
.
.
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-IO-Ol 1 AVU-G-lO-Ol
IPUC
Production Request
Staff-078
DATE PREPARD:WISS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/07/2010
Tara Knox
Tara Knox
State & Federal Regulation
[phone]
REQUEST:
In Knox's testimony, page 8, lines 14-17, she says "The natual gas weather adjustment is
developed from a regression analysis often years of biled usage-per-customer and biling period
heating degree-day data." Please explain why a regression analysis often years was used. As par
of your response, please include an executable electronic copy of your regression analysis.
RESPONSE:
The present methodology for determining the seasonal weather sensitivity factors was first
presented to the Idaho Commssion in Case No. A VU-E-08-01 and A VU-G-08-01. Prior to that
case the company had used five years of data in regression analysis to determine anual average
sensitivity factors applied unformly to all heating degree days throughout the year. The move to
ten years of data in the regression was a response to concerns that there were not enough data
points in the five year analysis. The winter season has four data points per year, the shoulder
season has five data points per year, and the sumer season has thee data points per year. With a
ten year regression there are at least 30 data points for each season.
Attached please find a zip fie (Staff_PR_078 Attchment A) containing the regression analysis
files used to determine the weather sensitivity factors in ths case. Due to the voluminous natue of
ths data, it is being provided in electronic format only.
.
.
.
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-10-01 1 AVU-G-10-01
IPUC
Production Request
Staff-080
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
06/07/2010
Patrck Ehrbar
Patrck Ehrbar
State & Federal Regulation
[phone]
REQUEST:
In Ehrbar's testimony, page 31, lines 4-8, regarding the proposed changes to Schedule 111, he says
"The present rates for Schedules 101 and 111 provide guidance for customer placement: customers
who generally use less than 200 thermslmonth should be placed on Schedule 101, customers who
consistently use over 200 thers per month should be placed on Schedule 111." Given gudance
for customer placement is 200 therms, please explain why the "present (breakeven) relationship
between the schedules" continues to be 192 therms. If the Company has apprehensions because of
customers shifting, please explain why it has not designated Schedule 101 as "residential" or made
slight moves toward 200 therms as the breakeven point.
RESPONSE:
Upon fuer review, it appears that the target breakeven percentage of 200 thers was
inadvertently affected as a result of the final order in the Company's 2004 general rate case
(A VU-G-04-01). Afer that case, the breakeven became 192 therms. The Company feels that
movement towards 200 thers should be made. However, signficantly changing the breakeven
level of 192 therms per month may result in unecessar shifting of customers between the
schedules. The Company wil propose to make steps in this regard in upcoming proceedings.
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-I0-01 1 AVU-G-1O-01
IPUC
Production Request
Staff-081
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/07/2010
Patrck Ehrbar
Patrck Ehrbar
State & Federal Regulation
[phone]
Please provide an executable electronic workpaper sumarzing by year, over the last five years,
the customers who have transferred between Schedule 111 and Schedule 101. As par of this
summar, please provide the anual median monthly usage and the average monthly usage of
these customers.
RESPONSE:
Please see Staff_PR_ 081-Attachment A.xlsx which is being provided in electronic format only as
requested.
.
.
.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-10-01 1 AVU-G-1O-01
IPUC
Production Request
Staff-082
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/0712010
Patrck Ehrbar
Patrck Ehrbar
State & Federal Regulation
[phone]
REQUEST:
In Ehrbar's testimony, page 32, lines 9-15, regarding the Company's proposal to change Schedule
150 concurent with the rate case, he says "The rates contained in Purchase Gas Cost Adjustment
Schedule 150 have been incorporated into the present and proposed rates." He then goes on to say
"present rates under the schedule have been zeroed-out and included in the Company's proposed
general servce tarffs." Please provide a detailed explanation and all supportng executable
electronic analyses used to support the Company's decision to zero-out Schedule 150 and include
it in base rates. In your response, please include an explanation of how gas costs in base rates wil
change, and how customers wil benefit.
RESPONSE:
Based on discussions with Staff the Company will change its proposal relating to incorporation of
the rates contained in the Purchase Gas Cost Adjustment into base rates. Therefore, the Company
would propose that all non-distrbution related costs, which would include commodity and
demand (transportation) charges, would reside in Schedule 150, Purchase Gas Cost Adjustment.
The rates listed on tarff sheets 10 1, 111, 112, 131, and 132 would only include distribution related
rates.
There is one potential byproduct of ths proposed change. While the Company does provide
shortcut sheets on its website for customers to easily determne what their biling rate is, customers
who only look specifically at the base tarff schedules (101,111,112, 131, and 132) may not notice
language directing them to other applicable tarffs which that can be additive or subtractive from
the base rate in order to determine the biling rate. If the Company's revised proposal is
acceptable, these additional applicable tarffs, including Schedule 150, could be additive. The
Company does not want customers to miss ths important provision.
Therefore, the Company is proposing to modify its existing tarffs. Attached as
"Staff _ PR _082- Attachment A" is a curent copy of Schedule 101. Highighted on that tarff is the
curent customer directives to review other applicable rate schedules. Again, this directive can be
easily overlooked by customers. "Staff_PR_082-Attachment B", however, is a revised Schedule
1 01 providing a clearer directive for customers. Ths change, which would be made to all affected
schedules (101, 111, 112, 131, 132), should address any issues in this regard.
.
.
.
I.P.U.C. NO.27
Fourth Revision Sheet 101
