20100310Comments.pdf

SCOTT WOODBURY
DEPUTY ATTORNEY GENERAL
IDAHO PUBLIC UTILITIES COMMISSION
PO BOX 83720
BOISE, IDAHO 83720-0074
[phone]
BARNO. 1895
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KRSTINE A. SASSER
DEPUTY ATTORNEY GENERAL
IDAHO PUBLIC UTILITIES COMMISSION
PO BOX 83720
BOISE, IDAHO 83720-0074
[phone]
BARNO. 6618
Street Address for Express Mail:
472 W. WASHINGTON
BOISE, IDAHO 83702-5918
Attorneys for the Commission Staff
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION OF )
PACIFICORP DBA ROCKY MOUNTAIN ) CASE NO. PAC-E-I0-0l
POWER FOR AUTHORITY TO IMPLEMENT )
POWER COST ADJUSTMENT RATES FOR )
ELECTRIC SERVICE FROM APRIL 1,2010 ) COMMENTS OF THE
THROUGH MARCH 31, 2011 THROUGH THE ) COMMISSION STAFF
ENERGY COST ADJUSTMENT MECHANISM )
)
COMES NOW the Staff of the Idaho Public Utilties Commission, by and through its
Attorney of record, Scott Woodbury, Deputy Attorney General, and in response to the Notice of
Application, Notice of Modified Procedure, Notice of Comment/rotest Deadline and Notice of
Reply Deadline issued on Februar 12,2010, submits the following comments.
STAFF COMMENTS 1 MARCH 10,2010
BACKGROUND
On February 1,2010, PacifiCorp dba Rocky Mountain Power (PacifiCorp; Company) fied
an Application with the Idaho Public Utilties Commission (Commission) for authority to
implement a power cost adjustment to rates for all customer classes excluding taiff contract
customers (Monsanto Company and Agrium, Inc.). i The proposed power cost adjustment is
calculated pursuant to an Energy Cost Adjustment Mechanism (ECAM) approved by the
Commission on September 29,2009 in Case No. PAC-E-08-08, Order No. 30904. The primar
purose of the ECAM is to collect from customers or credit to customers a portion of the difference
between base net power costs included in base rates, and actual net power costs incurred by the
Company. The ECAM also includes several other adjustments approved by the Commission. The
initial deferral period was July 1,2009 through November 30, 2009. The Company is proposing to
recover approximately $2.2 millon in total deferred net power costs. The energy cost adjustment is
set forth in a new electric service Schedule No. 94. The proposed effective date is April 1, 2010.
The Settlement Stipulation accepted by the Commission in Order No. 30904 identifies in substantial
par the procedures, dates and components associated with the ECAM.
The Net Power Cost (NPC) portion of the ECAM includes costs typically booked to the
following Federal Energy Regulatory Commission (FERC) accounts.
Account 447 - Sales for resale, excluding on-system wholesale sales and other
revenues that are not modeled in GRID.
Account 501 - Fuel, steam generation, excluding fuel handling, star-up
fuel/gas,2 diesel fuel, residua disposal and other costs that are not modeled in
GRID.
Account 503 - Steam from other sources.
Account 547 - Fuel, other generation.
Account 555 - Purchased power, excluding BPA residential exchange credit
pass-through, if applicable.
Account 565 - Transmission of electricity by others (wheeling).
i Tariff contract loads (Monsanto and Agrium) are not subject to any ECAM surcharges/credits until January I, 20 I I.
Reference Case No. PAC-E-07-05, Order No. 30482.
2 Start-up fuel is accounted for separately from the primar fuel for steam-powered generation plants. Start-up costs are
not accounted for separately for natural gas plants, and therefore all fuel for natural gas plants is included in the
determination of both base NPC and actual NPc.
STAFF COMMENTS 2 MARCH 10,2010
In addition to NPC, the ECAM includes three other components: a Load Growth
Adjustment, a credit for S02 allowance sales, and a Renewable Resource Adder. The ECAM also
includes an interest calculation and a symmetrical sharing band of90% (customers)/lO%
(Company) that is applied to most components.
The Renewable Resources Adder recognizes that the Company has made significant
investments in renewable generation projects that are not yet being recovered in Idaho rates, even
though these projects provide significant NPC benefits to customers. Specifically, the adjustment
recognizes that actual NPC were reduced by power generated from these renewable generation
projects. Pursuant to Commission Order No. 30904, the Commission approved a renewable
resource adjustment of $55 per megawatt-hour (MWh) multiplied by the actual MWh output
generated by the renewable resources that were not included in rates in the Company's last rate
case, Case No. PAC-E-08-07.
