20100317Reply Comments.pdf

~~~OUNTAIN
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ioiu M~R 11 M'l 9: 23
201 South Main, Suite 2300
Salt Lake Cit, Utah 84111
March 17,2010
VI OVERNIGHT DELIVERY
Jean D. Jewell
Commission Secreta
Idaho Public Utilties Commission
472 W. Washington
Boise, ID 83702
Re: Case No. PAC-E-IO-Ol
In the Matter of Rocky Mounta Power's Reply Comments to Commission Stas
comments on the matter of the Energy Cost Adjustment Mechansm rate implementation.
Dear Ms. Jewell:
Please find enclosed for fiing an original and seven copies of Rocky Mountain Power's Reply
Comments in the above-referenced matter, along with two Attchments supporting calculation of
the revised deferred balance and Schedule 94 rates.
Informal inquires may be directed to Ted Weston, Idaho Reguatory Manger at (801) 220-
2963.
Jeffy K. Laren
Vice President~ Reguation
Yvonne R. Hogle
201 South Mai Stret, Suite 2300
Salt Lake City, Uta 84111
Telephone No. [phone]
Facsimle No. [phone]
E-mail: yyonne.hogle(fpacificorp.com
Attorney for Rocky Mountain Power
BEFORE THE IDAHO PUBLIC UTILITIES COMMSSION
IN THE MATTR OF THE APPLICATION)
OF ROCKY MOUNTAI POWER FOR) CASENO.PAC-E-IO-Ol
AUTHORITY TO IMPLEMENT POWER)
COST ADJUSTMENT RATES FOR)
ELECTRIC SERVICE FROM APRIL 1, 2010 ) REPLY COMMENTS OF
THROUGH MACH 31, 2011 THROUGH ) ROCKY MOUNAIN POWER
THE ENERGY COST ADJUSTMENT)MECHAISM )
COMES NOW Rocky Mounta Power, a division of PacifiCorp ("Company"),
by and though its attorney of record Yvonne Hogle, in accordance with the Notice of
Comment/rotest Deadline and Notice of Reply Deadline issued on Febru 12, 2010,
and in response to the comments of the Commission sta ("Sta') received Marh 10,
2010, submits the followig reply comments.
BACKGROUND
On Febru 1, 2010, the Company filed Case No. PAC-E-1O-Ol (the
"Application") with the Idaho Public Utilities Commssion ("Commssion") requesting
authority to implement power cost adjustment rates for all customer classes excluding
cert taff contract customers, including Monsanto Company ("Monsanto") and
Agrum, Inc. ("Agrum") to collect $2,170,096 of deferred Net Power Costs (NPC) for
the deferral period of July 1,2009 though November 30, 2009, purt to the Energy
1
Cost Adjustment Mechansm ("ECAM") approved by the Commssion September 29,
2009 in Cas No. P AC-E-08-08, Order No. 30904.
On March 10,2010, afer review and anysis of the Application, Sta submitted
comments proposing two adjustments to the Company's ECAM deferrd balance. Stafs
proposa reduced the amount sought puruat to the Application by $156,434 for Idao~s
allocation of the Goose Crek sale and by an additiona $34,104 to adjust the allocation
of SOi sales. Based on these two adjustments and associated interest, Sta recommended
an ECAM deferral balance of$1,978,865.
COMPAN REPLY COMMNTS
The Company agrees with severa of Stas comments concernng the differences
between ths Application and the prospective applications the Company expects to fie in
the futue. As noted by Sta, this initial Application was for a parial deferral period
coverig the five-month period of July 1, 2009 though November 30, 2009. Sta also
noted tht customer energy usage durng ths period was abnormally low. The Company
agees tht usage was signficantly lower than normal, however; even with the reduced
usage, the NPC Differential was stil $121,504 above the ECAM base NPC. This is an
indication tht NPC continue to increase even with reduced usage. Whle the deferr
period used in ths Application was unque for many reasons, the Company posits that the
ECAM worked as it was designed to do and fuly supports the continued use of the
mechasm.