Canceling
Third Revision Sheet 101
AVISTA CORPORATION
d/b/a Avista Utiities
101
SCHEDULE 101
GENERAL SERVICE - FIRM - IDAHO
AVAILABLE:
To Customers in the State of Idaho where Company has natural gas service
available.
APPLICABLE:
To firm gas service for any purpose when all such service used on the
premises is supplied at one point of delivery through a single meter.
MONTHLY RATE:
$4.00 Basic charge
87.815
wtli
Minimum Charge: $4.00
SPECIAL TERMS AND CONDITIONS:
Service under this schedule is subject to . the Rules and Regulations
contained in this tariff.
Issued July 24, 2009 Effective August 1, 2009
Issued by Avista Utilities
By Kelly O. Norwood ,Vice-President, State & Federal Regulation
StafCPR_082 Attchment B Page 1 of 1
.
.
.
I.P.U.C. No.2?
Fourth Revision Sheet 101
Canceling
Third Revision Sheet 101
AVISTA CORPORATION
d/b/a Avista Utilties
101
SCHEDULE 101
GENERAL SERVICE - FIRM - IDAHO
AVAILABLE:
To Customers in the State of Idaho where Company has natural gas service
available.
APPLICABLE:
To firm gas service for any purpose when all such service used on the
premises is supplied at one point of delivery through a single meter.
MONTHLY RATE:
$4.00 Basic charge
87.815rl per therm
Minimum Charge: $4.00
SPECIAL TERMS AND CONDITIONS:
Service under this schedule is subject to the Rules and Regulations
contained in this tariff.
Issued July 24, 2009 Effective August 1, 2009
Issued by Avista Utilties
By Kelly O. Norwood ,Vice-President, State & Federal Regulation
StafCPR_082 Attchment A Page 1 of 1
.
.
.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-10-01 1 AVU-G-I0-0l
IPUC
Production Request
Staff-083
DATE PREPARD:WISS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/0712010
Patrck Ehrbar
Patrck Ehrbar
State & Federal Regulation
[phone]
REQUEST:
In Ehrbar's testimony, page 36, lines 8-14, regarding why increasing the basic charge won't send
the wrong price signal though the energy rates, he says "one might argue that a lower basic charge
results in higher commodity prices and a stronger price signal related to volume usage. However,
sending a price signal to customers though a residential rate design that contais a two tier
increasing block rate for electrc (natural gas has just one volumetrc rate) was developed just for
that reason." Please explain how the proposal to increase residential natual gas customers' basic
charge by nearly 69% and maintaining one volumetrc rate where the increase is approximately
6%, preserves the "abilty to provide price signals for conservation puroses."
RESPONSE:
The Company believes that a proper price signal is being maintained even while requesting a $2.75
increase in the basic charge. It should be noted that the Company has also requested an increase in
the volumetrc charge. As such, a slightly stronger price signal would stil be sent to customers
while allowing the Company to recover more of its fixed costs in the basic charge versus the
volumetrc rate. Furter, as I noted in my testimony and as is noted in Staffs Production Request
084, the Company's retail rate is higher than the forecasted natual gas prices at Henr Hub over
the next ten years.
It is important to note that the costs related to the distrbution of natual gas make up only
approximately 30% of a residential customers natual gas bilL. Almost 70% of the cost is related to
the procurement and transportatIon of natual gas, costs which are directly passed on to customers
through the PGA process. In short, any adjustment to the costs related to the distrbution of natural
gas, especially in the past several years, is more than dwared by the volatilty in the wholesale
market. The slight changes proposed on a biling basis to the Schedule 101 rate design would at
least maintain the curent overall price signal for conservation puroses.
.
.
.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-10-01 1 AVU-G-I0-01
IPUC
Production Request
Staff-084
DATE PREPARD:WISS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/07/2010
Patrck EhrbarlKevin Chrstie
GregRah
Energy Resources
[phone]
REQUEST:
In Ehrbar's testimony, page 37, lines 13-17, regarding the Company's proposal having adequate
price signals, he says "For natual gas, the Company included several forecasts in its 2009
Integrated Resource Plan which, for the most par, all show forecasted natual gas prices at Henr
Hub over the next ten years being lower than Avista's retail rates." Please explain the forecasts in
Figue 1.3 of the 2009 IR. Also include an explanation of how the NYX weightings were
derived and applied.
RESPONSE:
The Company reviewed several Henr Hub price forecasts durng the IR process which were
identified in Figue 6.3 in the IR. With assistance and concurence of the TAC Committee, we
selected high, medium and low price curves (sumarzed in Figures 6.411.3) to consider possible
outcomes and the impact each might have on our plang. The three fundamental price cures
selected were then adjusted to incorporate a market perspective into the forecasts by using the then
curent NYX forward price curve.
In the first year, each fudamental price cure was adjusted to reflect a weighting of 50%
fudamental price and 50% NYX price. In each subsequent year, we reduced the NYX
price adjustment by 10 percentage points, so that by the sixth year, the NYX weighting was
0%. Our selected weighting criteria was judgmentally based with the intent of captung a greater
market perspective on pricing in the early years while deemphasizing market prices in the later
years. Typically later year forward prices build in increasing pricing premiums to compensate for
perceived greater uncerainty and less market liquidity.
.
.
.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-1O-01 1 AVU-G-10-01
IPUC
Production Request
Staff-085
DATE PREPARD:WISS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/07/2010
Patrck Ehrbar
Patrck Ehrbar
State & Federal Regulation
[phone]
REQUEST:
In Ehrbar's testimony, page 42, lines 8-13, he explais that "traditional thinng might lead one to
believe that a low income electrc customer would tend to be a low user of electrcity," and then he
goes on to say "Although the Company has not conducted a demographic surey of its customers
in recent years, the limted data that we do have would suggest that just the opposite is tre."
Please provide the limited data you have in executable electronic format suggesting that "just the
