20050404PAC response IIPA requests 1-40.pdf

825 N.E. MuItnomah
Portland, Oregon 97232
[phone]
CEIVED
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UT\LftIES COt"1f~'\iSS1ON
PACIFIC POWER UTAH POWER
March 18, 2005
Eric L. OlsenISB#-81l--- n _._m. - ------
- - --- --
RACINE, OLSON, NYE, BUDGE &
BAILEY, CHARTERED
O. Box 1391; 201 E. Center
Pocatello, Idaho 83204-1391
RE:ID PAC-05-
IPP A Data Requests 1-
Please find enclosed PacifiCorp s Response to IPP A I?ata Request NUMBERS 1-40. Provided
on the enclosed CD are Attachments lIP A 1 H-, 2 D, 4-(1-6), 6, 17-(1-2), 18, 24-(1-3), 33 , 38
39-(1-2), and 40.
If you have any questions, please call Barry Bell at [phone].
Sincerely,~k\
~~
Ip.
Bob Lively, Manager
Regulation
Enclosures
cc:Katie Iverson/lIP A
Randall C. Budge/lIP A
James R SmithIMonsanto
James Fell/Stoel Rives
P AC-05-/Paci fi Corp
March 18 , 2005
lIP A Data Request
liP A Data Request 1
Please answer the following with respect to information contained on Weston
Exhibit 9, Tab 10 entitled "Allocation Factors
A. On page 3, are these the actual generation level energy and demand values
recorded for each jurisdiction during each of the months specified?
B. Do the energy and demand values for Idaho on page 3 include Monsanto?
I '
C. Are the values/adjustments on page 4 simply weather related adjustments?
these adjustments are more than simply weather related adjustments, please
provide a breakdown of these values that relate to weather adjustments and those
that relate to other adjustments (please provide specific detail for each "other
adjustment).
D. Are the demand and energy values on page 5 the ones used to form the basis for
such system allocators as SC and SE?
E. Are the values on page 5 simply the summation of the actual data on page 3 plus
the adjustments on page 4? If this is not the case, please explain.
F. !he Idaho demand value for January 2004 on page 3 is 366.91 MW and the
adjustment for demand for January 2004 on page 4 is-15.22 MW. How is the
figure of 421.7 MW on page 5 for January 2004 derived?
G. For each of the adjustments listed on page 4, what rate schedules or special
contract customer consumptions were adjusted in each month?
H. Please provide an electronic as well as hard copy of all workpapers that supportthe adjustments on page 4.
Response to liP A Data Request 1
Yes.
Yes.
The adjustments on Page 4 are weather only adjustments.
Yes. The allocation code percentages for the System Capacity (SC) factor
System Generation (SG) factor and the System Energy (SE) factor are derived
from the demand and energy values presented on Exhibit 9, Tab 10, Page 5.
P AC-05-1/PaciftCorp
March 18, 2005
lIP A Data Request
No. Exhibit 9, Tab 10, Page 5 Demand values for Idaho are the summation of
Exhibit 9, Tab 10, Page 6 values. Likewise, Exhibit 9, Tab 10, Page 5 Energy
values are the summation of Exhibit 9, Tab 10, Page 7 values. See response to
part F below for a further explanation as to the compilation of the values
presented on Exhibit 9, Tab 10, pages 6 and 7 values.
Exhibit 9, Tab 10, Page 6 Demand values for Idaho are the summation of
Exhibit 9, Tab 10, Page 3, Page 4 and the Monsanto buy-through curtailment
adjustments shown on Attachment lIP A 18. Likewise, Exhibit 9, Tab 10
Page 7 Energy values are the summation of Exhibit 9, Tab 10, Page 3, Page 4
and the Monsanto buy-through curtailment adjustments shown on Attachment
lIP A 18.
The 421.7 MW figure presented on Exhibit 9, Tab 10, Page 5 for Idaho for the
period of January 2004 is derived as follows:
MW Value
366.
15.
70.
421.70
Explanation
Idaho MW Demand Value
Idaho MW Temperature Value Adj
Monsanto Curtailment
Idaho MW Demand Value
Reference
Exhibit 9, Tab 10, Page
Exhibit 9, Tab 10, Page 4
A ttachm ent lIP A' 1 E
Exhibit 9, Tab 10, Page
The adjus~ments are for the following rate schedules
Oregon- Schedules 4, 25
Washington - Schedules 16
Idaho- Schedules 1 , 23
Wyoming- Schedules 1
Califomia- Schedules 1 , 25,
Utah- Schedules 1 , 6, 23
H. The requested information is provided as Attachment lIP 1 H-l and lIP A IH-
on the enclosed CD.
(J. Ted Weston will sponsor this response at hearing.
\ '
IDAHO
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4
IDAHO
PAC-O5-
GENERAL RATE CASE
ACIFICORP
TT ACHMENT lIP A 1 H-
ON THE ENCLOSED CD
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 2
liP A Data Request 2
, Please answer the following with respect to information contained on Taylor
Exhibit 24, Tab 5 "Cost of Service Allocation Factors
A. Are the times of the system peaks listed on page 6 the same as the actual
coincident system peaks during each of those months?
B. Are the times listed on page 6 on Pacific or Mountain time?
I '
C. With respect to the data listed on pages 7 and 10, which data came from the
Company s load research data and which data came from census data?
D. What was the level of curtailment/interruption for each customer class or
Monsanto during the times of each of the monthly peaks listed on page 7?
E. Is there any weather normalization of the Distribution Peak data on page 11 or
the Non-Coincident Peak data on page 13? If this data is weather normalized,
please provide an electronic as well as hard copy of all workpapers used to
support this normalization.
Response to liP A Data Request 2
A. Yes.
B. Mountain Time.
C. The data listed on pages 7 and 10 come from the Company s load research
data. Loads for Schedule 9 customers over 1 MW and the two special
contracts are based on census data and loads for other classes are based on
load research sample data.
D. The level of curtailment/interruption for the irrigation class is reflected in the
monthly peaks listed on page 7. The Idaho 2003 Irrigation Load Control
Credit Rider Program Impact Evaluation Report is provided as Attachment
Response lIP A 2 D on the enclosed CD. Table 1.4 of this report provides
estimates of the avoided demand realized by control period for 2003.
Monsanto is considered an Ancillary Service contract. The interruptions to
Monsanto are not considered reductions in load, but rather the acquisition of
resources to meet loads. In that case any load reduction as a result of physical
curtailments at the request of the Company is added back to Monsanto
E. Monthly Class Peak Demands were based on sample data which provided a
load shape for the test period. The load shape was then adjusted, up or down,
by month, to tie to the Energy reported in the Operating Statements of the
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 2
Company: A final monthly adjustment was made to the load shape to account
for such things as unbilled and weather adjustments. Attachment lIP A 2 E
provides the temperature adjustment summary report.
(David L. Taylor will sponsqr this response at hearing.
I "
IDAHO
PAC-O5-
GENERAL RATE CASE
ACIFICORP
TT A CHMENT lIP A 2 D
ON THE ENCLOSED CD
IDAHO
PAC-O5-
GENERAL RATE CASE
ACIFICORP
ATTACHMENT lIP A 2 E
...
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P AC-05-1/PacifiCorp
March 18, 2005
, lIP A Data Request 3
liP A Data Request 3
Please answer the following with respect to information contained on Weston
Exhibit 9,'Tab 10 entitled "Allocation Factors" and Taylor s Exhibit 24, Tab 5
Cost of Service Allocation Factors
\ "
A. The demand value for January 2004 for Idaho on Ex. 9 , Tab 10, page 5 is
421.7 MW, while the total value on Ex. 24 , Tab 5, page 6 for January 2004 is
465.361 MW. Please reconcile these two figures. If additional data is
required to reconcile all of Ex. 9, Tab 10, page 5 figures, with Ex. 24, Tab 5,
page 6, please provide that data.
B. On Ex. 24, Tab 5, page 14 there is listed a total annual energy figure of
147 807 MWH. On Ex. 9, Tab 10, page 5 the total Idaho annual energy is
listed as 3,719 256 MWH. Please reconcile these two figures.
Response to liP A Data Request 3
The State load data that is used for jurisdictional allocation will not reconcile to
tl)e sum of the Class loads used in the cost of service study because they are
calculated differently. Because the metering points and the treatment of losses are
different between the two calculations, the numbers will not match.
