20090326PAC to IIPA 1-10.pdf

~.
I.j."~ROCKY MOUNTAIN
POWER
A DMSION OF PACIFRP
RE:f~E:!
201 South Main. Suite 2300
Salt Lake City. Utah 84111
ZOU9 MAR 26 Pl1 2: 18
March 25, 2009
Eric Olsen
Idaho Irrgation Pupers Assoc
Racine, Olsen, Nye, Budge & Bailey
201 East Center
Pocatello,ID 83204
RE: PAC-E-08-08
IIPA Data Request (1-10)
Please find enclosed Rocky Mountan Power's Responses to IIPA Data Requests 1-10. Provided
on the enclosed CD are Attachments lIP A 6, 7, and 8 -(,m). Provided on the enclosed
Confdential CD are Confidential Attchments LIP A 8 -( a-j). The Confdential Attchments are
being provided to paries who have signed a confdentiality agreement pursuant to the protective
order in this case.
If you have any questions, please feel free to call me at [phone].
~YNQÛO\
Ted Weston, ~
Manager, Regulation
Enclosures
c.c.: Tony YanelllIIPA
Radall C. Budge/lIP A
Katie Iverson
Jean JewelllIPUC
Scott WoodburlIPUC
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 1
LIP A Data Request 1
Please provide a description of the fuel and/or net power cost recovery
mechanism that is presently in place in each jurisdiction that the Company serves.
Response to lIP A Data Request 1
PacifiCorp currently has power cost tracking mechanisms in place in California,
Oregon and Wyoming with an application pending in Idaho and Utah. Uta
required legislative changes before a mechanism could be implemented. That
legislation was approved in March 2009 and the Company filed its Energy Cost
Adjustment Mechanism (ECAM) application in Uta in March 2009. Utah's
ECAM application is consistent with the application pending in Idaho.
California:
The California Energy Cost Adjustment Clause (ECAC) was approved by the
California Commission in December 2006 with a January 1, 2007 effective date.
The ECAC tracks all net power cost accounts as modeled in GRID, the same
accounts included in the Idaho application. California utilizes a forecast to set the
base for net power costs. The California ECAC tracks actual net power costs
compared to the NPC forecast and resets base net power costs annually. The
California ECAC allows for full recovery of the difference between actual net
power costs and those collected through rates. There are two components to the
ECAC, the offset rate and the balancing rate. The offset rate allows the Company
to update forecasted net power costs that are currently in rates anually. The
balancing rate is used to true-up actual power costs to what was collected in rates
for the prior period. Monthly entries are made to a balancing account and the
balance is recovered from or retured to customers through the balancing rate.
Rates are updated only if the new rates vary +/- 5% or more from current rates.
PacifiCorp updates the rates with a filing each August 1 with rates effective the
following Januar i. No changes have been made to the mechanism since it was
approved.
The California ECAC deferral account balance for 2007 was $599,000 under
recovery and for 2008 the ECAC balance was $183,000 over collection.
Oregon:
The Oregon Public Utilties Commission approved PacifiCorp's Transition
Adjustment Mechanism (TAM) in September 2004 in Order 05-1050 (UE 170).
Net power costs (NPC) in Oregon are recovered through the annual Transition
Adjustment Mechanism (TAM). The TAM updates NPC for supply service
customers and sets the transition adjustment for customers electing to take direct
access in the following year. The TAM includes all NPC accounts, as modeled in
GRID, and is based on a forecast fied anually in April (outside of a general rate
case). This fiing is limited to include only the following updates to PacifiCorp's
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 1
NPC: (1) forward price curve; (2) forecast loads; (3) normalized hydro
generation; (4) forecast fuel prices; (5) contract updates; (6) thermal heat rates,
planed outages and de-rates; (7) wheeling expenses; (8) new resource
acquisitions; and (9) state allocation factors. At the time the Company makes its
rebuttal filing, which is generally at the end of July, PacifiCorp updates the filing
to reflect: (1) the curent forward price cure;. and (2) new contracts and/or
updates for wholesale sales, purchases, fuel and wheeling expenses. After the
Commission's order is issued in the TAM in late October, PacifiCorp incorporates
any Commission-ordered changes and updates costs for a new forward price
curve and for contracts entered into by November 1 for the calculation
of indicative transition adjustments, which are filed by November 8, 2007. There
is one final update for net power costs with the latest forward price cure and
final transition adjustment rates, which is fied by November 15 with rates
effective January 1. No changes to the TAM have been made since it was
established in 2004.