opposite is tre." In your response, please explain why you have not completed a demographic
sureyor analysis to confirm your assumption.
RESPONSE:
Please see "Staff_PR_085-Attachment A.xlsx" which is being provided in electronic format only
due to its voluminous natue. What is shown in that workbook are the average kWh usage for
reguar income electrc customers versus limited income electrc customers. Limited income
electrc only customers use, on average, 14,807 kilowatt hours per year, versus 12,908 kilowatt
hours for regular income customers.
Note that the limited income population used in this analysis were deterined though customers
paricipation in LIHAP and Limited Income DSM programs. Customers paricipating in those
programs have incomes at or below 125% of the federal povert guidelines. The Company has not
completed a demographic sureyor analysis in recent years but may look to do so in the near
futue.
.
.
.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
IDAHO
A VU-E-1O-01 1 A VU-G-10-01
IPUC
Production Request
Staff-086
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
06/0712010
Patrck Ehrbar
Patrck Ehrbar
State & Federal Regulation
[phone]
In Ehrbar's testimony, page 42, lines 16-22, he says "many low income customers, I believe, tend to stil
use electrcity for space and water heating. These customers, in my view, tend to live in aparents
(which in Avista's service terrtory predominantly have electrc space and water heat), live in areas
where natural gas is not available, or live in areas with natual gas, but canot afford to convert." Please
provide all the data in electronic executable format that leads you to believe these assumptions are tre.
RESPONSE:
As I noted in his testimony, it was Mr. Ehrbar's belief that limited income customers tend to live in
aparents, areas where natual gas is not available, or live in areas with natual gas, but canot afford to
convert. The Company, as noted in its response to Staff-085, has not conducted a demographic survey to
support these assertons. However, the Company has provided analysis which shows that, for those
limited income customers that have paricipated in LIHAP or Limited Income DSM programs, roughly
2,372 were dual electrc and natual gas customers, while 3,133 were electrc only.
Furher, it would be reasonable to assume that limited income customers may choose to live in housing
that is affordable. Aparents/multi-family unts are one source of affordable housing. In the past
several years, the Company has been evaluating the penetration of natual gas into aparents in its
serce tertory, and recently stared tracking how many individual multi-family unts were being served
with natual gas. For 2009, what was found was that at least 75% of new multi-famly unts do not have
natual gas, and therefore are reliant on electrc space and water heat.
Not Coded : 251 2.6%:,_,.,~,,,,,,.,"".,_..."",...~...,.,.,...,,,.....,.~,~,l,,....,......,_,..._"__¡..,_....~...."...,.,_..J
,~f?~'!,k~f?!" "...+ "...,gSL,JL$% ¡
: Electric 1 722: 74.9% j
~~':~:~~,.~=d,:::d'=,d~,.d',=:..:::.ddddd'd..,d...i~r"=d~~2~J¡Oil 31 0.3%
Finally, as par ofthe evaluation of Avista's Natual Gas Decoupling Mechanism in Washigton, a third
pary evaluator, Titus, conducted analysis on the Company's known limited income population. Their
report, which is included as Attachment A to the Company's response to Staff-087, at table K1 - shows
the following:
Page 1 of2
.
.
.
Based on ths analysis, it would appear that 43%1 of the limited income population are electrc only
customers, and therefore may rely more on electrcity for space and water heat than the total residential
population (38%f
i Calculation - 13,267/30,915 = 43%
2 Calculation- 67,510/178,563 = 38%
Page 2 of2
.
.
.
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/07/2010
Patrck Ehrbar
Patrck Ehrbar
State & Federal Regulation
[phone]
IDAHO
AVU-E-I0-01 1 AVU-G-1O-01
IPUC
Production Request
Staff-087
REQUEST:
In Ehrbar's testimony, page 43, lines 13-17, regarding the implications of the Company's
proposed rate design on limited income natual gas customers, he says "Data gathered as par of
the review of the Company's Washington natural gas Decoupling Mechansm showed that limited
income natual gas customers tend to use slightly less natual gas (58 thers per month) than the
traditional residential customer (63 therms per month)." Please provide all the data "gathered as
par of the review of the Company's Washington natual gas Decoupling Mechanism," specifically
data comparng income levels and demographics of customers to natural gas usages.
RESPONSE:
All of the data gathered as par of the Company's Decoupling Mechansm evaluation is
volumnous, and can be provided upon request.
With regards to the data specific to the derivation of the difference between the usage of traditional
residential customers and limited income residential customers, please see the following
attachments which are being provided in electronic format only due to their voluminous or
electronic nature:
. Staff_PR_087-Attchment A.pdf - Avista Natural Gas Decoupling Mechansm Pilot
Evaluation Report (August 2009)
. Staff_PR_087-Attachment B.xls - LIR-LIHAP Average Usage - this spreadsheet
shows the derivation of the 58 therms per month average usage for the limited income
population.
. Staff PR 087-Attachment C.xls - 2006 Avista Revenue Runs - shows the derivation of
average monthly use per residential customer (63 therms per month)
. StafCP~087-Attchment D.xls - 2007 Avista Revenue Runs - shows the dervation of
average monthly use per residential customer (63 therms per month)
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-lO-Ol 1 AVU-G-1O-01
IPUC
Production Request
Staff-088
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/0712010
Patrck Ehrbar
Patrck Ehrbar
State & Federal Regulation
[phone]
In Ehrbar's testimony, pages 38-44, he prepares several tables ilustrating the impact the proposed
rate design changes would have on customers, please provide these tables in executable electronic
format. As par of your response, please include all the data used to deterine low, average, and
high usage levels.
RESPONSE:
Please see StafCPR _ 088-Attachment A.xlsx which is being provided in electronic format only as
requested. The low, average and high use levels were chosen arbitrarly for ilustrative puroses
only.
.
.
.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-10-01 1 AVU-G-10-01
