20150710PAC to Staff 1-7.pdf

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July 9,2015
Jean Jewell
Idatro Public Utilities Commission
472W. Washington
Boise,ID 83702-5918
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RE: ID PAC-E-15-09
IPUC 1't Set Data Request (1-7)
Please find enclosed Rocky Mountain Power's Responses to IPUC Data Requests 1-7. Also
provided are Attachments IPUC 1,2,3, 4,5,6, and 7.
If you have any questions, please feel free to call me at [phone].
Sincerely,
J TtL t"X.(r,^ I prs
J. Ted Weston
Manager, Regulation
201 South Maln, Sulte 2300
Salt Lake City, Uah 84lll
PAC-E-15-09 / Rocky Mountain Power
July 9, 2015
IPUC Data Request I
IPUC Data Request I
Please provide the actual net power costs for the 12 months ending December 31,
2014 in similar format as witness Wilding's Exhibit No. l.
Response to IPUC Data Request I
Please refer to Attachment IPUC l.
Recordholder: Michael Wilding
Sponsor: Michael Wilding
PAC-E-15-09 / Rocky Mountain Power
July 9, 2015
IPUC Data Request 2
IPUC Data Request 2
Using the actual net power costs derived above in Response to Production
Request No. l, please show how this actual 2014 data is linked to Wilding's
Exhibit No. 2 and provide a new spreadsheet of Wilding's Exhibit No. 2 with the
actual 2014 net power costs.
Response to IPUC Data Request 2
Please refer to Attachment IPUC 2.
Recordholder: Michael Wilding
Sponsor: Michael Wilding
PAC-E-I5-09 lRocky Mountain Power
July 9, 2015
IPUC Data Request 3
IPUC Data Request 3
Please provide monthly base and actual Production Tax Credit amounts for both
the System and Idaho Jurisdiction for the past three ECAM deferral periods.
Response to IPUC Data Request 3
The annual base Production Tax Credits (PTC) in rates are $69,689,495 md
$4,217,95T for total Company and Idaho allocated, respectively. As these
amounts are tax credits, they must be grossed up to account for taxes to accurately
depict their impact on revenue requirement. Attachment IPUC 3 provides the
gross up calculation, which results in a total revenue requirement impact of
Sl 12,313,647 and56,797,775 for total Company and Idaho, respectively. This
amount was determined in the last general rate case (GRC) Case No. PAC-E-I l-
12 and has been effective for all of the last three Energy Cost Adjustment
Mechanism (ECAM) deferral periods. Monthly base amounts were not
determined as part of the last GRC. Attachment IPUC 3 also provides the actual
PTCs by month.
Recordholder: Michael Wilding
Sponsor: Michael Wilding
PAC-E-I5-09 lRocky Mountain Power
July 9,2015
IPUC Data Request 4
IPUC Data Request 4
Please provide monthly base and actual DSM cost amounts for both the System
and Idaho Jurisdiction for the past three ECAM deferral periods.
Response to IPUC Data Request 4
Please refer to Attachment IPUC 4, which provides base and actual Class I
demand-side management (DSM) costs for the past three deferral periods. Class I
DSM expenses were only included in the Energy Cost Adjustment Mechanism
(ECAM) beginning with the 2013 ECAM defenal period. For purposes of this
request Base DSM for the 2012ECAM deferral period is assumed to be the
amount included in Case No. PAC-E-ll-l2. Base DSM costs were set using an
annual figure; for purposes of the ECAM the base DSM was shaped monthly
proportionate to the actual monthly DSM costs.
Recordholder: Michael Wilding
Sponsor: Michael Wilding
PAC-E-I5-09 lRocky Mountain Power
July 9, 2015
IPUC Data Request 5
IPUC Data Request 5
Please provide monthly base and actual loads measured at customer meter for the
system and Idaho Jurisdiction for past three ECAM deferral periods.
Response to IPUC Data Request 5
Please refer to Attachment IPUC 5. Total system base loads at meter are not
prepared as part of the rate making process. To set rates in ldaho only Idaho
jurisdictional loads at meter are used.
Recordholder: Michael Wilding
Sponsor: Michael Wilding
PAC-E-15-09 / Rocky Mountain Power
July 9, 2015
IPUC Data Request 6
IPUC Data Request 6
Please provide monthly base and actual Quali&ing Facility (QF) costs included in
NPC for both System and Idaho Jurisdiction for the past three ECAM deferral
periods.
Response to IPUC Data Request 6
Please refer to Attachment IPUC 6.
Recordholder: Michael Wilding
Sponsor: Michael Wilding
PAC-E-I5-09 / Rocky Mountain Power
July 9,2015
IPUC Data Request 7
IPUC Data Request 7
Please provide an explanation and the analysis used to determine the loads at
customer meter for determining customer rates. Please reconcile this with loads
used to determine the proposed NPC of $ I .514 billion to be embedded in base
rates. Please provide all work papers with formulas intact.
Response to IPUC Data Request 7
Please refer to Attachment IPUC 7, which contains the development of the
normalized loads at meter by schedule from customerso monthly bills for the
period of January 2014 to December 2014. The proposed Total Company net
power costs (NPC) of $ 1 .5 1 4 billion is determined based on Total Company
weather normalized loads at input for the period of January 2014 to December
2014. Total Company weather normalized loads are developed by distributing the
monthly weather normalization at input to each hour of the corresponding
month. This apportioning process is based on the difference between the normal
daily weather and the actual daily weather; the resulting variation is multiplied by
the estimated temperature response. Total Company load at input is calculated by
adding all generation in PacifiCorp's control area, adding all inputs into the
control areaattie lines, subtracting all exports from the control area at tie lines,
and subtracting out third party load in the control area to arrive at PacifiCorp load
within the control area. PacifiCorp load outside the control area is then added to
arrive at total PacifiCorp load.
Recordholder: James Zhang, Mike Wilding
Sponsor: Joelle Steward, Mike Wilding