There is no true-up to actual NPC with the TAM.
Wyoming:
The Wyoming Public Service Commission approved PacifiCorp's Power Cost
Adjustment Mechanism (PC AM) in February 2006. The PCAM includes the same
NPC accounts included in the Company's Idaho application, as modeled in GRID.
NPC have been unbundled in Wyoming and are collected through the PC
AM with
anual filings. The Wyoming PCAM has a $40 milion (total company) dead band
above or below the base NPC with sharing ratios outside the dead band. From $40
to $100 milion the sharng ratio is 70/30, from $100 - $200 millon it is 85/15
sharing and over $200 milion it has a 90/1 0 sharing band. The Wyoming PCAM
was implemented as par of a lawsuit and the base NPC were set artificially low.
No changes to the PCAM have been made since it was established in 2006.
Wyoming's PCAM deferral for the 2006 period was $2.4 milion, for the 2007
period it was $31.3 milion and for 2008 the deferral was $26.8 millon.
(J. Ted Weston prepared this response and is the recordholder. Gregory N. Duvall
is expected to sponsor this response at hearing. Please contact J. Ted Weston at
801-220-2963 to discuss this response.)
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 2
LIP A Data Request 2
For each jurisdiction that the Company serves that has a fuel and/or net power
cost recovery mechanism, what was the date when it was first put in place?
. Response to lIP A Data Request 2
Please refer to the Company's response to lIP A Data Request 1.
(J. Ted Weston prepared this response and is the recordholder. Gregory N. Duvall
is expected to sponsor this response at hearing. Please contact J. Ted Weston at
801-220-2963 to discuss this response.)
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 3
LIP A Data Request 3
For each jurisdiction that the Company serves that has a fuel and/or net power
cost recovery mechanism, please describe any changes to that mechanism that
were put in place over the last 10 years. Please list the specific year associated
with any changes.
Response to lIP A Data Request 3
Please refer to the Company's response to lIP A Data Request 1.
(J. Ted Weston prepared this response and is the recordholder. Gregory N. Duvall
is expected to sponsor this response at hearing. Please contact J. Ted Weston at
801-220-2963 to discuss this response.)
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 4
LIP A Data Request 4
For each jurisdiction that the Company serves that has a fuel and/or net power
cost recovery mechanism, please describe the difference between that mechanism
and the mechanism being proposed in this case for Idaho.
Response to IIPA Data Request 4
California's Energy Cost Adjustment Clause (ECAC) utilzes forecasted net
power costs to establish the base which is compared to actual net power costs.
Oregon's Transition Adjustment Mechanism (TAM) also utilzes forecasted net
power costs. However the Oregon TAM has no true-up mechanism it is an anual
reset to net power costs utilzing a forecast.
Wyoming's Power Cost Adjustment Mechanism (PCAM) updates net power costs
anually. The PCAM has a total Company (+/-) $40 milion dead band with
sharing bands after that.
(J. Ted Weston prepared this response and is the recordholder. Gregory N. Duvall
is expected to sponsor this response at hearing. Please contact J. Ted Weston at
801-220-2963 to discuss this response.)
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 5
LIP A Data Request 5
In what way do any non-regulated affiliates share in, contribute to, or are
allocated a share of the costs and/or revenues that go into the net power cost
calculation.
Response to lIP A Data Request 5
PacifiCorp does not allocate any net power costs to any non-regulated affliates.