IPUC
Production Request
Staff-090
DATE PREPARD:WISS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/07/2010
Patrck Ehrbar
Patrck Ehrbar
State & Federal Regulation
[phone]
REQUEST:
Please explain how you have deterined the Schedule 111 four-tier declining block-rate
differentials. In your response, explain why these differentials have been chosen. Include all
executable electronic workpapers associated with these decisions (e.g. - bil frequency study, load
factor study, etc.).
RESPONSE:
The first thee tiers of rate schedule 111 have been in place at their current levels for well over 25
years. It is clear, based on the declining block strctue, that more fixed cost recovery was
included in the first two blocks.
The four tier was developed as a result of Avista's 2008 Idaho General Rate Case
(A VU-G-08-0 1). As par of that case, the Company requested the elimination of Schedule 121 and
proposed moving the customers served under that schedule to Schedule 111. In support of this, the
Company requested the addition of an additional block to Schedule 111 for usage in excess of
10,000 therms per month. By doing ths, the proposed rate strctue for Schedule 111 would then
be nearly identical to the existing rate strctue under Schedule 121, supporting the case to
eliminate that schedule. Ths change was approved by the Commission in that case.
.
.
.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
06/0112010
Tara Knox
Tara Knox
State & Federal Regulation
[phone]
IDAHO
AVU-E-1O-01 1 AVU-G-1O-01
IPUC
Production Request
Staff-091
REQUEST:
In Case A VU-G-09-01, the Company changed from a 25-year to a 30-year average for
deterining "normal" heating and cooling degree days reported for each month. Since the case
settled without a decision regarding the change, please provide a detailed explanation and all
supporting executable electronically formatted analysis (with the exception of the 2007 & 2008
"Factors WC_1209 _w_30 yr rolling") ilustrating:
a. Why a 30-year average more accurately captues "normal" heating and cooling
degree days than a 25-year average. Ifless varabilty is the determning factor,
include an explanation of why this should be the deterinig factor, even though it
is important to captue recent climactic cycles and the Company continues to file
frequent rate cases.
b. A comparson of the change from a 25-year to a 30-year average for normal degree
days. In your response include all comparsons ilustrating how the final Revenue
Requirement is different with respect to the change from a 25-year to a 30-year
average for normal degree days.
RESPONSE:
a. Staff_PR_91_Attachment A includes a graph showig a comparson over time of the
annual total heating degree days using a 30 year rollng average versus a 25 year rolling
average. The R2 measurements associated with the trendline equations show that the 30
year rollng average has less varability than the 25 year rollng average. Less varability
around the trendline indicates that there is more likely to be a relatively smooth progression
from year to year using the longer rolling average. Having the values bounce about from
year to year is not desirable, therefore the measure with less varabilty is more desirable.
Both the 25 and 30 year measures move forward anually and captue the effect of the most
recently observed weather patterns.
b. Staff_PR_91_Attachment B contains the electronic files computing the weather
adjustment if the 25 year rolling average had been used instead of the 30 year rollng
average as fied. Also included in Attachment B is a comparson of the impact on revenue
requirement of the difference between the 25 year and 30 year normals in ths case.
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1976 6810
1977 6792
1978 6822
1979 6881
1980 6848
1981 6816 6819 1981
1982 6799 6805 1982
1983 6814 6810 1983
1984 6831 6827 1984
1985 6833 6834 1985
1986 6875 6842 1986
1987 6843 6822 1987
1988 6841 6843 1988
1989 6844 6852 1989
1990 6808 6815 1990
1991 6823 6829 1991
1992 6803 6779 1992
1993 6836 6800 1993
1994 6800 6794 1994
1995 6779 6763 1995
1996 6788 6782 1996
1997 6782 6809 1997
1998 6756 6796 1998
1999 6743 6762 1999
2000 6711 6748 2000.2001 6737 6770 2001
2002 6742 6752 2002
2003 6722 6743 2003
2004 6662 6733 2004
2005 6653 6700 2005
2006 6655 6689 2006
2007 6649 6686 2007
2008 6677 6690 2008
2009 6676 6656 2009
.
staff_PR_091_Attachment A.xlsm / Chart Data Page 2
.
.
.
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AVISTA UTILITIES
IPUC Case No. AVU-E-10-01 and AVU-G-10-01
Response to Staff Production Request No. 91, Part B.Revenue Requirement Impact of 25-Year Average Weather Correction vs Filed Case
(41,930,614)
(44,832,283)
2,901,669
Schedule 1 Schedule 11
(35,577,366) (6,353,248)
(37,997,921) (6,834,362)
2,420,555 481,114
Electric Weather Correction KWhs
With 25-Year Average Normal
As filed
Change in Load Adjustment
Total
$OOO's
Weather Sensitive Rate 0.07867 0.07433
Change in Revenue $226 $190,425 $35,761
Uncollectibles 0.4498%1
Commission Fees 0.1662%
Idaho State Income Tax 1.4203%3
Operating Income Before FIT $222
Federal Income Tax 35%78
Net Operating Income Change $144
.
Change in Production Propert Adjustment
With 25-Year Average Normal
As filed
Change in Production Property Adj
State Income Tax 1.4203%
Operating Income Before FIT
Federal Income Tax 35%
Net Operating Income Change
Net Expense
(3,625)
(3,731)
106 $
2
(108) $
(38)
(/0) $
$
Rate Base Debt Cost
(4,579)
(4,853)
274 3.10%
$
$
(3)
3
Rate of Return
Conversion Factor
8.55%
0.63676
Electric Revenue Requirement Impact $(116) $32 $(84)
Gas Weather Correction Therms Total Schedule 101 Schedule 111
With 25-Year Average Normal (3,583,540)(2,939,216)(644,324)
As filed (3,762,074)(3,083,186)(678,888)
Change in Load Adjustment 178,534 143,970 34,564
Weather Sensitive Rate 0.92932 0.76632
Cost of Gas 0.58429 0.58429
Change in Revenue $160 $133,794 $26,487
Change in Gas Cost $104 $84,120 $20,195
Uncollectibles 4.4980%7
Commission Fees 0.1662%
Idaho State Income Tax 1.4203%1
Operating Income Before FIT $48
Federal Income Tax 35%17
Net Operating Income Change $31.Conversion Factor 0.636764
Gas Revenue Requirement Impact $(49)
Staff_PR_091~ttachment B.xls Page 1
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,
0
1
2
-2
2
2
,
6
1
3
-1
,
0
3
2
,
4
9
2
-1
3
2
,
3
6
9
-3
0
2
,
7
2
5
18
7
,
9
4
2
-1
,
1
4
5
,
6
9
3
-7
9
8
,
8
6
0
-8
6
1
.
8
0
5
-3
0
5
,
9
7
5
16
0
,
4
4
0
-6
0
0
,
7
5
7
No