For an historical test period, the hour of system peak is based on actual metered
load data at specific metering points. For each hour of the month, all inputs into
the system such as Company owned generation, purchases or interchanges are
measured. From that measurement, all deliveries outside the system or to non-
retail customers are deducted to arrive at total retail load. The Coincident Peak is
the hour of each month during which the combined demand of all retail customers
is the greatest.
Each State s contribution to hourly loads is determined in essentially the same
way. Each State s hourly load consists of the Company owned generation within
that State, purchases or interchanges delivered into the State, plus metered flows
of energy into the State from other parts of the PacifiCorp system. From that
measurement, metered and/or scheduled energy flows out of the State and
deliveries to non-retail customers are deducted to arrive at that State s retail load.
As described in the response to lIP A 4, Class peak load data is either measured or
estimated at the sales level (at the customer meter) and then adjusted up to the
input (Generation) level by the use of historical loss factors.
The same differences occur in measuring Jurisdictional and Class energy usage.
Jurisdictional energy usage is measured at the same metering points as the
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 3
system peak data. Class energy usage is based on billed energy at the customer
meter and grossed up to the input level by the 'use of historical loss factors.
A. While the values do not match on an individual month basis, the sum of the 12
CP values in the two exhibits are very close. A comparison of Ex. 9, Tab 10
page 5 line 23, (5,566.1 total MWs), with the total from Ex. 24, Tab 5 page 6
line 35, (5,612.924 MWs), shows a difference of less than 10/0.
B. The total annual energy figure of2 147 807 MWH from Ex. 24, Tab 5, page
14 does not include 1 504 671 MWH's associated with Monsanto. Including
Monsanto in Ex. 24, Tab 5 page 14 brings the new total of 3,652,478 MWHs,
which is within 1.80/0 of the total MWHs shown on Ex. 9, Tab 10, page
(David L. Taylor will sponsor this response at hearing.
P AC- E-O5-/PacifiCorp
March 18, 2005
lIP A Data Request 4
liP A Data Request 4
With respect to the Company s Load Research data, please provide for each
sample customer with valid data that was sampled between January 2002 and the
most recent month available the following:
A. Customer identification number;
B. Customer rate schedule;
I "
C. Strata to which it belongs;
D. Raw hourly usage data-(he.unadjusted, simply the data-originally gathered
for each sample);
E. Raw hourly usage data modified to reflect losses;
F. On an hourly basis, any additional calibrations that are applied to the Load
Research data before it is applied to develop the allocation factors used in the
Company s cost of service study in this case.
G. Please provide copies of the formulas (and data) used to expand the Load
Research data up to the population as a whole as used in the class cost of
service study in this case. This information should include number of
customers in the population of each class.
Response to liP A Data Request 4
Load research estimates have been developed for the test period only and
therefore will be provided for April 2003 to March 2004. Additionally, load
research studies were not installed on Rates 006, 023, 019, 008 , and 035 'during
the test period. Class load estimates for these rates were obtained using historical
data. Furthermore, data collection was not conducted for Rates 001 and 036 for
April 2003 - July 2003 , due to manpower issues. Class loads for these rates were
also estimated using historical data.
Rate 001 was estimated for April - July using an average of 1991-1994 Rate 001
load.
Rate 036 was estimated for April- July using an average of 1991-1994 Rate 036
loads.
Rate 006 was estimated using historical average loads from 1998-2000.
Rate 023 was estimated using historical average loads from 1998-2000.
Rate 008 was estimated using historical average loads from 1997-1999.
Rate 019 was estimated using historical average loads from 1998-2000.
Rate 035 was estimated using historical average loads from 1998-2000.
P AC-O5-1/PaciftCorp
March 18, 2005
lIP A Data Request 4
Street lighting was estimated using prior year data.
I Please refer to Attachments lIP A 4-1 ,3, and 4-4, on the enclosed CD, for
sample data collected for each sample customer from April 2003 to March 2004
as follows:
Rate 001
Rate 036
Rate 010
Rate 009
Attach lIP A 4-xls
Attach lIP A 4-xls
Attach lIP A 4-xls
Attach IIPA 4-xls
A. Customer identification number is contained in column A of each file, please refer
to attachments lIP A 4-1, 4-2, 4-3 & 4-4;
B. Customer rate schedule is contained in cell Al of each file, please refer to
attachments lIP A 4-, 4-, 4-3 & 4-
C. Strata to which it belongs is contained in column C of each file, please refer to
attachments lIP A 4-1, 4-2, 4-3 & 4-
D. Raw hourly usage data (Le., unadjusted, simply the data originally gathered for
each sample) is ,contained in columns D - AA of each file, please refer to
attachments lIP A- 4-, 4-, 4-3 & 4-
E. Raw hourly losses for each rate schedule are detailed below:Rate 001 Secondary
Rate 036 Secondary
Rate 010 Secondary
Rate 009 Primary
Secondary loss factor 14.6680/0
Primary loss factor 10.418%
Transmission loss factor 5.6970/0
F. Two adjustments are made to the load research hourly data prior to input into the
cost of service study. Please refer to attachment lIP A 4-5 on the enclosed CD. for
the adjustment factors for these two calibrations.
Sample data is adjusted on a monthly basis to match the billed energy as reported
in the Company s Operating Statements. Please refer to attachment lIP A 4-6 on
the enclosed CD, tab 1 for a comparison of the estimated kWh energy as derived
from the sample against the actual calendar adjusted billed kWh energy for the
entire rate population. Factors developed on Tab 1 are applied to every hour for
each month for each rate.
P AC-O5-1/PacifiCorp
March 18, 2005
lIP A Data Request 4
Similarly, load research kWh estimates adjusted to population billing are then
compared to kWh energy figures that have been adjusted by the Regulation
Group. Please refer to Tab 2 of attachment lIP A 4-6. Likewise, hourly data for
each month for each rate are adjusted to match the kWh energy supplied by theRegulation Group.
\ "
G. Formulas as requested.
For any given time interval the load research estimate (y) is equal to the sum of
the weighted stratum averages (W nYh).
Y =~ WhYh
Monthly billing adjustments are derived using the following formula:
_._,---- ... . .-- ---- _
n y
(y*
(Y m IYffi)*(Y-a/Ya))n
___,..
Where Y= adjusted load research estimate
Where y= unadjusted load research estimate
Where Y m= Billed calendar monthly customer energy
Where Ya = Regulatory annual adjusted customer energy
Strata weight factors and populations are detailed for each load research sample in
header of each of the following attachments:
Attach lIP A 4-xls
Attach lIP A 4-xls
Attach lIP A 4-xls
Attach lIP A 4-xls
(David L. Taylor will sponsor this response at hearing.
IDAHO
'---
_n -
-- - -
A C- O5-
GENERAL RATE CASE
ACIFICORP
ATTACHMENT lIP A 4-(1-
ON THE ENCLOSED CD
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 5
lIP A Data Request 5
, In January 2002 the Company developed/presented a "Load Research Status
report in Utah. Does something similar exist for the Idaho jurisdiction? If so,
please provide a copy and indicate if there have been any changes to th~ Load
Research Program since that report was written.
Response to liP A Data Request 5
\ "
A similar report does not exist for the Idaho Jurisdiction. However the Company
offers the following information regarding the Utah report. The 2002 Load
Research Status Report was developed at the request of the Utah PSC under the
direction of the Division-of Public Utilities. The report detailed load research
activities in Utah and therefore did not relate to Idaho.
Changes of significance since the January 2002 Load Research Status Report can
be summarized as follows:
1. Load Research hourly loads are no longer calibrated to jurisdictional hourly
loads.
2. No new sample plans are being implemented for the Utah Irrigation Class as a
result of an agreement to spread any future cost allocations on a system
average basis.
3. A residential time-of-use load study was implemented in the State of Oregon.
4. A new system (ITRON - MV90) for collecting, processing and reporting load
research data was implemented and replaced all legacy "load research"
systems in June 2002. To the extent possible, historical data files were
transferred to the new MV90 system and operations on most legacy systems
has been terminated.
5. New load studies are being implemented in Idaho on Rate 006 and 023, in
Washington on Rate 024, and in Wyoming on rates 006 & 206.
(David L. Taylor will sponsor this response at hearing.
