20090612Response to Joint Motion.pdf

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iDAHO P' .
UTtUT\ES CO~.'\N
esIDA~POR(I
An IDACORP Company
LISA NORDSTROM
Senior Counsel
June 12, 2009
VIA HAND DELIVERY
Jean D. Jewell, Secretary
Idaho Public Utilities Commission
472 West Washington Street
P.O. Box 83720
Boise, Idaho 83720-0074
Re: Case No. IPC-E-09-03
LANGLEY GULCH POWER PLANT
Dear Ms. Jewell:
Enclosed for filing are an original and seven (7) copies of Idaho Power Company's
Response to Intervenors' Joint Motion to Stay in the above matter.
Very truly yours,
1a't~~:i~
LDN:csb
Enclosures
P.O. Box 70 (83707)
1221 W. Idaho St.
Boise. ID 83702
BARTON L. KLINE (lSB No. 1526)
LISA D. NORDSTROM (lSB No. 5733)
Idaho Power Company
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: 208-388-6936
bklineCâidahopower.com
InordstromCâidahopower.com
RECEIVED
iU9 JUN l 2 P" ,: 27
IOAHO p! i I ieUTILJTfES co ISSION
Attorneys for Idaho Power Company
Street Address for Express Mail:
1221 West Idaho Street
Boise, Idaho 83702
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF IDAHO POWER
COMPANY'S APPLICATION FOR A
CERTIFICATE OF PUBLIC
CONVENIENCE AND NECESSITY FOR
THE LANGLEY GULCH POWER PLANT.
)
) CASE NO. IPC-E-09-03
)
) IDAHO POWER COMPANY'S
) RESPONSE TO INTERVENORS'
) JOINT MOTION TO STAY
i.
PROCEDURAL BACKGROUND
On May 29, 2009, the Industrial Customers of Idaho Power ("ICIP"), the Idaho
Irrigation Pumpers Association ("Pumpers"), the Snake River Allance ("Allance"), the
Idaho Conservation League ("ICL"), and the Northwest & Intermountain Power
Producers Coalition ("NIPPC") filed a Motion to Stay further proceedings in this case for
1 0 months. The above-referenced parties are all intervenors in this case and wil
hereinafter be referred to jointly as "Intervenors."
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 1
The Commission issued a Scheduling Order in this case on April 20, 2009.
Intervenors all agreed to the schedule and the Commission adopted the agreed-upon
schedule. All of Intervenors' discovery requests have been made. Idaho Power has
received more than 225 discovery requests, most of which contain multiple parts. The
Company has responded to all but about 10 of the requests. The remaining 10
requests were received approximately a week ago. Idaho Power is preparing
responses and wil respond to the remaining requests as soon as reasonably possible.
Staff and Intervenors' testimony is due June 19.
II.
INTERVENORS HAVE NOT PRESENTED
ANY EVIDENCE TO SUPPORT THEIR MOTION
Intervenors' Motion is a collection of speculation, conjecture, and unfounded
assumptions. The Motion is a collection of "what ifs." What if the Company has a
better response to its DSM programs than it expects? What if the Company's current
load forecasts are so far off that they really do not need to add a baseload resource in
2012? What if the Company's greenhouse gas mitigation strategy causes the Company
to abandon the Langley Gulch project? But under Idaho law, simply posing questions
and hypotheticals is not a sufficient basis to grant the Intervenors' Motion. Under Idaho
law, the Commission must base its decisions and issue its orders based on substantial,
competent evidence. See Industrial Customers of Idaho Power v. Idaho Public Utilties
Com'n, 917 P.3rd 776, 775, 128 Idaho 609, 618 (1996) and Application of Hayden
Pines Water Company, 111 Idaho 331, 334, 723 P.2d 875 (1986).
Idaho Power has provided testimony and exhibits, Le., evidence, demonstrating
the need for the Langley Gulch project. The Company has also presented evidence
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 2
demonstrating that the Request for Proposals ("RFP") process it used to select the
Langley Gulch project was administered neutrally and the submitted proposals were
evaluated fairly. The Company has presented evidence that Langley Gulch represents
a significant value for the Company's customers. In contrast, Intervenors' Motion does
not provide the Commission with any evidence that supports their speculative
assertions. Intervenors ask the Commission to place the viabilty of the Langley Gulch
project at risk without presenting any evidence upon which the Commission could base
its decision. For this reason alone, the Commission must deny Intervenors' Motion.