The firs adjustment Sta proposed was to reduce the ECAM balance by
$156,434 for Idaho's shar of the Goose Creek sale as agreed to by the paries to the
Stipulation in Case No. P AC-E-08-08, Order No. 30904. The day afer the Company filed
ths Application, the Company realized that the Goose Creek adjustment was
2
inadvertently excluded from the Application and notified Staff. The Company agres that
the ECAM deferred balance of $2,170,096 should be reduced by $156,434 for the Goose
Creek sale and by an additional $522 of associated interest, resulting in a new ECAM
balance of $2,013,140.
The second adjustment Sta proposed in their comments was to reduce the
amount sought in the Application by an additional $34,104 for Monsto's and Agrum's
collective shae of the SOi sales made durng the deferr period. The Company opposes
this adjustment because (i) in Order No. 30482 from Case No. PAC-E-07-05 the
Commssion stated: "(t)he cost of serice methodology proposed by the Company in ths
proceeding will remai as the accepted methodology though the maximum durtion of
the rate plans for Agrum and Monsanto, which expire December 31,2010." Stipulation ~
11, (ii) the Order fuer states "(t)he Company agrees that in any rate filing durg the
terms of such rate plan that it will not seek to reover any revenue shortalls related to
Agrum and Monsanto from other Idaho cusomers when compard to cost of service
studies from those fiings." Stipulation ~ 10.
The Company has complied with ths Commssion order by excluding all Agrum
and Monsto (taff contract customers) impacts from the ECAM deferr caculation,
including the NPC Differential, Load Growt Adjustment, SOi Credit, and Renewable
Resource adder. Staff acknowledges that the SOi sales should be allocated to Idaho using
Idao's shae of the system energy factor. However Sta states that; "fuer adjustment
by the percentage representing the taff customer porton of tota Idao load is not
consistent with prior rate case treatment." The Company disagrees with this statement. In
order to comply with Commission Order No. 30482 and ensure that no revenue shortalls
associated with the taff contract customers are sought from other Idaho customers in
3
any rate proceeding, the additional step in the calculation is necessar to exclude the
taff contract customer impact from all components of the ECAM deferral, which is what
the Company has done. Neither the impacts associated with the components of the
ECAM nor the revenue credits related to the SOi saes are being included for the taff
contract customers. Simlar to the treatment in a rate case, jursdictional allocation is first
addressed, followed by customer class allocations. Customer class, or cost of service,
allocation is based on the intr,.jursdiction usage relationship. between customer classes
with the state. Thus it is necessar to first allocate Idaho's share of the tota Company
SOi sales and then adjust or allocate tota Idao SOi sales to the taiff customers,
removing Monsanto's & Agrium's share of the sales. Ths is consistent with the way the
Company excluded Agrum's and Monsanto's shar ofNPC Differential $/MWh (Line 5
from Ms. Shu's Exhbit 1) by only applying taff customers' load to the NPC
Differential $/MWh rate. Had the Company used tota Idaho load to multiply the NPC
Differential $/MWh rate, then:
(i) the NPC Differential would have been $204,247 instead of$121,504,
(ii) the Load Growt Adjustment would have been $3.4 milion rather than
$1.5 millon, and
(ii) the Renewable Resource Adder would have been $1.4 millon rather than
$811,412.
In tota, the ECAM deferral balance would have been $4.5 millon rather than
$2.0 milion. However, the Company acknowledges that ths is counter to Commission
Orders Nos, 30482 and 30904. Therefore, the Company has only deferred and requested
recovery of the taff customers' portion of the ECAM. The Company's position is that it
is not appropriate to ignore the costs associated with the taff contrct cusomers while at
4
the same time tag the SOi revenues as an offset to the ECAM deferral balance. Staff s
adjustment to SOi sales is counter to Commission Orders Nos. 30482 and 30904 which
both specify that Agrum's and Mo'nsato's revenue shortalls and costs would not be
sought from other customers or included in the ECAM until Janua 1,2011.