The components making up the deferred ECAM balance are reflected in the following table:
NPC Differential $ 121,504
Load Growth Adjustment 1,499,793S02 Credit (120,562)Sub-Total $1,500,735
90%
$1,350,662
811,412
8,022
$2,170,096
Customer Responsibilty
Renewable Resource Adder
Interest
Total Idaho Deferral
In Schedule 94 the Company proposes the following rates by delivery voltage:
Secondar Distribution Rate
Primar Distribution Rate
Transmission Rate
0.107 t/kWh
0.100 t/kWh
0.098 t/kWh
The proposed Schedule 94 ECAM rates would have the following rate impacts:
Residential Customers - an increase of 1.29%, i.e., approximately $0.91 per
month for the average residential home using 850 kWh per month.
Irrigation Customers (Schedule 10): 1.55% increase
STAFF COMMENTS 3 MARCH 10,2010
General Service
Schedule 23/23A: 1.34% increase
Schedule 6/6A/8/35: i .70% increase
Schedule 9: 2.13% increase
Schedule 19: 1.57% increase
Public Street Lighting
Schedules 7/7A, 11, 12: 0.46% increase
STAFF ANALYSIS
ECAM Deferral
Staff notes that this is the first ECAM filing made by the Company subsequent to approval
of the mechanism in Commission Order No. 30904. As a result, the ECAM fiing in this case
differs in several respects from Company fiings that will be made in subsequent years. (1) This
fiing includes adjustments for Net Power Cost Differential, Load Growth Adjustment, and S02
Sales for the 5-month period of Julyl, 2009 through November 30, 2009; future filings wil be for
the 12-month period of December 1 through November 30 of the application year. (2) The
Renewable Resource Adder wil only be included in the ECAM until the costs and benefits can be
included in base rates in the Company's next general rate case. A rate case wil eliminate the need
for this special adjustment. (3) In future years there wil be a "true up" between the deferral balance
and amounts actually recovered; any over- or under-recovery that occurs as a result of this ECAM
filing wil result in an adjustment to future ECAMs.
The Commission Staff has reviewed the Company's ECAM filing and audited the
Company's actual results as they pertain to the ECAM. Staff recommends changes to the
Company's proposal as defined and discussed below.
Net Power Cost Differential - The Net Power Cost differential is the driving force behind
the creation and need for a power cost adjustment mechanism. Normally this differential is the
single largest cost component of the mechanism. In this case it is a small portion of the total
deferraL. Two primar reasons for this are (1) the review period is only five months instead of
twelve months and (2) the actual system load was lower than the base load assumed in the
Company's last general rate case. The lower system load is probably associated with the current
economic downtur.
Staff reviewed transaction activity in the FERC accounts used to record net power costs.
Specifically, base and actual NPC include amounts booked to the following FERC accounts:
STAFF COMMENTS 4 MARCH 10,2010
Account 447 (sales for resale, excluding on-system wholesale sales and other revenues not modeled
in GRID), Account 501 (fuel, steam generation, excluding fuel handling, star up fuel/gas, diesel
fuel, residual disposal and other costs not modeled in GRID), Account 503 (steam from other
sources), Account 547 (fuel, other generation), Account 555 (purchased power, excluding BPA
residential exchange credit pass-through if applicable), and Account 565 (transmission of electricity
by others). Staffs analysis did not find any transaction that was not reasonable or significantly out-
of-trend with previous activity. Staff notes, however, that the audit period in this case included only
five months of transactions; future audits that encompass an entire year wil provide better data for
trend analysis and transaction evaluation.
The Idaho share of net power costs increased by $121,504; the Idaho customers' share ofthe
increased cost is $109,354 after 90/10 sharing. This amount represents 5.43% of the Company's
proposed total ECAM deferraL.
Load Growth Adjustment - The Load Growth Adjustment is by far the largest component of
this ECAM deferraL. During the five month review period actual Idaho loads were down 85,810
MWh or 7.95% from the same 2007 normalized five month period used to calculate Idaho base
load. At an approved adjustment rate of $17 .48/MWh, this results in an adjustment of $1,499,793.
The Idaho customer share is $1,349,814 after 90/10 sharing. These are the same results presented
by the Company.
The theory behind the LGAR is that the Company should not be allowed to collect growth
related power supply costs through an ECAM surcharge and then also collect base revenue from
that new load to cover the same power supply costs. The same theory has been applied when loads
decline. The Company should not be required to provide a credit to customers when power supply
costs decline due to declining load and also suffer the loss of base revenue from the lost load. In
this case, power supply costs increased slightly at the same time load decreased significantly.
Rather than offsetting lost revenue that the Company already gave back in an ECAM credit, the
Load Growth Adjustment simply reimbursed the Company for lost revenue due to lost load. This is
very similar to decoupling or the Fixed Cost Adjustment Mechanism (FCA) in place for Idaho
Power Company.