P AC- E-05-/PacifiCorp
March 18, 2005
lIP A Data Request 6
liP A Data Request 6
I Previously the Company developed hourly calibrations that calibrated the Load
Research data such that the summation of the (population expanded) Load
Research data and the Gensl\s data equaled the Company s "Operations Stat" or
border loads. The Company may no longer be applying these calibrations to the
Load Research data, but the data is still of interest. On an hourly basis from
January 2002 through the most recent month available, please provide:
A. The "Operations Stat" or border load;
B. The summation of the (population expanded) Load Research data and the
Census data that would reflect what the Company measured or estimated as its
internal customer load for each rate schedule or customer group;
C. The hourly load for each rate schedule or special contract customer that is
measured or calculated on a census basis as opposed to using load research
data;
D. Any other load that is contained in "" above but is not addressed in "" above
(please specify the type of load); and
E. Any information such as difference in measuring techniques or timing of the
data that needs to be addressed when comparing the above data.
Response to liP A Data Request 6
A. Please refer to attachment lIP A 6 on the enclosed CD for the "Operations
Stat" or border load for the State of Idaho. It is detailed for each hour of the
test period in attachment lIP A 6 in column C.
B. Please refer to attachment lIP A 6 on the enclosed CD for hourly data for all
rate classes in Idaho.
C. Please refer to attachment lIP A 6 on the enclosed for the hourly load for each
rate schedule or special contract customer that is measured or calculated on a
census basis as opposed to using load research data, in columns E, S, and T.
D. Please refer to attachment lIP A 6 on the enclosed CD. Loads that are
contained in "" above but are not addressed in "" above include Street
Lighting loads, detailed in columns 0, P, Q, and R.
E. When comparing Idaho State border line loads against actual measured loads
correct loss factors need to be applied, adjustments at tie-line points need to be
estimated accurately, and every meter has to be time synchronized
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 6
(adjustments for daylight savings time). It should be noted that the load research
estimates are, in fact, estimates.
(David L Taylor will sponsor this response at hearing.
\ "
- .. ,-,- _n______---
------ ---~-_..- .. --..-----..- - -- -- -
IDAHO
--..--, .--,..-.-
"--..-n'____"'_n
PAC-O5-
GENERAL RATE CASE
ACIFICORP
TT A CHMENT lIP A 6
ON THE ENCLOSED CD
P AC-05-/PacifiCorp
March 18, 2005
, lIP A Data Request 7
liP A Data Request 7
Please provide for each month from January 2002 forward a copy of the results of
all checks that the Company makes regarding how well the load research data
reflects the actual population usage.
Response to liP A Data Request 7
\ '
Please refer to Attachment lIP A 4-6. Checks that the Company makes regarding
how well the load research data reflects actual population usage are detailed in
Tab 1 , where sample estimated kWh energy is compared to actual calendar
adjusted billed kWh energy.
(David L. Taylor will sponsor this response at hearing.
P AC-05-1/PacHiCorp
March 18, 2005
lIP A Data Request 8
liP A Data Request 8
I Please provide a copy of any summary reports that have been produced between
January 2002 and the present.
Response to liP A Data Request 8
Summary reports are available only for test period months and therefore will be
provided only for April 2003 to March 2004. Please refer to Attachment lIP A 4-
(David L. Taylor will sponsor this response at hearing.
P AC-O5-1/PacifiCorp
March 18, 2005
lIP A Data Request 9
liP A Data Request 9
This filing used weather-normalized data for developing allocation factors in the
jurisdictional allocations and presumably the class cost-of-service study. For each
, rate schedule, please provide all workpapers as well as a description of the flow
(manipulation) of data from historic load research or consensus data to projected
test year energy, coincident demands, and non-coincident demands.
Re~ponse to liP A Data Request 9
Please refer to lIP A Data Request 2 E.
(David L. Taylor will sponsor this response at hearing.
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 10
liP A Data Request 10
Please ,provide a copy of the bill frequency distribution for each month of the test
year as well a~ each month from January 2002 through the most recent month
available for each rate schedule that is weather normalized. Distributions can be
provided in a manner that is convenient for the Company,
Response to liP A Data Request
The Company does not prepare a bill frequency distribution as part of its rate case
filing process. The Company does prepare temperature normalized annual billing
determinants for the rate case test period. Please refer to Exhibit 29 for the annual
billing determinant detail filed within this case. Additionally, please refer to
Exhibit 28 for the monthly billing comparisons that show the bill impacts at
various usage levels when applying the Company s proposed price changes for
each rate schedule.
(William R. Griffith will sponsor this response at hearing.
P AC-05-1/PacifiCorp
March 18, 2005
, lIP A Data Request
liP A Data Request
Please provide in electronic format for the period January 1, 2003 through the
most recent month available hourly data similar to that provided in CCS Request
. 9.2 in the most recent Utah rate case Docket 04-035-42.
Response to liP A Data Request
\ '
This response is still being prepared and will be provided as soon as it is
completed. It is expected to be completed within approximately one week.
(Stan K. Watters will sponsor this response at hearing.
.. ----- -~....,. -- -- . ....- .-- ,
P AC-O5-1/PaciftCorp
March 18, 2005
lIP A Data Request 12
liP A Data Request 12
I Are the Short Term Firm Sales listed on Ex. 9, Tab 5, page 5 related to actual test
year sales, or are they simply a function of the net power cost model picking this
source of supply at any given hour?
Response to liP A Data Request 12
The Short Term Firm Sales/Purchases presented on the Company s Net Power
Cost report represent actual transactions entered by the Company to balance loads
and resources, as of the day the data were extracted. The Short Term Firm
Sales/Purchases included in the Net Power Cost were all transactions entered into
by the Company as of November 11 , 2004,Hfor the proforma period April 2004-
March 2005.
The System Balancing Sales/Purchases presented on the Company s Net Power
Cost report represent the power cost model's balancing of the Company s system
at the time of delivery. The power cost model does have the ability to make
Opportunity" Purchases and Sales, if the transmission between markets is
available. These types of transactions are included in the System Balancing
Sales/Purchases sections of the Net Power Cost report.
(Mark T. Widme~ will sponsor this respor:'se at hearing.
P AC-05-1/PacifiCorp
March 18 , 2005
lIP A Data Request
liP A Data Request
With respect to Ex. 9, Tab 5, page 5 , do the System Balancing Sales relate to
actual sales that may have occurred during the test year, or are they something
, picked by the net power cost model?
Response to liP A Data Request
Please refer to the Company s response in lIP A Data Request 12.
\ '
(Mark T. Widmer will sponsor this response at hearing.
P AC- E-OS-l /PaciftCorp
March 18 , 2005
lIP A Data Request 14
lIP A Data Request
I In actual operation, would the "Balancing Sales
" '
used in the net power cost model
be Opportunity Sales, Short-Term Firm, or something else? Please specify the
approximate percentage of different types of actual sales that would make up the
Balancing Sales" used in the net power cost model.
Response to lIP A Data Request
Please note the power cost model does not distinguish between types of
transactions that the linear program logic makes to balance the system in the least
cost. However, the Company expects that a very high percentage of the
transa-ctions are short~term--firm transaet-ion-s,-Gensi-stentwith actual operation.
(Mark T. Widmer will sponsor this response at hearing.
P AC-05-1/PacifiCorp
March 18, 2005
. lIP A Data Request
liP A Data Request
In actual operation, would the "Balancing Purchases" used in the net power cost
model be 'Opportunity Purchases, Short-Term Firm, or something else? Please
specify the approximate percentage of different types of actual sales that would
make up the "Balancing Purchases" used in the net power cost model.
Response to liP A Data Request
I '
Please refer to the Company s response to lIP A Data Request 14.
(Mark T. Widmer will sponsor this response at hearing.
P AC-05-1/PaciftCorp
March 18, 2005
lIP A Data Request 16
liP A Data Request 16
I Please provide in eh~ctronic format a listing of the date, time, and estimated
magnitude of all actual hourly curtailments/interruptions that occurred during the
test year in Idaho separated by rate schedule or special contract customer.
outright curtailments/interruptions are treated differently than "buy-throughs
please state each separately.
Response to liP A Data Request 16
Idaho irrigation interruptions for Summer 2003 and 2004 are provided as Attach
lIP A 16-1. Additional requested information regarding curtailments of special
- ---
contract-custo-mersi-s-f'r0-vided-as-A-ttac-h,-IIRAJ-2.-Ther.e_currently. no buy-
throughs in Idaho.