RECOMMENDATIONS
WHREFORE, Rocky Mountain Power respectfuly requests that the
Commssion accept the Idaho ECAM deferr balance of $2,013,140, as calculated in
Attchment 1 to these comments, which represents the Company's original request of
$2,170,096 adjusted for the Goose Creek sale as agreed to by all paries to the ECAM
stipulation, Order No. 30904. The Company's position is that it is not appropriate to
reduce the ECAM deferral balance by Agrum's and Monsanto's share of the SOi sales
and recommends the Commssion deny Stas adjustment. Alternatively, if the Sta
adjustment is accepted, then corresponding and consistent adjustments must be made to
the other components of the ECAM, including the NPC Differential, Load Growth
Adjustment, and Renewable Resource adder, resulting in a Deferred NPC amount of $4.5
millon.
The Company recommends, based on the ECAM deferral balance of $2,013,140,
that the Commission approve the following loss differentiated energy rates to be included
in Schedule 94. Atthment 2 to these comments support the calculation of the thee loss
differentiated rates listed below:
Seconda Distrbution Rate
Primar Distrbution Rate
Transmission Rate
0.0100 ~/kWh
0.0093 ~/kWh
0.0091 ~/kWh
The Company support Stas recommendation and Order No. 30904 that rates
become effective April 1,2010.
5
Respectfully submitted this 17th day of March 2010.
ROCKY MOUNTAI POWER
i~'M
Yvonne R. Hogle
201 South Mai Stret, Suite 2300
Salt Lake City, Uta 84111
Telephone No. (80l) 220-4050
Facsimile No. [phone]
E-mail: yyonne.hogle(fpacificorp.com
Attorney for Rocky Mountain Power
6
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ATTACHMENT 2
~~~~o~OUNTAIN
I.P.U.C. No.1 Original Sheet No. 94.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 94
STATE OF IDAHO
Energy Cost Adjustment
AVAILABILITY: At any point on the Company's interconnected system.
APPLICATION: This Schedule shall be applicable to all retail tariff Customers taking service
under the Company's electric service schedules.
ENERGY COST ADJUSTMENT: The Energy Cost Adjustment is calculated to collect the
accumulated difference between total Company Base Net Power Cost and total Company Actual Net Power
Cost calculated on a cents per kWh basis.
MONTHLY BILL: In addition to the Monthly Charges contained in the Customer's applicable
schedule, all monthly bils shall have applied the following cents per kilowatt-hour rate by delivery voltage.
Secondary
Schedule 1 0.100Ø per kWh
Schedule 6 0.100Ø per kWh
Schedule 6A 0.100Ø per kWh
Schedule 7 0.100Ø per kWh
Schedule 7A O.lOOØ per kWh
Schedule 9
Schedule 10 0.100Ø per kWh
Schedule 11 0.100Ø per kWh
Schedule 12 O.lOOØ per kWh
Schedule 19 0.100Ø per kWh
Schedule 23 0.100Ø per kWh
Schedule 23A 0.100Ø per kWh
Schedule 24 0.100Ø per kWh
Schedule 35 0.100Ø per kWh
Schedule 35A 0.100Ø per kWh
Schedule 36 0.100Ø per kWh
Delivery Voltage
Primary Transmission
0.093Ø per kWh
0.093Ø per kWh
0.091Ø per kWh
0.093Ø per kWh
0.093Ø per kWh
0.093Ø per kWh
0.093Ø per kWh
0.093Ø per kWh
Submitted Under Case No. PAC-E-I0-0l
ISSUED: March 17,2010 EFFECTIVE: April 1,2010
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%
S5
2
12
1
12
1
13
5
13
5
0
0
0.2
0
/
$3
7
0
1,
9
7
4
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7
4
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$0
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8
1
25
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7
0
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1
7
28
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4
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0
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3
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3
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3
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0
5
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6
2
18
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,
9
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1
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.
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%
SI
4
7
,
7
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1,8
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,
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1
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5
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13
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7
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1
0
6
59
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1
6
9
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6
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8
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2
2,
3
1
6
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1
1
7
1,8
5
1
51
11
9
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1
1.7
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