o
f

C
u
s
t
19
,
0
6
0
19
,
0
6
9
19
,
0
8
3
19
,
0
9
0
19
,
0
9
4
19
,
0
7
6
19
,
0
4
0
18
,
9
8
2
19
,
0
0
5
19
,
0
3
8
19
,
0
6
6
19
,
0
8
3
19
,
0
9
5
Os
a
g
e
/
D
O
H
0.
3
5
3
5
0.
3
5
3
5
0.
3
5
3
5
0.
1
4
7
5
0.
1
4
7
5
0.
1
4
7
5
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.1
4
7
5
0.
1
4
7
5
0.
3
5
3
5
Os
a
g
e
/
D
O
C
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
2.
2
4
1
8
2.
2
4
1
8
1.
0
7
7
8
1.
0
7
7
8
1.
0
7
7
8
1.
0
7
7
8
2.
2
4
1
8
2.
2
4
1
8
0.
0
0
0
0
WA

R
e
s

S
c
h
e
d

2
1
-7
1
1
.
8
3
1
-9
8
,
3
8
4
-4
0
,
6
0
3
-1
8
8
,
2
5
0
-3
0
,
6
1
4
9,
1
1
9
34
,
4
2
6
-9
6
,
7
0
7
-6
6
,
4
9
7
-7
5
,
2
8
5
-8
3
,
8
7
5
38
,
5
5
6
-1
1
3
,
7
1
7
No

o
f

C
u
s
t
79
77
78
78
78
78
78
79
78
82
81
81
81
Os
a
g
e
/
D
O
H
15
.
7
7
4
3
15
.
7
7
4
3
15
.
7
7
4
3
8.
3
5
0
8
8.
3
5
0
8
8.
3
5
0
8
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
8.
3
5
0
8
8.
3
5
0
8
15
.
7
7
4
3
Os
a
g
e
/
D
O
C
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
21
.

8
5
9
7
21
.

8
5
9
7
21
.
8
5
9
7
21
.
8
5
9
7
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
ID

R
e
s

S
c
h
e
d

1
-3
5
,
5
7
7
,
3
6
6
-4
,
8
8
3
,
3
0
0

-
1
,
9
8
6
,
8
8
2
-9
,
2
0
4
,
4
2
0
-2
,
0
2
5
,
7
1
1
60
2
,
7
1
7
2.
1
9
1
,
2
3
4
-4
,
8
9
0
,
5
3
8
-3
.
4
0
9
,
3
7
8
-3
,
6
9
0
.
7
1
6
-5
,
3
7
2
.
6
6
3

2
,
4
7
1
,
5
4
6
-5
.
3
7
9
,
2
5
5
No

o
f

C
u
s
t
99
,
5
7
7
99
,
8
1
4
99
,
6
8
3
99
,
6
0
2
99
,
3
7
8
99
,
2
6
5
98
,
8
9
4
99
,
2
0
6
99
,
3
0
7
99
,
8
2
3
99
,
9
0
3
99
,
9
7
8
10
0
,
0
6
8
Os
a
g
e
/
D
O
H
0.
6
0
4
0
0.
6
0
4
0
0.6
0
4
0
0.
4
3
3
7
0.
4
3
3
7
0.
4
3
3
7
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.
4
3
3
7
0.
4
3
3
7
0.6
0
4
0
Os
a
g
e
/
D
O
C
0.
0
0
0
0
0.
0
0
0
0
0.0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.
8
8
0
3
0.8
8
0
3
0.
8
8
0
3
0.
8
8
0
3
0.
0
0
0
0
0.0
0
0
0
0.
0
0
0
0
ID

R
e
s

S
c
h
e
d

1
1
-5
7
3
,
9
8
7
-9
2
,
2
3
7
-3
7
.
5
9
5
-1
7
3
,
9
8
7
-2
6
,
7
3
4
7,
9
7
8
28
,
5
5
7
-5
6
,
4
2
3
-3
9
,
4
9
9
-4
2
,
4
1
3
-7
1
.
3
0
4
33
,
0
8
0
-1
0
3
,
4
1
0
No

o
f

C
u
s
t
4,
4
1
4
4,
3
7
3
4,
3
7
5
4,
3
6
7
4,
3
8
9
4,
3
9
7
4,3
8
3
4,
4
2
3
4,
4
4
6
4,
4
3
3
4.
4
3
7
4,
4
7
8
4,
4
6
2
Os
a
g
e
/
D
O
H
0.
2
6
0
4
0.
2
6
0
4
0.
2
6
0
4
0.
1
2
9
6
0.
1
2
9
6
0.
1
2
9
6
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.1
2
9
6
0.
1
2
9
6
0.
2
6
0
4
Os
a
g
e
/
D
O
C
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.
2
2
7
8
0.
2
2
7
8
0.
2
2
7
8
0.
2
2
7
8
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
ID

C
o
m

S
c
h
e
d

1
1
-5
,
7
7
9
,
2
6
1
-5
7
4
,
1
3
1
-2
3
4
.
0
6
5
-1
,
0
8
4
,
8
4
0
-2
2
9
,
3
0
0
68
,
3
3
5
28
5
,
6
9
3
-1
,
2
4
2
,
0
2
6
-8
6
6
,
1
6
7
-9
3
7
,
9
6
2
-6
0
7
,
8
8
9
27
9
,
7
7
4
-6
3
6
,
6
8
3
No

o
f

C
u
s
t
14
,
6
8
5
14
,
6
7
2
14
,
6
8
2
14
,
6
7
7
14
,
6
6
4
14
,
6
7
1
14
,
6
3
0
14
,
6
0
3
14
.
6
2
3
14
,
7
0
4
14
,
7
3
5
14
,
7
5
3
14
,
8
0
8
Os
a
g
e
/
D
O
H
0.
4
8
3
1
0.
4
8
3
1
0.
4
8
3
1
0.
3
3
2
7
0.
3
3
2
7
0.
3
3
2
7
0.0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.
3
3
2
7
0.
3
3
2
7
0.
4
8
3
1
os
a
g
e
/
D
O
C
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
1.
5
1
8
8
1.5
1
8
8
1.
5
1
8
8
1.
5
1
8
8
0.
0
0
0
0
0.
0
0
0
0
0.
0
0
0
0
To
t
a
l