(Stan K. Watters will sponsor this response at hearing.
\ '
IDAHO
P A C- O5-
GENERAL RATE CASE
ACIFICORP
ATTACHMENT lIP A 16-
Magnitude of Idaho Irrigation Load Curtailments: 2004
All curtailments occurred between the hours of 2:00p
(14:00) and B:OOp (20:00) hours inclusivf!1
Summer 2004 DataDate Day of Week Day-of-Week6/1/2004 3 Tuesday6/2/2004 4 Wednesday6/3/2004 5 Thursday6/4/2004 6 Friday6/5/2004 7 Saturday6/6/2004 1 Sunday
6n/2004 2 Monday
6/8/2004 3- Tuesday--- _m.,
6/9/2004 4 Wednesday6/10/2004 5 Thursday6/11/2004 6 Friday6/12/2004 7 Saturday6/13/2004 1 Sunday6/14/2004 2 Monday6/15/2004 3 Tuesday6/16/2004 4 Wednesday6/17/2004 5 Thursday6/18/2004 6 Friday6/19/2004 7 Saturday6/20/2004 1 Sunday6/21/2004 2 Monday6/22/2004 3 Tuesday6/23/2004 4 Wednesday6/24/2004 5 Thursday6/25/2004 6 Friday6/26/2004 7 Saturday6/27/2004 1 Sunday6/28/2004 2 Monday6/29/2004 3 Tuesday6/30/2004 4 Wednesday7/1/2004 5 Thursday7/2/2004 6 Friday7/3/2004 7 Saturday7/4/2004 1 Sunday7/5/2004 2 Monday7/6/2004 3 Tuesday7/7/2004 4 Wednesday7/8/2004 5 Thursday7/9/2004 6 Friday7/10/2004 7 Saturday7/11/2004 1 Sunday7/12/2004 2 Monday7/13/2004 3 Tuesday7/14/2004 4 Wednesday7/15/2004 5 Thursday7/16/2004 6 Friday7/17/2004 7 Saturday7/18/2004 1 Sunday7/19/2004 2 Monday
Page 1
kW avoided (2004)
35,897.
286.
35,897.
N/A
N/A
N/A
32,286.
- - __-,
35,897~ 7- u
286.
35,897.
N/A
N/A
N/A
32,286.
35,897.
32,286.
35,897.
N/A
N/A
N/A
32,286.
35,897.
32,286.
35,897.
N/A
N/A
N/A
32,286.
35,897.
286.
33,283.
N/A
N/A
N/A
30,998.
283.
30,998.
33,283.
N/A
N/A
N/A
30,998.
33,283.
30,998.
33,283.
N/A
N/A
N/A
30,998.
Summer 2003 DataDate Day of Week Day-ot-Week6/1/2003 1 Sunday6/2/2003 2 Monday6/3/2003 3 Tuesday6/4/2003 4 Wednesday6/5/2003 5 Thursday6/6/2003 6 Friday
6n/2003 7 Saturday
6J8L2.o0~ J__~lJnday6/9/2003 2 Monday6/10/2003 3 Tuesday6/11/2003 4 Wednesday6/12/2003 5 Thursday6/13/2003 6 Friday6/14/2003 7 Saturday6/15/2003 1 Sunday6/16/2003 2 Monday6/17/2003 3 Tuesday6/18/2003 4 Wednesday6/19/2003 5 Thursday6/20/2003 6 Friday6/21/2003 7 Saturday6/22/2003 1 Sunday6/23/2003 2 Monday6/24/2003 3 Tuesday6/25/2003 4 Wednesday6/26/2003 5 Thursday6/27/2003 6 Friday6/28/2003 7 Saturday6/29/2003 1 Sunday6/30/2003 2 Monday7/1/2003 3 Tuesday7/2/2003 4 Wednesday7/3/2003 5 Thursday7/4/2003 6 Friday7/5/2003 7 Saturday7/6/2003 1 Sunday/2003 2 Monday7/8/2003 3 Tuesday7/9/2003 4 Wednesday7/10/2003 5 Thursday7/11/2003 6 Friday7/12/2003 7 Saturday7/13/2003 1 Sunday7/14/2003 2 Monday7/15/2003 3 Tuesday7/16/2003 4 Wednesday7/17/2003 5 Thursday7/18/2003 6 Friday7/19/2003 7 Saturday
kWavoided (2004)
N/A
20,533.
19,012.
20,533.
19,012.
N/A
N/A
N/A
20,533.
19,012.
20,533.
19,012.
N/A
N/A
N/A
20,533.
19,012.
20,533.
19,012.
N/A
N/A
N/A
20,533.
19,012.
20,533.
19,012.
N/A
N/A
N/A
20,533.
19,012.
20,533.
19,012.
N/A
N/A
N/A
20,533.
19,012.
20,533.
19,012.
N/A
N/A
N/A
20,533.
19,012.
20,533.
19,012.
N/A
N/A
2003 2004 Magnitude of Idaho Irrigation Load Curtailments
Magnitude of Idaho Irrigation Load Curtailments: 2004
All curtailments occurred between the hours of 2:00p
(14:00) and 8:00p (20:00) hours inclusive
7/20/2004 3 Tuesday 33,283.7/20/2003 1 Sunday N/A
7/21/2004 4 Wednesday 30,998.7/21/2003 2 Monday 20,533.
7/22/2004 5 Thursday 33,283.7/22/2003 3 Tuesday 19,012.
7/23/2004 6 Friday N/A 7/23/2003 4 Wednesday 20,533.
7/24/2004 7 Saturday N/A 7/24/2003 5 Thursday 19,012.
7/25/2004 1 Sunday N/A 7/25/2003 6 Friday N/A
7/26/2004 2 Monday 30,998.7/26/2003 7 Saturday N/A
I "
7/27/2004 3 Tuesday 33,283.7/27/2003 1 Sunday N/A
7/28/2004 4 Wednesday 30,998.7/28/2003 2 Monday 20,533.
7/29/2004 '5 Thursday 33,283.7/29/2003 3 Tuesday 19,012.
7/30/2004 6 Friday N/A 7/30/2003 4 Wednesday 20,533.
7/31/2004 7 Saturday N/A 7/31/2003 5 Thursday 19,012.
8/112004 1 Sunday N/A 8/1/2003 6 Friday N/A
8/2/2004 2 Monday 28,262.8/2/2003 7 Saturday N/A
8/3/2004 3 Tuesday 29,899.8/3/2003 1 Sunday N/A
8/4/2004 4 Wednesday 28,262.8/4/2003 2 Monday 20,533.
8/5/2004 5 Thursday 29,899.8/5/2003 3 Tuesday 19,012.
8/6/2004 6 Friday N/A 8/6/2003 4 Wednesday 20,533.
8/7/2004 7 Saturday N/A 8n /2003 5 Thursday 19,012.
8/8/2004 1 Sunday N/A 8/8/2003 6 Friday N/A
8/9/2004 2 Monday 28,262.4 8/9/2003 7 Saturday N/A
8/10/2004 3 Tuesday 29,899.8/10/2003 1 Sunday N/A
8/11/2004 4 Wednesday 28,262.4 8/11/2003 2 Monday 20,533.
8/12/2004 5 Thursday 29,899.8/12/2003 3 Tuesday 19.012.
8/13/2004 6 FrIday N/A 8/13/2003 4 Wednesday 20,533.7 '
8/14/2004 7 Saturday N/A 8/14/2003 5 Thursday 19,012.
8/15/2004 1 Sunday N/A 8/15/2003 6 Friday N/A
8/16/2004 2 Monday 28,262.4 8/16/2003 7 Saturday N/A
8/17/2004 3 Tuesday 29,899.8/17/2003 1 Sunday N/A
8/18/2004 4 Wednesday 28,262.4 8/18/2003 2 Monday 20,533.
8/19/2004 5 Thursday 29,899.8/19/2003 3 Tuesday 19,012.
8/20/2004 6 Friday N/A 8/20/2003 4 Wednesday 20,533.
8/21/2004 7 Saturday N/A 8/21/2003 5 Thursday 19,012.
8/22/2004 1 Sunday N/A 8/22/2003 6 Friday N/A
8/23/2004 2 Monday 28,262.8/23/2003 7 Saturday N/A
8/24/2004 3 Tuesday 29,899.8/24/2003 1 Sunday N/A
8/25/2004 4 Wednesday 28,262.4 8/25/2003 2 Monday 20,533.