PacifiCorp purchases coal from Bridger Coal Company, a 2/3 owned subsidiar
that operates the Bridger coal mine. The cost of coal purchased from Bridger is
included in PacifiCorp's net power costs at Bridger's cost of production.
(J. Ted Weston prepared this response and is the recordholder. Gregory N. Duvall
is expected to sponsor this response at hearing. Please contact J. Ted Weston at
801-220-2963 to discuss this response.)
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 6
LIP A Data Request 6
In Case No. PAC-E-07-05, Net Power Cost calculations were contained in Exhibit
11 under Tab 5. Under Tab 5 was included "Study Results" under pages 5.1.2
through 5.1.11. Why weren't similar "Study Results" included under Tab 5 of
Exhibit 12 in Case No. PAC-E-08-07?
Response to lIP A Data Request 6
The "Study Results" pages were not included under Tab 5 of Exhibit 12 due to the
fact that at the time of printing it had not been determined whether or not the
Chehalis acquisition would be treated as confidential or not. However, in the
direct testimony of Gregory N. Duvall, Exhibit No. 14, the Company did provide
monthly net power details. Please refer to Attachment LIP A 6 for the "Study
Results" that would have been included under Tab 5 of Exhibit 12.
(J. Ted Weston prepared this response and is the recordholder. Gregory N. Duvall
is expected to sponsor this response at hearing. Please contact J. Ted Weston at
801-220-2963 to discuss this response.)
IDAHO
PAC-E-08-08
ROCKY MOUNTAIN POWER
IIPA DATA REQUEST (1-10)
ATTACHMENT LIP A 6
ON THE ENCLOSED CD
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 7
LIP A Data Request 7
For any Net Power Cost calculations that were fied in any of
the Company's
jurisdictions during the previous 5 years, please provide in Excel spreadsheets
data similar to that provided in the Net Power Cost calculation in Case No. P AC-
E-07 -05 (including the "Study Results" under pages 5.1.2 through 5.1.11 and
provide this information on a monthly basis).
Response to lIP A Data Request 7
Please refer to Attachment lIP A 1.7 for net power cost calculations fied in the
Company's general rate cases during the previous five years. Monthly net power
cost data has been provided where available.
(1. Ted Weston prepared this response and is the recordholder. Gregory N. Duvall
is expected to sponsor this response at hearing. Please contact J. Ted Weston at
801-220-2963 to discuss this response.)
IDAHO
P AC-E-08-08
ROCKY MOUNTAIN POWER
IIPA DATA REQUEST (1-10)
ATTACHMENT IIPA 7
ON THE ENCLOSED CD
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 8
LIP A Data Request 8
Please provide in electronic format, on an hourly basis, for the period January 1,
2004 through the most recent month available the following data:
a. Total system input (MWH);
b. System input from Company owned generation (stating hydro, coal, and other
generation separately) (MWH);
c. System input from longer term purchases such as those listed on the lower
portion of page 5.1.4, tab 5, Exhibit 11 of Case No. PAC-E-07-05. (MWH and
$);
d. System input (outputs) from exchanges into the system such as those listed on
the middle portion of page 5.1.5, tab 5, Exhibit 11 of Case No. PAC-E-07-05.
(MWH and $);
e. System input from Unit purchases and QF purchase such as those listed on the
upper portion of page 5.1.5, tab 5, Exhibit 11 of Case No. PAC-E-07-05.
(MWH and $);
f. Other system inputs (MWH and $);
g. Requirements (RQ) Wholesale sales (MWH and $);
h. Long-term firm (LF) Wholesale sales (MWH and $);
1. Short-term (SF) Wholesale sales (MWH and $);
J. System Balancing Sales (MWH and $);
k. Inadvertent power flows into or out of the system;
i. Any other power flow information needed to balance the input and the output
m. Total retail load by jurisdiction.