If the Commission denies Intervenors' Motion to Stay, the Commission's
established procedure for this case provides a forum where all of the concerns raised by
the Intervenors can be presented to the Commission for consideration. Intervenors wil
have the opportunity in their testimony and exhibits to present evidence that supports
the validity of their concerns. Idaho Power will then have an opportunity, in its rebuttal
testimony, to respond to the concerns raised by Intervenors. The Commission will then
presumably have at least some evidence from the Intervenors supporting their request
that the proceedings be stayed or, alternatively, that the Langley Gulch project not
receive a Certificate of Public Convenience and Necessity ("CPCN").
It is very important that the Commission understand the importance of
maintaining the agreed-upon schedule. A 10-month delay in this proceeding wil, at a
minimum, substantially increase the cost of Langley Gulch. Those costs are addressed
in greater detail in Section VII below. A 10-month delay could, as shown in Section IV
below, jeopardize the Company's abilty to serve all of its loads in 2012 and thereafter.
As a result, Intervenors' Motion is more than a mere procedural request. It has a
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 3
substantive effect and requires consideration based on substantial and competent
evidence in the record. For all of these reasons, the Commission should dismiss
Intervenors' Motion and reaffirm that the schedule established in the Commission's April
20, 2009, Scheduling Order wil be followed.
II.
THE COMMISSION'S SCHEDULING ORDER
ADDRESSES THE ISSUES RAISED BY INTERVENORS' MOTION.
Intervenors characterize the various issues they raise as "significant and
unforeseen events." (Motion for Stay, p. 2). In fact, the issues list contained in the
Commission's April 20, 2009, Scheduling Order covers all but one of the issues raised
by Intervenors. The issues identified for review in the April 20, 2009, Scheduling Order
are as follows:
1. Integrated Resource Plan (IRP)
. need for resource
. load forecast/timing
2. Request for Proposal (RFP)
Sufficiency of RFP
. Resource identification
. Benchmark Resource
Third part consultant
. Selection process
Resource Selection Process
. Fairness
. Criteria - price/non-price attributes
. Transparency
3. Certificate of Public Convenience and Necessity - IDAPA 3 1.0 1.0
1.1 12
4. Ratemaking treatment (cost recovery/ratemaking commitment)
A. Construction Work In Progress (CWIP)
Allowance of Funds Used During Construction (AFUDC)
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 4
B. Idaho Code § 61-541 (71112009) - Binding ratemaking
treatment
C. Financial considerations - risk, etc.
It is clear from the Commission's Scheduling Order that the Commission (and the
parties) expected that the parties would address in their respective cases the issues the
Intervenors raise in their Motion, including the status of the Company's IRP, its load
forecast, its DSM programs, and the effect of the recession on the Company's need for
Langley Gulch. The only issue raised by Intervenors in their Motion that is not included
within the issues list is the Intervenors' speculation that the recent Idaho Power
shareholder advisory vote regarding goals for reducing greenhouse gas emissions
might cause the Company to abandon Langley Gulch. Idaho Power wil address this
"what if' in greater detail later in this Response. Other than that one issue, none of the
issues raised by Intervenors are surprises that were not anticipated as issues to be
considered in this proceeding. Intervenors should move forward and present their case.
Idaho Power wil respond and the Commission will have a full and adequate record
upon which it can make a decision as to whether or not it is in the public interest to
issue a CPCN authorizing Idaho Power to move forward with the Langley Gulch project
on the schedule it has proposed.
iv.
TO PROVIDE ADEQUATE AND RELIABLE POWER TO
ITS CUSTOMERS, IDAHO POWER NEEDS TO PROCEED
WITH THE LANGLEY GULCH PROJECT.
The principal theme in the Intervenors' Motion is that Idaho Powets current load
forecast may not be accurate and, therefore, it is necessary to defer a decision on
Langley Gulch until after the Company presents a new sales and load forecast in
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 5
conjunction with its 2009 IRP filng. The economic recession, new DSM programs, and
the Company's greenhouse gas reductions strategy are the principal examples cited to
support this thesis. Intervenors' assertion - that a new load forecast is necessary to
demonstrate the need for the Langley Gulch project to be available in 2012 - is wrong.
The Company has prepared updated sales and load forecasts and load and resource
balances that reflect the effects of both the current recession and the impact of
anticipated DSM programs, including the irrigation and air conditioning peak reduction
programs cited in Intervenors' Motion. (Motion, pp. 7-8).
It is true that Idaho Power prepares a sales and load forecast each year. It is
also true that the Company wil complete its 2009 sales and load forecast late this
summer for use in the 2009 IRP that wil be filed before the end of the year. However, it
is incorrect to assume that Idaho Power does not continuously monitor its sales and
load and periodically update both its sales and load forecast and its load and resource
balance.