E
l
e
c
t
r
i
c

A
d
j
u
s
t
m
e
:
-
1
2
0
,
4
0
8
,
1
3
9

-
1
5
,
7
1
4
,
9
1
5

-
6
,
4
0
1
,
6
7
6

-
2
9
,
6
5
1
,
4
9
3
-6
,
2
4
6
,
9
8
1
1
,
5
1
6
,
2
0
1
6,
9
2
5
.
6
6
6

-
1
8
,
2
2
0
,
5
8
2

-
1
2
,
6
9
3
,
9
3
3

-
1
3
,
7
2
8
,
8
9
5

-
1
6
,
4
9
2
,
2
4
9

7
,
6
0
7
,
1
1
9
-1
7
,
3
0
6
,
4
0
1
WA

s
u
b
t
o
t
a
l
-7
8
,
4
7
7
,
5
2
5

-
1
0
,
1
6
5
,
2
4
7

-
4
,
1
4
3
,
1
3
4

-
1
9
,
1
8
8
,
2
4
6
-3
,
9
6
5
.
2
3
6
83
7
,
1
7
1
4,
4
2
0
,
1
8
2

-
1
2
,
0
3
1
,
5
9
5
-8
,
3
1
8
,
8
8
9
-9
,
0
5
7
,
8
0
4

-
1
0
,
4
4
0
,
3
9
3

4
,
8
2
2
,
7
1
9
-1
1
,
1
8
7
,
0
5
3
ID

s
u
b
t
o
t
a
l
-4
1
,
9
3
0
.
6
1
4
-5
,
5
4
9
,
6
6
8

-
2
,
2
5
8
,
5
4
2

-
1
0
,
4
6
3
,
2
4
7
-2
,
2
8
1
,
7
4
5
67
9
,
0
3
0
2,
5
0
5
,
4
8
4
-6
,
1
8
8
,
9
8
7
-4
,
3
1
5
,
0
4
4
-4
,
6
7
1
,
0
9
1
-6
.
0
5
1
,
8
5
6

2
,
7
8
4
,
4
0
0
-6
,
1
1
9
,
3
4
8
Su
m
r
i
z
e

b
y

S
c
h
e
d
u
l
e
WA

S
c
h

1
-7
1
,
1
9
6
,
4
7
9
-9
,
3
5
3
,
0
9
0

-
3
,
8
1
1
,
4
6
7

-
1
7
,
6
5
0
,
1
3
9
-3
,
7
4
4
,
7
3
5

1
,
1
1
3
,
6
7
0
4,
1
3
9
,
1
8
9

-
1
0
,
7
2
3
,
4
7
9
-7
,
4
6
7
,
6
5
0
-8
,
0
7
1
,
0
3
6
-9
,
8
9
6
.
3
5
9

4
,
5
5
3
,
1
4
8
-1
0
,
2
8
4
.
5
3
1
WA

S
c
h

1
1
-6
,
5
6
9
.
2
1
5
-7
1
3
,
7
7
3
-2
9
1
,
0
6
4
-1
,
3
4
9
,
8
5
7
-1
8
9
,
8
8
7
-2
8
5
,
6
1
8
24
6
,
5
6
7
-1
,
2
1
1
,
4
0
9
-8
4
4
,
7
4
2
-9
1
1
,
4
8
3
-4
6
0
,
1
5
9
23
1
,
0
1
5
-7
8
8
,
8
0
5
WA

S
c
h

2
1
-7
1
1
,
8
3
1
-9
8
,
3
8
4
-4
0
,
6
0
3
-1
8
8
,
2
5
0
-3
0
,
6
1
4
9,
1
1
9
34
.
4
2
6
-9
6
,
7
0
7
-6
6
,
4
9
7
-7
5
,
2
8
5
-8
3
,
8
7
5
38
,
5
5
6
-1
1
3
,
7
1
7
ID

S
c
h

1
-3
5
,
5
7
7
.
3
6
6
-4
,
8
8
3
,
3
0
0

-
1
,
9
8
6
.
8
8
2
-9
,
2
0
4
,
4
2
0
-2
,
0
2
5
,
7
1
1
60
2
.
7
1
7
2,
1
9
1
,
2
3
4
-4
,
8
9
0
,
5
3
8
-3
,
4
0
9
,
3
7
8
-3
,
6
9
0
,
7
1
6
-5
.
3
7
2
,
6
6
3

2
,
4
7
1
,
5
4
6
-5
,
3
7
9
,
2
5
5
ID

S
c
h

1
1
-6
.
3
5
3
.
2
4
8
-6
6
6
,
3
6
8
-2
7
1
,
6
6
0
-1
,
2
5
8
,
8
2
7
-2
5
6
,
0
3
4
76
,
3
1
3
31
4
,
2
5
0
-1
,
2
9
8
,
4
4
9
-9
0
5
,
6
6
6
-9
8
0
,
3
7
5
-6
7
9
.
1
9
3
31
2
,
8
5
4
-7
4
0
,
0
9
3
ID

S
c
h

2
1
0
0
0
0
0
0
0
0
0
0
0
0
0
St
a
f
f
_
P
R
_
0
9
1
_
A
t
t
a
c
h
m
e
n
t

B
.
x
l
s
Pa
g
e

5
.
.
.
St
a
f
f

P
R

0
9
1
_
A
t
t
a
c
h
m
e
n
t

B
.
x
l
s

/

G
a
s

b
y

M
o
To
t
a
l
Ja
n
u
a
r
y
Fe
b
r
u
a
r
y
Ma
r
c
h
Ap
r
i
l
Ma
y
Ju
n
e
Ju
l
y
Au
g
u
s
t
Se
p
t
e
m
b
e
r
Oc
t
o
b
e
r
No
v
e
m
b
e
r
De
c
e
m
b
e
r
No
r
m
l

D
D
H
6,
6
7
6
1,
1
2
3
92
4
78
3
53
9
31
7
13
8
33
36
18
5
54
4
89
1
1,
1
6
3
Ac
t
u
a
l

D
D
H
6,
9
7
6
1,
2
0
4
95
7
93
6
58
6
30
3
93
17
23
10
3
66
8
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4
1,
2
5
2
Un
b
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d

D
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0
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1
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3
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7
14
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16
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82
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57
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9
Ra
t
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G
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p
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1
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2
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6
9
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9
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5
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3

-
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9
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51
7
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8
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2
,
3
2
0
66
0
,
5
8
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,
1
8
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7
9
7
No

o
f

C
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t
13
1
,
6
4
2
13
1
,
8
2
3
13
1
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.
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4
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1
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8
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0
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7
7
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8
7
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1
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2
WA