8/26/2004 5 Thursday 29,899.8/26/2003 3 Tuesday 19,012.
8/27/2004 6 Friday N/A 8/27/2003 4 Wednesday 20,533.
8/28/2004 7 Saturday N/A 8/28/2003 5 Thursday 19,012.
8/29/2004 1 Sunday N/A 8/29/2003 6 Friday N/A
8/30/2004 2 Monday 28,262.4 8/30/2003 7 Saturday N/A
8/31/2004 3 Tuesday 29,899.8/31/2003 1 Sunday N/A
9/1/2004 4 Wednesday 23,683.9/1/2003 2 Monday 20,533.
9/2/2004 5 Thursday 26,340.9/2/2003 3 Tuesday 19,012.
9/3/2004 6 Friday N/A 9/3/2003 4 Wednesday 20,533.
9/4/2004 7 Saturday N/A 9/4/2003 5 Thursday 19,012.
9/5/2004 1 Sunday N/A 9/5/2003 6 Friday N/A
9/6/2004 2 Monday 23,683.9/6/2003 7 Saturday N/A
9/7/2004 3 Tuesday 26,340.9/7/2003 1 Sunday N/A
9/8/2004 4 Wednesday 23,683.9/8/2003 2 Monday 20,533.
9/9/2004 5 Thursday 26,340.9/9/2003 3 Tuesday 19.012.
9/10/2004 6 Friday N/A 9/10/2003 4 Wednesday 20,533.
2003 2004 Magnitude of Idaho Irrigation Load Curtailments
Page 2
Magnitude of Idaho Irrigation Load Curtailments: 2004
All curtailments occurred between the hours of 2:00p
(14:00) and 8:00p (20:00) hours inclusive
9/11/2004 7 Saturday N/A 9/11/2003 5 Thursday 19,012.
9/12/2004 1 Sunday N/A 9/12/2003 6 Friday N/A
9/13/2004 2 Monday 23,683.9/13/2003 7 Saturday N/A
9/14/2004 3 Tuesday 26,340.9/14/2003 1 Sunday N/A
9/15/2004 4 Wednesday 23,683.9/15/2003 2 Monday 20,533.
2003 2004 Magnitude of Idaho Irrigation Load Curtailments
Page 3
I '
IDAHO
P AC-O5-
GENERAL RATE CASE
ACIFICORP
ATTACMENT lIP A 16-
Monsanto Interruption and Curtailment Detail
Beg & End Time PPT Duration
Allowed
Date Hrs YTD HRS Re lacement MW Re lacement $Number
Curtailment 1/5104 1000 - 2300 1 hr ~ 67 719.Max of 500 hours in Year
Curtailment 1/13/04 1700 - 1900 0 $
Curtailment 1/19/04 1730 - 1930 0 $
Curtailment 2116104 1730 -1930 0 $
Curtailment 5/4/04 1230 - 2130 0 $
Curtailment 5/5/04 1330 - 2130 0 $
Curtailment 7/12/04 1330 - 2030 0 $
Curtailment 7/13/04 1330 - 2030 0 $
Curtailment 7/14104 1230 - 1930 0 $
Curtailment 7/15/04 1230 - 1430 0 $
Curtailment 7/16/04 1330 - 1630 0 $
Curtailment 7/18/04 1405 -1705 0 $
Curtailment 8/20/04 1330 -1730 5 hrs ~ 67 21,386.40
Curtailment 8/25104 1130 -1930 7 hrs ~ 67 24,061.
Curtailment 8/26/04 1630 - 1730 2 hrs ~ 67 635.
Curtailment 8/27/04 1430 - 1730 4 hrs ~ 67 12,622.
Curtailment 8131/04 1230 - 2130 107 8 hrs ~ 67 24,511.
Curtailment 9/1/04 130- 730 114 7 hrs ~ 67 20,638.
Curtailment 9/2/04 130 - 730 121 7 hrs ~ 67 20,638.
Curtailment 913104 130 - 630 127 4hrs ~ 67 13,783.
Curtailment 919/04 330 - 530 130 3 hrs ~ 67 933.
Curtailment 9/10/04 1230 - 630 137 7 hrs ~ 67 21,694.
Curtailment 9/29/04 830 - 130 143 4hrs ~ 67 12,226.
Curtailment 9/30/04 930 -130 148 0 $
Curtailment 10/1/04 930 - 430 156 8 hrs ~ 67 23,803.
Curtailment 10/4/04 1330- 2130 165 9 hrs ~ 67 25,612.
Curtailment 10/5/04 1330 - 2130 174 9 hrs ~ 67 26,586.
Curtailment 10/6/04 1330 - 2130 183 9 hrs ~ 67 28,261.
Curtailment 10nJ04 1330 - 2130 192 7 hrs ~ 67 21,860,
Curtailment 0/8/04 1330- 2130 201 8 hrs ~ 67; 1 hr ~ 18 25,821.
Curtailment 1019/04 1330 - 2130 210 9 hrs ~ 67 25,961.
Curtailment 10/10/04 1330 - 2130 219 9 hrs ~ 67 26,821.
Curtailment 10/12/04 1830- 2230 224 5 hrs ~ 67 15,125.
Curtailment 10/13/04 1830- 2130 228 3 hrs ~ 67 392.
Curtailment 10/14/04 1830 - 2130 232 3 hrs ~ 67; 1 hr ~ 18 10,606.
Curtailment 10/18/04 1230-1930 240 7 hrs ~ 67; 1 hr ~ 18 21,846.
Curtailment 10/19/04 1130-1830'248 7 hrs ~ 67; 1 hr ~ 22 21,898.
Curtailment 10/20/04 1130-1830 256 7 hrs ~ 67; 1 hr ~ 22 21,898.
Curtailment 10/21/04 1030-1830 265 9 hrs ~ 67 26,893.
Curtailment 10/22/04 1230-1730 271 5 hrs ~ 67; 1 hr ~ 22 20,863.
Curtailment 10/25/04 830-1530 279 6 hrs ~ 67 24,057.
Curtailment 10/26/04 830-1030,1630-1930 286 6hrs~67 27,139.
Curtailment 10/27/04 930 -1330,1930 - 2130 294 3 hrs ~ 67; 2 hr ~ 21 12,068.
Curtailment 10/28/04 830-1130,1930- 2130 301 0 $
Curtailment 10/29/04 830 - 1130, 1830 - 2030 308 0 $
Curtailment 11/1104 830 - 1130. 1730 - 2030 316 0 $
Curtailment 11/2/04 830-1130,1630-1930 324 0 $
Curtailment 11/3/04 830 -1130 328 0 $
Curtailment 11/4/04 830 - 930,1830 - 1930 332 0 $
Curtailment 11/5/04 530 - 830, 1730 - 2030 340 0 $
Curtailment 11nJ04 1630 - 2030 345 0 $
Curtailment 11/8/04 530 - 830 349 0 $
Curtailment 11/16/04 1630 - 2030 354 2 hrs ~ 67 599.
Curtailment 11/17104 530-1030,1630-1730 362 8hrs ~ 67 27,488.
Curtailment 11/18/04 1630 - 1930 366 4 hrs ~ 67 13,582.
Curtailment 11/22/04 1230 - 1730 372 6 hrs ~ 67 17,884.
Curtailment 11/23/04 1530-1830 376 3 hrs ~ 67, 1 hr ~ 18 11,254.41
Curtailment 11/30/04 530 - 2230 394 16 hrs ~ 67 67,996.
Curtailment 12/1/04 930 - 2230 408 0 $
Curtailment 12/2/04 830 - 2230 423 0 $
Curtailment 12/3/04 830 - 2230 438 0 $
Curtailment 12/4/04 730 - 2230 454 0 $
Curtailment 12/6/04 530 - 1030, 1730 - 2030 464 2 hrs ~ 67 435.
Curtailment 1217/04 1730 - 2030 468 4 hrs ~ 67 16,827,
Curtailment 12/8/04 1730 - 2030 472 0 $
Curtailment 12/9/04 1630 - 1930 476 4 hrs ~ 67 15,667.
Curtailment 12/10/04 1630 - 1930 480 3 hrs ~ 67 12,156.
Curtailment 12/11/04 1730 - 2130 485 4 hrs ~ 67 16.208.