While Staff does not propose to remove the Load Growth Adjustment in this case given that
a symmetrical mechanism was approved by the Commission, we note that decoupling has not been
approved in Idaho for PacifiCorp. Staff also notes that all three Idaho utilties have ECAM/PCA's
in place with similar provisions. Staff believes that fuher investigation is necessar in conjunction
STAFF COMMENTS 5 MARCH 10,2010
with Compariy filings for all three mechanisms to determine if a Load Growth Adjustment is
appropriate when the adjustment exceeds the magnitude of the ECAM/PCA surcharge/credit or is
otherwise reasonable when loads decline.
S02 Credits - In Commission Order No. 30904 the Commission accepted a stipulated
settlement that required that the ECAM include and share revenues from the sale of S02 credits
between the Company and its customers (90% customers/1 0% Company). This applied to all S02
sales beginning July 2009. The Company calculated the Idaho portion of the S02 credit sale
proceeds by multiplying total sales by the Idaho energy allocation factor of 6.5865%. The Idaho
portion of the S02 credit sale proceeds was then further reduced to an Idaho tarff customer portion
based on the percent of the Idaho tariff load to total Idaho load in each month. (Shu Direct
Testimony p. 5, lines 18-23 through p. 6, lines 1-5 and Company Exhibit 1, lines 13-17). The
Company calculated the Idaho tariff customer portion to be $108,506 after the 90/10 sharing.
Staff agrees that S02 sales proceeds should be allocated to Idaho based on the energy
allocation factor. However, Staff believes fuher adjustment by the percentage representing the
tariff customer portion of total Idaho Load is not consistent with prior rate case treatment of S02
credit sale proceeds to tariff customers. Ratemaking treatment of S02 credit sale proceeds prior to
the ECAM resulted in 100% of the sale proceeds reducing the approved rate increase whether
contract customers were affected or not. Staff believes the 10% sharing represents the appropriate
Company share as the sale of S02 credits are moved from base rates to the ECAM. This final
Company proposed reduction in Idaho S02 proceeds, which have already been reduced to 90% of
the originally allocated amount, results in an even smaller allocation to Idaho tariffed customers and
an even larger share retained by the Company. This should not occur simply because an ECAM has
been implemented. Therefore, Staff recommends that the Commission reject the Company's
proposal to furher reduce Idaho S02 credits. Eliminating the reduction results in a net S02 credit
of $142,609 after 90/10 sharing, increasing the Idaho tarff customer credit by $34,104.
Renewable Resource Adder - The Renewable Resource Adder is a relatively short term
adjustment included in the ECAM by Commission order. This adjustment allows the ECAM to
include a cost for renewable resources that have come on-line since base power costs were set in the
Company's last rate case, Case No. PAC-E-08-07. The costs are included at $55/MWh. The costs
of these resources are not included in base rates but generation from the resources reduces actual
Net Power Costs. In the Company's next general rate case the costs and benefits of these resources
STAFF COMMENTS 6 MARCH 10,2010
wil be included in base rates which wil eliminate the need for this special adjustment. The Idaho
customer share of this cost is $811,412. These are the same results presented by the Company.
Goose Creek Transmission Sale Credit - Commission Order No. 30904 required the
Company to include an Idaho customer benefit for the sale of Goose Creek Transmission assets in
its ECAM calculation. The amount that was to be included as an Idaho customer benefit was
established as $156,434. The Company inadvertently left this credit out of its filing. Shortly after
the filing was made the Company contacted Staff and identified the error. Staff has included the
credit in its calculations.
Interest - As required by Commission Order No. 30904, the Company included interest on
monthly deferral balances at the Commission approved customer deposit interest rate. This rate is
2% for 2009. The Company calculated the interest amount to be $8,022. Due to the addition of the
Goose Creek Sale Credit and the adjustment for S02 sales, Staff calculates a slightly different
interest amount than the Company calculated. Staff calculates interest of $7,329 resulting in an
adjustment of $693.
Incorporating the Staff adjustments discussed above, Staff calculates the ECAM components
and Total Idaho Deferral to be:
Customer Responsibility
Renewable Resource Adder
Goose Creek Sale Credit
Interest
Total Idaho Deferral
$ 121,504
1,499,793
(158,455)
$1,462,842
90%
$1,316,558
811,412
(156,434)
7,329
$1,978,865
NPC Differential
Load Growth Adjustment
S02 Credit
Sub-Total
The Staff adjustments reduce the deferral amount from the Company calculation of
$2,170,096 to $1,978,865. The sum of all Staff adjustments reduced the ECAM deferral by
$191,231. Attachment A shows Staff s calculations in more detaiL.