Idaho Power has prepared a number of updated load forecasts since the 2006
IRP was published. The September 2008 forecast was used for the 2009 IRP.
Uncertainty associated with the effect of the current recession on Idaho Powets service
area prompted the Company to update the September 2008 load forecast in December
of 2008 and then again in May 2009. The December 2008 update considered the
residential and commercial class loads. The most recent update, performed in May of
2009, updated the forecast loads for special contract customers as part of preparing the
newest load forecast, which is expected to be completed in late summer 2009. The
May 2009 update also included the impact from all DSM programs, including new DSM
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 6
irrigation, commercial, industrial, and A1C cycling programs. The December 2008 and
May 2009 load forecasts and load/resource balances have been provided to the
Intervenors in discovery in this case.
Utilizing the May 2009 load forecast, along with the forecast peak-hour DSM
contributions and the assumed level of purchases from the Pacific Northwest, Idaho
Power is still projecting peak-hour deficits during July of 2009 through July of 2012 of 40
MW, 21 MW,91 MW, and 183 MW, respectively. From an average energy perspective,
using the May 2009 load forecast along with the forecast DSM contributions to reduce
average energy requirements and the assumed level of purchases from the Pacific
Northwest, Idaho Power is still projecting average energy deficits during July of 2009
through July of 2012 of 397 MW, 418 MW, 465 MW, and 535 MW, respectively.
In spite of the fact that recent economic conditions have been very volatile, Idaho
Powets updated load forecasts have been very accurate. The chart below ilustrates
that accuracy. The chart below compares the December 2008 load forecast to the
weather-adjusted actual ("WA Act") loads for January, February, March, and April of
2009.
Weather Adjusted December 2008 Difference (aMW)
Month Actual (WA Act) Loads Load Forecast (aMW)Forecast minus
(aMW)WAAct
January 2009 1,774 1,859 86
February 2009 1,683 1,714 31
March 2009 1,499 1,519 20
April 2009 1,445 1,504 59
The table shows that the average difference between the weather adjusted
actual loads and the December 2009 load forecast is approximately 50 aMW - with the
December 2009 load forecast slightly exceeding weather-adjusted actual loads. The
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 7
average difference between the weather adjusted actual loads and the forecast from
January 2009 through April of 2009 is approximately 3 percent. Looking at the May
2009 load forecast, the weather-adjusted actual load for May was 13 aMW greater than
the May 2009 forecast.
In May of 2009, the load forecast was updated again, making specific
adjustments to the load forecast for Idaho Powets special contract customers. In this
update, the load forecast was reduced again, with the largest reductions (94 aMW and
97 MW during peak-hours) occurring in late 2009. This reduction at least partially
offsets some of the approximately 50 MW of variance in the December 2009 forecast
discussed above.
Furthermore, in July of 2012, Power Supply plans to receive a 115 MW set-aside
of firm network transmission to import purchases from the Pacific Northwest. However,
to meet peak hour loads, the Company is planning to import 315 aMW of energy from
the Pacific Northwest during the same month. This means the majority of the planned
imports wil be on Secondary Network (non-firm) transmission. Based on the
Company's current projections, Langley Gulch, or another similarly sized resource, is
needed in the 2012 timeframe to reduce the risk of a shortage of imported energy
availability and wholesale market price risk.
The resource need that the Langley Gulch project will meet was identified in the
20041RP. In the 2004 IRP, 500 MW of seasonal ownership coal-fired generation was
identified for 2011. This was updated in the 2006 IRP, which included 250 MW of coal-
fired generation in 2013 and an additional 225 MW of transmission import capacity in
2012. The 2008 IRP Update reflected the Company's decisions to change from a coal-
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 8
fired to a natural gas-fired resource and to accelerate the resource one year (from 2013
to 2012) in order to meet expected load. Thus, the 2008 IRP Update included a 250
MW CCCT resource and the 225 MW of import capacity on the Hemingway-Boardman
transmission line in 2012. The Boardman to Hemingway ("B2H") transmission line has
been delayed, probably until 2015. With the B2H project delayed, development of
additional generation resources that do not utilze transmission capacity over the
Company's constrained western interconnections, such as Langley Gulch, becomes
even more important.