Curtailment 12/12/04 1630 - 1930 489 4 hrs ~ 67 14,351,
Curtailment 12/16/04 1430 -1830 494 4 hrs ~ 67 13,992.
Curtailment 12/17/04 630 - 830, 1530 -1730 500 4 hrs ~ 67 12,574.
Duration YTD Allowed Number of
Type Date ' Beg & End Time PPT Hrs Interru tions Interru tions
Interruption 1/6/04 0914-0954
Max of 3 in any 4 hour period
Interruption 1/16/04 0637.705
Max of 25 for each Billing Period
Interruption 1/16/04 2125-2145
Max of 288 interruptions in Year
interruption 1/20/04 1816-1908
Max 1 hour per interruption
Interruption 1/28/04 1423-1500
Interruption 1/30/04 0100-0118
Interruption 1/30/04 1601-1700
Interruption 2/6/04 224 - 255
Interruption 2/12/04 1338 - 1400
interruption 2/13/04 1300 - 1356
Interruption 2/16/04 0011 - 0102
Interruption 2(16104 1023-1110
Interruption 2/18/04 801 .850
Interruption 2/25/04 1314 - 1405
Interruption 2/29/04 1953 - 2050
Interruption 3/13/04 1722 - 1800
Interruption 3/15/04 0943 - 1015
Interruption 3/15/04 1026 -1057
interruption 3/22/04 1349 - 1416
Interruption 3/26/04 0200 - 0245
Interruption 3/26/04 0440 - 0540
Interruption 3/26/04 1107 -1157
Interruption 413/04 1700 - 1753
Interruption 4/6/04 0405 - 0453
Interruption 4/11/04 0200 - 0251
Interruption 4/14/04 1826-1844
Interruption 4/14/04 1140-1203
Interruption 4/16/04 0031 - 0105
Interruption 4/23/04 2233 - 2257
Interruption 4/24/04 1910 - 1956
Interruption 4/27/04 , 1334-1351
Interruption 5/8/04 1935 - 2005
Interruption 5/9/04 538 - 555
Interruption 5/11/04 943 - 957
Interruption 6/29/04 1230 - 1250
Interruption 7/2/04 0042 - 0100
Interruption 7/6/04 2030 - 2105
Interruption 7/11/04 1631 -1648
Interruption 7/14/04 0201 - 0252
Interruption 8/10/04 1736 - 1828
Interruption 8/24/04 0948 - 1003
Interruption 9/11/04 2128.2218
Interruption 9/21/04 557 - 608
Interruption 10/1/04 1904 - 2000
Interruption 10/12/04 1528 -1558
Interruption 10/17/04 157 - 243
Interruption 10/22/04 102-152
Interruption 10/28/04 920 - 1020
Interruption 11/1/04 1226 - 1252
Interruption 11/5/04 1150-1157
Interruption 11/19/04 0849 - 0903
Interruption 12/18/04 1053-1130
Interruption 12/20/04 1045-1130
Interruption 12/23/04 0808 - 0850
Interruption 12/27/04 0922 - 0934
P AC-05-1/PaciflCorp
March 18,2005
lIP A Data Request 1 7
IIPA Data Request 17
Please provide in electronic format a listing of the date, time, and estimated
magnitude of ~ll actual hourly curtailments/interruptions that occurred during the
test year in each of the other jurisdictions. If outright curtailments/interruptions
are treated differently than "buy-throughs , please state each separately.
Response to liP A Data Request 17
The requested information is provided as Attachments lIP A 17-1 and 17-2 on the
enclosed CD.
(Stan Watters will sponsor this response at hearing.
I "
IDAHO
PAC-O5-
GENERAL RATE CASE
ACIFICORP
ATTACHMENTS lIP A 17-(1-
ON THE ENCLOSED CD
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 18
lIP A Data Request 18
Please reconcile the total system load of 52 721 424 MWH listed on Ex. 9, Tab 5
(Net Power Costs), page 5, with the difference between the actual system energy
of 53,184 855' MWH on Ex. 9, Tab 10, page 3, less the adjustment of 432 150
MWH found on Ex. 9, Tab 10, page 4 (53,184 855 - 432 150 = 52 752,705).
Response to liP A Data Request
The 53,184 855 MWh on Ex. 9, Tab 10 represent actual Company load before any
normalizing adjustments. Please refer to Attachment lIP A 18 on the enclosed
CD, for the normalizing adjustments made in the jurisdictional allocation model.
Tlie-52~721 ~424-MWh-on--E-x~-9-; ~ab-5 represent the loads that are reported by the
Company s power cost model.
The Company begins by taking the actual loads and applying a weather
normalizing adjustment, (See the Company s response to IIPA Data Request 20
for an explanation on this process.) In this case, the normalizing adjustment made
to the hourly data totaled -325,416MWh.
Next, the pro forma period for the Idaho GRC is one year out from the historical
period of the actual loads. In order to align the loads with the test period, the
Company places the weather normalized lQads one year into the future. In order
to keep the shape of the load accurate, the days of the week must coincide. For
example, Tuesday 1/13/2004 coincides with Tuesday 1/11/2005. This process
shifts the data which will change the total load reported by the Company
s power
cost model.
Also, the historical period of the actual loads was a Leap Year. Bringing the
loads forward one year removes the extra day of load reported in the 53,
184 855
MWh represented on Ex. 9, Tab 10.
(Mark T. Widmer will sponsor this response at hearing.
I '
IDAHO
P A C- O5-
GENERAL RATE CASE
ACIFICORP
ATTACHMENT lIP A 18
ON THE ENCLOSED CD
P AC-05-/PacifiCorp
March 18, 2005
lIP A Data Request 19
liP A Data Request 19
I How was actual test year hourly data incorporated into the Company s net power
cost model and the values used in this case?
Response to liP A Data Request
Assuming this data request refers to hourly "Load" Data, please see the
Company s response to lIP A Data Request 18.
(Mark T. Widmer will sponsor this response at hearing.
~ -- - ---
- u--
-..--- ~
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 20
liP A Data Request 20
If the Company s net power cost model was run using weather normalized loads,
how were those weather-normalizing adjustments spread out for each hour used in
the net power cost model?
Response to liP A Data Request 20
I '
The weather normalization of system loads is done directly at the hourly level
using historical hourly load values. A regression model using about 250 variables
is used to model the hourly loads. Several of these variables measure the weather
effect on the state s system loads. To weather normalize the hourly loads the
difference between normal hourly weather and actual hourly weather is multiplied
by the weather measure coefficient and this value is added to the actual load.
(Stan K. Watters will sponsor this response at hearing.
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 21
lIP A Data Request 21
'Please provide in a summary fashion similar to that provided in Ex. 9, Tab 5, the
results of the Company s net power cost model assuming that the Company was
supplying all ~f the curtailments/interruptions/buy-throughs from all jurisdictions
less the Monsanto load.
Response to liP A Data Request 21
This response is still being prepared and will be provided as soon as it is
completed. It is expected to be completed within approximately one week.
(Mark T. Widmer will sponsor this response at hearing.
P AC-O5-1/PacifiCorp
March 18, 2005
IIPA Data Request 22
liP A Data Request 22
Please provide in a summary fashion similar to that provided in Ex. 9, Tab 5, the
results of the Company s net power cost model assuming that the Company was
supplying all of the curtailments/interruptions/buy-throughs from all juri~dictions
as well as the Monsanto load.
Response to IIPA Data Request 22
\ "
This response is still being prepared and will be provided as soon as it is
completed. It is expected to be completed within approximately one week.
,. (N~(frR-T;--idmer-will-sponsof-this-response.at hearing.
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 23
liP A Data Request 23
Please provide in a summary fashion similar to that provided in Ex. 9, Tab 5, the
results of the Company s net power cost model assuming that the Company was
supplying all of the curtailments/interruptio~s/buy-throughs from all jurisdictions
as well as the Monsanto load, excluding the Irrigation loads that are
curtai I ed/interrupted.
Response to liP A Data Request 23
This response is still being prepared and will be provided as soon as it is
completed. It is expected to be completed within approximately one week.
---- --~ .... - ..... ---
(Mark T. Widmer will sponsor this response at hearing.