C
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1
0
1
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1
4
5
,
0
1
6
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3
6
,
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1
6
-9
6
,
0
9
8
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4
4
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9
0
1
-9
2
,
4
1
4
27
,
5
1
4
88
,
4
7
4
0
0
0
-2
4
4
,
5
2
0
11
2
,
9
5
2
-2
6
0
,
0
0
7
No

o
f

C
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s
t
11
,
7
9
8
11
,
8
1
1
11
,
8
0
4
11
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7
8
7
11
,
7
7
4
11
,
7
6
8
11
,
7
7
3
11
,
7
5
7
11
,
7
7
6
11
,
8
0
5
11
,
8
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8
11
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8
6
6
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Us
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D
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2
4
6
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2
4
6
7
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1
6
7
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0.
1
6
7
0
0.
1
6
7
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0
0
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0
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0
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2
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7
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1
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1
0
1
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,
5
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9
7
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2
3
9
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,
6
1
3
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1
5
5
35
2
1,
1
3
3
0
0
0
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,
1
5
8
1,
4
0
1
-3
,
2
6
5
No

o
f

C
U
s
t
86
86
88
86
83
85
85
85
86
87
86
83
86
Us
a
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D
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0.
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2
6
6
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2
6
6
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4
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6
6
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2
9
6
1
0.
2
9
6
1
0.
2
9
6
1
0.
0
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0
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0
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2
9
6
1
0.
2
9
6
1
0.
4
2
6
6
WA

C
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1
1
1
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,
0
2
7
,
0
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4
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3
3
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6
6
,
3
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7
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8
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4
5
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3
8
9
59
,
2
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0
,
2
8
5
0
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1
4
,
8
8
1
23
7
,
2
6
7
-4
4
7
,
3
6
3
No

o
f

C
U
s
t
2,
0
3
6
2,
0
1
3
2,
0
3
3
2,
0
5
7
2,
0
6
8
2,
0
5
1
2,
0
5
1
2,
0
3
8
2,
0
4
1
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0
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0
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7
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4
7
9
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4
7
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4
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9
8
2.
0
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1
7
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0
6
1
7
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0
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1
7
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0
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1
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3
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1
,
9
5
9
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6
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9
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8
7
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6
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6
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6
9
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6
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9
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4
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4
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1
8
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23
8
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1
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6
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-6
6
1
,
8
3
5
30
4
,
9
6
9
-5
1
0
,
3
0
6
No

o
f

C
U
s
t
64
,
9
8
3
64
,
8
9
8
64
,
9
1
5
64
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8
7
9
64
,
7
2
6
64
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6
2
3
64
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5
4
9
64
,
6
7
9
65
,
7
9
4
64
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9
3
7
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8
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8
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52
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7
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0
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4
5
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0
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3
66
,
9
8
1
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3
5
,
6
5
7
No

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f

C
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s
t
7,
3
7
6
7,
4
0
6
7,
3
9
9
7,
3
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7
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6
8
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1D

1
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1
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7
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,
3
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9
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2
2
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3
3
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3
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0
84
8
0
0
0
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,
3
7
1
1,
0
7
4
-2
,
5
2
2
No

o
f

C
U
s
t
69
70
68
69
68
68
69
68
68
69
70
69
69
Us
a
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2
7
3
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2
7
3
2
0.
2
7
3
2
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0
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2
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2
7
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4
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1D

C
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d

1
1
1
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4
4
,
3
2
4
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2
8
,
6
6
8
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2
,
7
7
1
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4
4
,
1
2
4
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5
,
0
7
2
16
,
5
6
6
52
,
7
8
6
0
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0
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5
2
,
4
5
8
69
,
9
3
5
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5
0
,
5
1
8
No

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f

C
U
s
t
92
5
89
7
90
3
90
1
91
3
92
2
91
4
91
4
92
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95
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7
0
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7
7
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7
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1.
2
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3
4
1.
2
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3
4
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4
1.
2
8
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4
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7
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0
9
WA

s
u
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.
5
2
7
,
8
2
3
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7
1
3
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9
-6
9
9
,
5
6
7

-
3
,
2
5
0
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7
6
6
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24
8
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79
7
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-
2
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9
4
,
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7
9

1
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0
1
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8
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4
3
2
1D

s
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a
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,
5
8
3
,
5
4
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1
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4

-
1
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2
5
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0
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3
7
10
7
,
4
6
0
34
4
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6
1
,
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7
44
2
.
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9
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,
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3
Su
m
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e

b
y

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d
u
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1
0
1
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,
5
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,
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9
1
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8
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0
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-
2
,
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3
2
1
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3
5
,
9
2
4
18
9
,
2
2
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60
7
,
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5
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-
1
,
6
7
9
,
9
9
8
77
4
,
9
3
3
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,
4
4
4
,
0
6
9
WA

1
1
1
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,
0
2
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,
0
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2
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0
4
,
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3
9
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6
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,
3
6
7
-7
8
0
,
4
4
5
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0
0
,
3
8
9
59
,
2
0
0
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2
8
5
0
0
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1
4
,
8
8
1
23
7
,
2
6
7
-4
4
7
,
3
6
3
WA

1
2
1
0
0
0
0
0
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0
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1D

1
0
1
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,
9
3
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2
1
6
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8
6
,
2
1
6
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,
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3