Response to lIP A Data Request 8
a. Please refer to Confidential Attachment lIP A 8a. Data includes all generation
(GEN) accounts regardless of the direction of the megawatts and includes all
market (MKT) accounts in which the megawatts are positive (+), excludes
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 8
inadvertent deviations which are included in the result set for 'T', and includes
only wholesale energy; does not include retaiL.
b. Please refer to Confidential Attachment lIP A 8b. Data includes all generation
accounts (GEN) regardless of the direction of the megawatts except for unit-
contingent generation (IU, LU). Unit contingent generation (GEN with IU or
LU FERC codes) accounts are included in the result set for 'E'.
c. Please refer to Confidential Attachment lIP A 8c. Data includes all firm
purchases - long term (LF), short term (SF) and intermediate firm (IF).
d. Please refer to Confidential Attachment lIP A 8d. Data includes all purchases
and sales that are exchanges (EX).
e. Please refer to Confidential Attachment lIP A 8e. Data includes all unit
contingent purchases. There are two fies included, one for unit purchases and
the other for QF purchases. Since some of the QFs are classified as unit
contingent they may appear in both fies. QF data is combined at the hourly
level due to confidentiality reasons.
f. Please refer to Confidential Attachment IIPA 8f. Data includes all non-firm
purchases (OS).
g. Please refer to Confidential Attachment IIPA 8g.
h. Please refer to Confidential Attachment lIP A 8h. Data includes both long-
term firm (LF) and intermediate firm (IF) sales.
1. Please refer to Confidential Attachment LIP A 8i. Data includes all short-term
firm sales.
J. Please refer to Confidential Attachment IIPA 8j. Data includes all non-firm
sales (OS).
k. Please refer to Attachment lIP A 8k. Data includes market accounts (MKT)
that have a FERC code of DE V regardless of the direction of the megawatts.
L. The Company does not have this information.
m. Please refer to Attachment LIP A 8m. Jurisdictional load data is included.
Confidential information is provided subject to the terms and conditions of
the
protective order in this proceeding.
P AC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 8
(Ray M. Zacharia prepared this response and is the recordholder. Gregory N.
Duvall is expected to sponsor this response at hearing. Please contact J. Ted
Weston at 801-220-2963 to discuss this response.)
IDAHO
P AC-E-08-08
ROCKY MOUNTAIN POWER
IIPA DATA REQUEST (1-10)
ATTACHMENT IIPA 8 -(k, m)
ON THE ENCLOSED CD
IDAHO
PAC-E-08-08
ROCKY MOUNTAIN POWER
IIPA DATA REQUEST (1-10)
CONFIDENTIAL (LEVEL YELLOW)
ATTACHMENT IIPA 8 -(a-j)
ON THE ENCLOSED CONFIDENTIAL CD
P AC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 9
LIP A Data Request 9
At times when the Company's Retail load is approaching its annual peak, is the
Company a net purchaser or seller of electricity to non-retail customers?
Response to lIP A Data Request 9
The Company is a net purchaser at the time when its retail load is approaching its
anual peak.
(Gregory N. Duvall prepared this response, is the recordholder, and is expected to
sponsor the response at hearing. Please contact J. Ted Weston at 801-220-2963 to
discuss this response.)
PAC-E-08-08/Rocky Mountain Power
March 25, 2009
LIP A Data Request 10
I1PA Data Request 10
If the Company is a net purchaser at the times when the Company's Retail load is
approaching its anual peak, please answer the following:
a. How long has this situation existed as opposed to being a net seller?
b. What plans does the Company have to become a net seller during times of its
Retail load approaching its anual peak?
Response to IIPA Data Request 10
a. This situation has existed for at least 10 years. Records are not available to
indicate exactly how long this situation has existed.
b. The Company does not have plans to become a net seller during times of its
retail load approaching its anual peak.
(Gregory N. Duvall prepared this response, is the recordholder, and is expected to
sponsor the response at hearing. Please contact J. Ted Weston at 801-220-2963 to
discuss this response.)