P AC-05-lIPacifiCorp
March 18, 2005
, lIP A Data Request 24
liP A Data Request 24
Please provide a copy or copies of the Company s Jurisdictional Allocation
Model (in a manner similar to that of Exhibit 9 Tabs 1, 2 and 10) stating the Idaho
Jurisdiction without Monsanto and the Monsanto load as two separate
jurisdictions.
Response to liP A Data Request 24
I '
Please refer to Attachment lIP A 24-1 on the enclosed CD for the copy of the
Jurisdictional Allocation Model. Please note the model was calculated using the
Revised Protocol Methodology. There are separate jurisdictions for Idaho and
. ---'
onsan1o-:-The-jurisdicti0fl-se-leGtiencan-be-changed by selecting the desired
jurisdiction in the jurisdiction drop-down menu in the variables tab.
For Monsanto jurisdiction tabs 1 , 2 , and 10, please refer to Attachment lIP A 24-
on the enclosed CD. For Idaho Jurisdiction, please refer to Attachment lIP A 24-
on the enclosed CD. Please note that Tab 10 is the same for both jurisdictions
because it is based on the same data. It is included in both attachments.
(J. Ted Weston will sponsor this response at hearing.
IDAHO
P A C- E-O5-
GENERAL RATE CASE
ACIFICORP
ATTACHMENT lIP A 24 (1-
ON THE ENCLOSED CD
Exhibit 9, Tab 10, page 3 lists a total Idaho energy requirement of 3,688,337
MWH and Exhibit 24, Tab 5, page 5 lists a total Idaho energy requirement for
class cost of service purposes as 2,147,807 MWH. Please reconcile the difference
between these two figures.
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 25
liP A Data Request 25
Response to liP A Data Request 25
I '
Exhibit 9, Tab 10 page 3 line 25 lists total Idaho energy requirement of 3,688,337
MWH and does not include 37,684 of Monsanto curtailment. Exhibit 9, Tab 10,
Rage I li 25 lists a total energy requirement 00,726 021 which includes the
37,684 Monsanto- curtiiile-d--MWlt'S~- Exhibit-9;Hq'-ab 1 0, page 7 line 46 lists the
total Idaho energy requirement after temperature adjustments. The difference
between Exhibit 9, Tab 10, page 7 line 46 and Exhibit 24, Tab 5 page 5 line 11 is
explained in lIP A Data Response 3 B.
(David L. Taylor will sponsor this response at hearing.
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 26
lIP A Data Request 26
Exhibit 9, Tab 10, page 3 lists a total Idaho 12-CP demand requirement of
394 640 KW and Exhibit 24, Tab 5, page 6 lists a total 12-CP demand
requirement for class cost of service purposes as 5,612,924 K W. Please reconcile
the difference between these two figures.
Response to liP A Data Request 26
The 5,394 640 kW shown on Exhibit 9 , Tab 10 page 3 does not include the
Monsanto curtailment. Exhibit 9, Tab 10 page 5 line 23 lists a total Idaho 12-
demand requirement of 5,566,100 k W, and includes temperature adjustments and
the Monsanto curtailment. A comparison of Ex. 9, Tab 10, page 5 line 23, total
kW's of 5,566 100, with the total kW's from Ex. 24, Tab 5 page 6 line 35
612,924, shows a difference of less than 10/0.
(David L. Taylor will sponsor this response at hearing.
P AC-05-1/PacifiCorp
March 18, 2005
IIPA Data Request 27
liP A Data Request 27
Wi~h respect to Exhibit 24, Tab 5, page 6, please answer the following:
A. Are all of these values actual? If not, please provide and explanation of how
they were normalized and the workpapers that support the normalization.
B. Please explain the difference between the figures on lines 20 and 21.
\ '
C. What level of curtailment of Schedule 10 load is reflected on line 26? Is this
level of curtailment the same as occurred in 2004 or is expected to be incurred
in 2005?
.. -----
Response to liP A Data Request 27
A. These values are weather normalized. For a summary of the weatrher
adjustments, please refer to lIP A Data Response 2 E.
B. Line 20 is Monsanto s metered monthly load coincident with monthly system
, peaks and line 21 represents Monsanto s curtailment during those same hours.
C. Please refer to lIP A Data Response 2 D Table 1-4. This level of curtailment is
the same as expected to be incurred in 2005.
(David L. Taylor will sponsor this response at hearing.
P AC-O5-lIPacifiCorp
March 18, 2005
BPA Data Request 28
liP A Data Request 28
Please reconcile the total Idaho Operating Revenue figure of $133, 904 000 on
Exhibit 9, Tab Bl , page 7 with the revenue figures on Exhibit 9, Tab 2, page 2.
Response to liP A Data Request 28
The requested information is provided as Attachment BPA 28.xls. The single
reason for the variance is that the incorrect Idaho System Generation "SG"
allocation code percentage was used in preparing Exhibit 9, Tab B
I '
The correct "SG" percentage of 6.44620/0 was used in preparing Exhibit 9, Tab 2
Page 2.2 (Revised Protocol Methodology) and Exhibit 9, Tab 9, Page 2.2 (Rolled-
In Methodology). The correct "SG" percentage of 6.44620/0 is presented in
Exhibit 9, Tab 1 0, Page 1.
(J. Ted Weston will sponsor this response at hearing.
IDAHO
PAC-O5-
GENERAL RATE CASE
ACIFICORP
ATTACHMENT lIP A 28
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p AC-05-1/Paci~Corp
March 18,2005
lIP A Data Request 29
liP A Data Request 29
I Please reconcile the total Idaho Operating Revenue figure of $120 460,798 on
Exhibit 24, Tab 5, page 26 with the revenue figures on Exhibit 9, Tab 2, page 2.
Response to liP A Data Request 29
The revenue figure of$120,460,798 on Exhibit 24, Tab 5, page 26 does not
include revenues from Monsanto. The cost of service study treats Monsanto as a
state specific revenue credit which is indicated by the $42,906 416 shown on
Exhibit 24, Tab 4.1 line 150. The $120 460 798 plus the $42 906 416 equals the
revenues of$163 367,214 shown on Exhibit 9, Tab 2, page 2.
(David L. Taylor will sponsor this response at hearing.
P AC- E-05-/PacifiCorp
March 18, 2005
IIPA Data Request 30
liP A Data Request 30
Please provide the test year billing determinants, rates and calculations used to
support the Monsanto revenue (actual and normalized) that was credited to the
Idaho Jurisdiction.
Response to liP A Data Request 30
I "Please refer to page 9 of Exhibit 29 for the test year billing determinants, rates and
calculations used to produce the Monsanto actual and normalized revenue used in
this case that was credited to the Idaho jurisdiction.
(David L. Taylor will sponsor this response at hearing.
P AC-05-1/PacipCorp
March 18,2005
lIP A Data Request
liP A Data Request 31
I Commission Order No. 29157 set an interruptible credit of 7.48 millslkWh for
Monsanto. How was this credit address in this case? Further information is
clearly needed for the Commission, the Commission Staff, and the Irrigators
thoughtfully make such a determination.
Response to liP A Data Request 31
As shown in William R. Griffith Exhibit 25 and Exhibit 29, page 9, Monsanto
present revenues used in the this case are $42.9 million which reflects all of its
usage priced at the firm service rate. The $4.51 per kW discount for ancillary
services is included as a resource purchase in Net Power Costs and allocated
among all states.
Consistent with reflecting Monsanto s revenues at the firm service equivalent
rate, Monsanto s loads are included at its full requirements level and do not reflect
any curtailments due to System Integrity, Operating Reserves, and Economic.
(David L. Taylor will sponsor this response at hearing.
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 32
liP A Data Request 32
On page 3 of Mr. Stewart's testimony it is stated that "base rates are actually
about 7 percent lower today than they were in 1986." Please supply whatever
data or source there is that supports this calculation.
Response to liP A Data Request 32
I "Please see Attachment lIP A 32.
(David L. Taylor will sponsor this response at hearing.
__' ,
on
. -,- - - -
"" .. -- -.-.."
IDAHO
P A C- O5-
GENERAL RATE CASE
ACIFICORP
ATTACHMENT lIP A
Utah Power & Light
State of Idaho
Summary of price Changes
Attachment Response IIPA 1.
Base
Price
Tariff Effective Change
Date Index
, "
May-100
Apr -(1.56)98.44
Jan-(0.80)97.
F eb-(0.80)96.
Mar-(1.70)95.
T -28 (I)May-(2.10)93.