-
1
,
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0
6
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6
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0
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,
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,
8
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4
29
1
,
7
8
5
0
0
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0
9
,
2
4
9
37
3
,
0
2
4
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4
8
,
4
8
5
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1
1
1
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4
4
,
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2
8
,
6
6
8
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2
,
7
7
1
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4
4
,
1
2
4
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5
,
0
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16
,
5
6
6
52
,
7
8
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0
0
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5
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,
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69
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9
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5
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5
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6
AVISTA UTILITIES
Production Factor Adjustment
Twelve Months Ended December 2009.Idaho Electc Rate Case
$OOO's Production Transmissic Pro formed Producton Test Year Workpaper
Period Totl Factor ~djustmen Total References
Pro forma Rate Base
Plant
Çap~¡;lM~!~Cl~~0.01273 7,184 557,189 PF6, 7, 2
N 0.03074 146 4,597 PF8
0.03074 327 10,313 min,o
0.03074 547 17,242 j, k,l
0.03074 61 1,923 P
8,265 591,264
(59,2!S)(212,252)0.01273 (2,702)(209,550)PF6, 7, 2
(100)0.03074 (3)(97)PF8
(451)0.03074 (14)(437)m,n,o
(744)0.03074 (23)(721)j, k,l
(59,275)(213,547)(2,742)(210,805)
Accumulated Deferred FIT
Ca (1S,~3)0.01273 (717)(55,620)PF6, 7, 2
0.03074 (9)(273)PF8
0.03074 (14)(445)m,n,o
0.03074 (183)(5,782)j, k,l
0.03074 (21)(673)P
(944)(62,793)
Net Rate Base 223,800 98,445 322,245 4,579 317,666
Depreciation/Amortization
0.01273 169 13,111 PF6,7
0.03074 4 138 PF8
0.03074 12 365 m,n1o.0.03074 15 476 j, k,l
0.03074 11 350 P
211 14,440
Propert Taxes
ç 0.03074 154 4,872 PF 6,7, rand b
0.03074 2 58 PF8
156 4,930
O&MExpense
S 1,404 0.03074 43 1,361 PF12
843 0.03074 26 817 PF12
54,534 0.03074 1,676 52,858 PF1
62,052 0.03074 1,907 60,145 PF1
6,347 0.03074 195 6,152 PF3
1,964 0.03074 60 1,904 PF10and PF3
737 0.03074 23 714 PF5
481 0.03074 15 466 ab
158 0.03074 5 153 ac
185 0.03074 6 179 ad
1,521 0.03074 47 1,474 P
308 0.03074 9 299 ae
4,012 126,52
Revenue
20,035 0.03074 616 19,419 PF1
137 0.03074 4 133 PF1
4,352 0.03074 134 4,218 PF5
Total pro formed Revenues 20,1 (2 4,352 24,524 754 23,110
Net Operating Expense Before Tc 116,604 9,143 125,747 3,625 122,122
Idaho Retail Loads PF2.12 Months Ended September 30, 2011 0.03074 September 2011 Factor
12 Months Ended December 2010 0.01273 December 2010 Factor
Normalized 12 Months Ended December 2009
Staff_PR_091_Attachent B.xls Page 7
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-10-01 1 AVU-G-1O-01
IPUC
Production Request
Staff-96
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/08/2010
Elizabeth Andrews
Theresa Melvin
State & Federal Reg.
[phone]
Please provide a list, in Excel format with formulas activated, of all charges to the following
accounts for 2009. The list should include FERC account, FERC subaccount, date, vendor,
amount, a brief description, and some method of tracking, i.e.-voucher number or invoice number.
598000
813000
824000
837000
874000
879000
880000
887000
889000
892000
894000
903000
905000
908000
909000
910000
912000
913000
916000
921000
922000
923000
924000
925100
925200
925300
928000
930100
930200
935000
DISTRUTION MAT-MISC
OTHR EXPENSE
NAT GAS STORAGE-OTHR EXPENSES
NAT GAS STRGE MA-OTHR EQUI
DIST EXPENSES OPER-MAS&SVCS EXP
DIST EXP OPER-CUST INSTALL EXP
DIST EXP OPER-OTHR EXPENSES
DIST EXP MA-MAS
DIST EXP MA-MEA & REG STAT EQP GEN
DIST EXP MA-SERVICES
MA OF OTHR DISTRUTION EQUIMENT
CUST ACCOUNS EXP-RECORDS & COLLECT
MISC CUST AC EX
CUST SVC & INO EXP-CUST ASST EXP
INO AN INSTRUCT ADVERT EXP
CUST SVC & INO EXP-MISC
SALES EXPENSES-DEMONSTRTING
ADVERTISING EXPENSE
MISC SALES EXPENSES
OFFICE SUPPLIES & EXPENSES
ADMISTRTIV EXPENSE TRSFERRD
OUTSIDE SERVICES EMPLOYED
PROPERTY INSURCE
INJUS & DAMGES NON PB
INJUS & DAMGES PB
INJUS & DAMGES PB CLEARG
REGULATORY COMMSSION EXPENSES
GENERA ADVERTISING EXPENSE
MISC GENERA EXPENSE
MA OF STRUCTU & IMROVEMENTS
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Page 2
RESPONSE:
Please refer to the folder named Staff DR 96. Due to the voluminous amount of data in ths
response, the data wil only be provided electronically.
FERC accounts 925200 and 925300 are Injur and Damages Payroll Benefits Clearng accounts
and net to zero; therefore, they are not included in Results of Operations and have been omitted
from this response.
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-10-01 1 AVU-G-10-01
IPUC
Production Request
Staff-l 00
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/08/2010
Richard L. Storro
Linda Donley
Resource Accountig
[phone]
Please identify any costs associated with the Rearden Project referenced in Company witness
Storro's testimony that are included in the test year. Please identify all costs included by FERC
account.
RESPONSE:
Please refer to Staff PR 034-Attachment A for this information. All of the costs associated with
the Reardan Project are accounted for in FERC account 183, Prelimiar Surey & investigation
(PS&I). None of the costs are included in the test year.
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-I0-01 1 AVU-G-IO-01
IPUC
Production Request
Staff-101
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/08/2010
Richard L. StorfO
Linda Donley
Resource Accounting
[phone]
Company witness Storro, page 11, states, "In addition, the Company continues to place met towers
at other locations withn its servce terrtory to collect wind data and explore other sites for
potential development." Please identify all costs associated with the placement of the met towers
that are included in the test year. Please identify all costs included by FERC account.
RESPONSE:
All of the costs associated with the placement of met towers are accounted for in FERC account
183, Preliminar Surey & investigation (PS&I). None of the met tower costs are included in the
test year. Cost incured for the placement of met towers is $348,278. Please refer to
Staff_PR_10I-Attachment A for a spreadsheet containing the costs associated with the placement
of met towers.