ECAMRates
The methodology for calculating ECAM rates is generally defined in the Settlement
Stipulation accepted by the Commission in Order No. 30904. The details of the rate design were
STAFF COMMENTS 7 MARCH 10,2010
accepted by paricipating parties in discussions after Order No. 30904 was issued. The rates were to
be energy rates (t/kWh) and they were to be differentiated based on delivery losses. In Company
Exhibit No.3, the Company proposes three different energy rates that vary by delivery voltage. In
general the lower the delivery voltage the higher the losses associated with serving the load. Higher
losses translate into higher ECAM rates and lower losses, due to higher delivery voltages, translate
into lower ECAM rates. Attachment B to these comments shows the calculation of the three loss
differentiated rates on the right hand side of the box at the bottom of the Attachment. Staff
calculates the ECAM rates for customers taking service at the secondar distribution voltage level
to be .00098 $/kWh (0.098 t/kWh). The ECAM rate for those taking service at the Primar
Distribution voltage level is 0.00091 $/kWh (0.091 t/kWh). Finally, customers taking service at the
Transmission voltage level should pay an ECAM rate of 0.00089 $/kWh (0.089 t/kWh). These
rates applied to the Company's customer Classes produce the percentage increases shown on the
right hand side of the "Revenues" column of Attachment B. The Staff proposed ECAM rate
adjustment results in an average rate increase to tariff customers of 1.34%.
It may be noted that the application of these three rates to the estimated metered energy sales
produce a revenue amount of approximately $1,981,000 which is approximately $2,000 above the
deferral amount. This occurs because the rates are rounded to five decimal places like all Rocky
Mountain Power energy rates. This is not a problem because this difference, or any other
difference, between the deferral amount and amounts actually recovered is caried back into the
following years deferral balance as a true up.
CONSUMER ISSUES
Customer Notice and Press Release
The Customer Notice and Press Release were included in Rocky Mountain Power's
Application. The Application was received on Februar 1,2010. Staff reviewed the customer
notice and press release and determined they were in compliance with the requirements of Rule 102,
Utility Customer Information Rules (UCIR), IDAPA 3 i .21.02.102. The customer notice was
mailed to Rocky Mountain's customers with cyclical billngs beginning Februar 1,2010 and
ending March 1,2010.
STAFF COMMENTS 8 MARCH 10,2010
Customer Comments
Customers were given unti March 10, 2010 to fie comments. As of March 10, 2010, two
comments had been received. Both commenters opposed any increase in rates.
RECOMMENDATIONS
The Commission Staff recommends that the Commission accept an Idaho ECAM deferral
balance of $1 ,978,865 for the July 1, 2009 through November 30, 2009 deferral period. This
number includes a Goose Creek Transmission Sale credit, an adjustment to the S02 sale credit, and
an adjustment to the Company's interest calculation as previously discussed in these comments.
Staff also recommends that the Commission approve the following loss differentiated energy
rates to be included in Schedule 94:
Secondar Distribution Rate
Primar Distribution Rate
Transmission Rate
0.098 t/kWh
0.091 t/kWh
0.089 t/kWh
Staff fuher recommends that the rates become effective April 1, 2010 as requested by the
Company.
As previously discussed in these comments, Staff also recommends that the application and
implementation of the Load Growth Adjustment be fuher evaluated either in the Company's next
general rate case or in a separate case before the next anual ECAM filing.
Respectfully submitted this
lo"Jday of
Marh 2010.
Scott Wooäbur
Deputy Attorney General
Technical Staff: Keith Hessing
Cecily Vaughn
Marilyn Parker
i:umisc: comments/pace I 0.0 Iswkhcvmp comments
STAFF COMMENTS 9 MARCH 10,2010
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W
CERTIFICATE OF SERVICE
I HEREBY CERTIFY THAT I HAVE THIS 10TH OF MARCH 2010, SERVED
THE FOREGOING COMMENTS OF THE COMMISSION STAFF, IN CASE
NO. PAC-E-1O-01, BY MAILING A COPY THEREOF, POSTAGE PREPAID, TO THE
FOLLOWING:
TED WESTON
ID REGULATORY AFFAIRS MANAGER
ROCKY MOUNTAIN POWER
201 S MAIN ST STE 2300
SALT LAKE CITY UT 84111
E-MAIL: ted.weston(ipacificorp.com
YVONNE R HOGLE
SENIOR COUNSEL
ROCKY MOUNTAIN POWER
201 S MAIN ST STE 2300
SALT LAKE CITY UT 84111
E-MAIL: Yvonne.hogle(ipacificorp.com
DATA REQUEST RESPONSE CENTER
PACIFICORP
825 NE MULTNOMAH STE 2000
PORTLAND OR 97232
E-MAIL: datarequest(ipacificorp.com
,-bftmt
SECRETARY
CERTIFICATE OF SERVICE