28 (F)Mar-00 93.
Oct-93.
Oct-93.
Oct-93.
May-93.
Oct-93.
Aug-93.
Jul-93.
Jan-93.
Jun-93.
Feb-93.
Jun-93.
Feb-93.
Jun-93.
Jun-93.
Jan-93.
Net % Loss in Base Rates 78%
P AC-05-1IPaci~Corp
March 18 2005
lIP A Data Request 33
IIPA Data Request 33
For each rate schedule and special contract customer listed in Exhibit 25, for each
year since the last rate case, please list the amount of energy consumed and the
revenue collected.
Response to liP A Data Request 33
Please see Attachment lIP A 33. The attachment contains the annual revenue
reports for the Idaho jurisdiction for calendar years 1989 through 2003. Each
report has by rate schedule the amount of energy consumed and the revenue
collected. 1989 is the earliest year that the Company has this detail.
(David L. Taylor will sponsor this response at hearing.
I "
IDAHO
P A C- O5-
GENERAL RATE CASE
ACIFICORP
ATTACHMENT IIPA
ON THE ENCLOSED CD
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 34
lIP A Data Request 34
I With respect to the Company s 2003 FERC Form 1 page 304., please explain
how lines 2 and 6-9 are related.
Response to liP A Data Request 34
FERC Form 1 page 304.24 lines 6-9 represent billings to customers (lines 6 and
8) and the BP A credits given the customers on their bills (lines 7 and 9). Line 2
represents an accounting entry recording the timing difference between the credits
received from BP A and the inclusion of those credits on the customers' bills.
(Stan K. Watters will sponsor this response at hearing.
P AC-05-lIPacifiCorp
March 18, 2005
lIP A Data Request 35
liP A Data Request 35
, With respect to the Company s 2003 FERC Form 1 page 304., line 22 through
page 304~13 , line 13 please explain how these lines are related and what each line
represents.
Response to liP A Data Request 35
\ "
The following lines are related in that they are all schedules associated. with
Irrigation in Idaho. See Attach lIP A 35.xls for an explanation of what each line
represents.
(Stan K. Watters will sponsor this response at hearing.
IDAHO
PAC-O5-
GENERAL RATE CASE
ACIFICORP
TT ACHMENT lIP A 35
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P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 36
liP A Data Request 36
Regarding the irrigation loads listed on the 2003 FERC Form 1 page 304.12, line
22 through page 304.12, line 13, which of these lines pertain to Schedule 10 and
which lines pertain to some other rate schedule?
Response to liP A Data Request 36
I '
This response assumes the question refers to page 304., line 22 through page
304.13, line 13. If so, page 304., lines 25-28 and 36-, and page 304.13, lines
13 all pertain to schedule 10. The remaining lines pertain to some other rate
schedule. See details below.
u._-
- ,-- - -- -
Line Rate Schedule Rate Description
No.
Other UNBILLED REY - IRRlGA TION
Other IRRlGA TION BPA BAL ACCT
Other 07MISCOOOO-FEE OFFERING N
07 APSYCNLL-LRG LOAD CANAL
07 APSYCNLL-LRG LOAD CANAL
07 APSYCNLS-SML LOAD CANAL
07 APSYCNLS-SML LOAD CANAL'
Other 07BPADEBIT-BPA ADJUST FEE
Other 07LNXOOIII-80%MIN+ADY+BTW
Other 07LNXOOI12-80%ANN+ADY+BTW
Other 07LNXOOI07-SUBD ADY & AIC
Other 07LNXOO040- ADY + REFCH G+80%
Other 07LNXOOOI5-ANNUAL 80%GUAR
Other 07ZZMERGCR-MERGER CREDITS
07 APSCL 1 OX - was 07 APSe OLX 21697
07 APses 1 OX - was 07 APSe 1 OSX 21698
07 APSBS 1 OX - IRG & PUMP - Sm load
07 APSBL lOX - IRG & PUMP - Large Load
07 APSAL lOX - IRG & PUMP - Large load
07 APSAS 1 OX - IRG & PUMP - Small load
07 APSAO 1 OL - IRG & Pump Large Load
07 APSAO 1 OL - IRG & Pump BP A Large
Load
07 APSAO 1 OS - IRG & Pump Small Load
07APSAOI0S - IRG & Pump BPA Small
Load
07 APSBO 1 OL - IRG & Pump Large Load
07 APSBO 1 OL - IRG & Pump BP A Large
. -
Load
07 APSBO 1 OS - IRG & Pump Large Load
07 APSBO 1 OS - IRG & Pump BP A Large
Load
07APSeOl0S - IRG PUMP SRY Small Load
07APSCOI0S - IRG PUMP Srv BPA Small
Load
07 APSeO 1 OL - IRG PUMP Srv Large Load
P AC-O5-1/PaciftCorp
March 18, 2005
lIP A Data Request 36
07 APSCO 1 OL - IRG PUMP Srv BP A Large
Load
(Stan K. Wa~ters will sponsor this response at hearing.
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 37
liP A Data Request 37
Statistics for Monsanto appear to be contained on the 2003 FERC Form 1 at page
304.7, line 25. Please answer the following:
a. Do the revenues and MWh listed include both firm and interruptible'
deliveries? If affirmative, please list the revenues for the firm and
interruptible deliveries separately.
I "
b. Do the revenues and MWh listed include buy-through purchases? If
affirmative, please list the MWh and the revenues for the buy-through
separately.
c. Do the revenues include any amount due from a previous timeframe?
affirmative, please specify the amount and the reason for the payment.
d. Do the revenues include the interruptibility credit approved by the
Commission in Order 29157? If affirmative, what was the MWh and revenue
associated with the interruptibility credit? If negative, where in the FERC
, Form 1 is this interruptibility credit addressed?
Response to liP A Data Request 37
a. Yes Both Firm and interruptible deliveries are included.
Firm 78 840 MWh $ 2 197 929
Interruptible 1 287 460 MWh $38,018 933
TOTAL 1 366,300 MWh $40,216 862
b. No, there were no buy-through purchases in this period.
c. No.
d. The revenues are prior to any reduction for the interruptibility credit. The
interruptibility credit can be found on page 327., line 7.
(J. Ted Weston will sponsor this response at hearing.
P AC-05-1/PaciftCorp
March 18, 2005
lIP A Data Request 38
liP A Data Request 38
'Please provide a cop y of the Company s recent study entitled "PacifiCorp Idaho
2001 Analysis of System Losses
Response to liP A Data Request 38
See Attachment lIP A 38 on the enclosed CD.
(David L. Taylor will sponsor this response at hearing.
I '
IDAHO
PAC-O5-
GENERAL RATE CASE
ACIFICORP
TT A CHMENT lIP A 38
ON THE ENCLOSED CD
P AC-05-1/PacifiCorp
March 18, 2005
lIP A Data Request 39
liP A Data Request 39
Please provide in electronic format a copy of all interjurisdictional and class cost
of service studies conducted by the Company in this case.
Response to liP A Data Request 39
Electronic copies of the interjurisdictional and class cost of service studies were
provided as part of the Company s original filing. An additional cost of service
study was conducted by the Company in response to IPUC Staff Request 35 and
is provided as Attachment lIP A 39-1 on the enclosed CD. Additional
interjurisdictional studies were performed by the company in response to IPUC
Staff request 38 and lIP A request 24. The Company filed a revised response to
IPUC Staff request 38; this is provided as Attachment lIP A 39-2 on the enclosed
CD.
(David L. Taylor will sponsor this response at hearing.
\ '
IDAHO
P AC-O5-
GENERAL RATE CASE
ACIFICORP
ATTACHMENT lIP A 39-(1-
ON THE ENCLOSED CD
P AC- E-05-/PacifiCorp
March 18, 2005
lIP A Data Request 40
liP A Data Request 40
Please provide an electronic copy as well as a hard copy of any cost of service
studies (similar to Exhibit 24 in this case) that were fun by the Company in Case
PCA-01-' that support the results listed i~ Taylor s Exhibit 1 page one of that
case.
Response to liP A Data Request 40
The requested information is provided as Attachment lIP A 40 on the enclosed
CD.
(David-Taylor willsponsor--this-response--at-hearing.
) -. -
I '
IDAHO
P A C- O5-
GENERAL RATE CASE
ACIFICORP
TT A CHMENT lIP A 40
ON THE ENCLOSED CD