Idaho Power will continue to update its load forecast; however, it is important to
recognize that the load forecast has been updated and that differences between
weather-adjusted actual values and the load forecast over the last few months have
been about 50 MW on average, or about 3 percent. Idaho Powets load and resource
balance projections based on the May 2009 load forecast, indicate demand and energy
deficits significantly in excess of the recent 3 percent forecast differences. These
projected deficits coupled with the facts that (1) water conditions can be worse than
planned for, (2) economic recovery could be faster than anticipated, (3) Idaho Power
stil relies on a significant amount of imports during the summer (a portion of which are
imported on non-firm transmission), (4) Idaho Power continues to receive inquiries from
potential new large loads, and (5) Idaho Power has a legal obligation to serve new and
existing loads, all indicate the need for additional internal generation resources. The
persistence of the projected resource deficits through continued analysis, recent
adjustments for the economic downturn, and increased DSM, underscores the need for
rapid deployment of this needed resource.
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY.. 9
The Commission is also well aware of the fact that the Company produces
monthly operating plans, which consider both the most recent sales and load forecast
and changing conditions on the Company's system as a part of the Company's Energy
Risk Management Policy. In fact, representatives of the ICIP and the Pumpers are
active participants in the Company's Customers Advisory Group ("CAG") that consults
with the Company on its Energy Risk Management Policy. Members of the CAG are
briefed at least twice a year on the Company's current load forecasts and its near-term
plans for meeting those loads.
The Company would have preferred to provide these updated load forecasts with
explanatory testimony, in accordance with the Commission's Scheduling Order in this
case. However, since the Intervenors have raised this issue, it is necessary to correct
the misunderstanding evident in their Motion. Copies of projected load and resource
balances based on both the December 2008 and the May 2009 updated load forecasts
are enclosed with this Response as Attachments Nos. 1 and 2, respectively. Also
enclosed as Attachment NO.3 is an Affidavit of Mr. Karl Bokenkamp confirming that (1)
these load/resource balance projections were prepared by the department he manages
and (2) the most recent load/resource balance based on the May 2009 load forecast is
reasonable and indicates a need for a resource like Langley Gulch in 2012.
It is the Company's intention to file rebuttal testimony providing further
explanation and additional information regarding its load/resource balance projections.
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 10
V.
THE COMPANY'S COMMITMENT TO PROVIDE A REPORT ON ITS GREENHOUSE
GAS REDUCTION STRATEGY DOES NOT ALTER THE COMPANY'S LEGAL
OBLIGATION TO PROVIDE ADEQUATE AND RELIABLE ELECTRIC SERVICE.
In support of their Motion, Intervenors reference the passage of an advisory
shareholder proposal at the Company's 2009 Annual Shareholdets Meeting. The
proposal urges the Company to develop and publish a plan for reducing its emissions of
greenhouse gases. At the meeting, the Company's CEO, LaMont Keen stated that
U(t)he Company takes this vote, an expression of shareowner interest, seriously and will
consider adopting carbon initiative disclosure and/or goals this year."1 From the mere
passage of the advisory proposal, the Intervenors speculate that "a cloud of uncertainty
(exists) over whether. . . Langley Gulch wil be built." (Motion, pp. 2-3.)
Intervenors have apparently forgotten one very important point. Idaho Power is
required by Idaho law to provide adequate and reliable electric service to its customers.
Idaho Code §§ 61-302, -508. Idaho Power is legally required to take this obligation into
consideration in considering any greenhouse gas strategy. The Commission and the
Company's customers can rest assured that in any greenhouse gas reduction analysis,
the Company wil perform a serious and meaningful analysis of greenhouse gas
reduction. But that analysis wil not result in the Company proposing a future resource
strategy that jeopardizes the Company's long history of providing adequate and reliable
electric service.2
i Intervenors erroneously characterize the Company's response to the shareholder proposal as
"an agreement to be bound by it and . . . have its greenhouse gas reduction strategy report prepared by
September 30 of this year." (Motion to Stay, p. 2.)
2 Idaho Power is already among the 26 lowest carbon dioxide emitters within its peer group of the
100 largest electricity producers in the United States.
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 11
Langley Gulch is a critical part of the Company's plan to continue to provide
adequate and reliable electric service and completely consistent with an overall strategy
to control greenhouse gas emissions. Idaho Powets resource plans indicate that it
intends to add significant amounts of new renewable generating resources such as
wind, geothermal, solar, and biofuels. However, it is important to remember that major
categories of these renewable resources, such as wind and solar, are intermittent in
their generation profile. As a result, as the Company adds new renewable wind and
solar resources to its portolio, it must have other types of generating resources
available that can be dispatched on short notice to fil in the gaps when intermittent
renewable resources are not operating. Operating restrictions placed on Idaho Powets
hydro system by various water management agencies means that the Company's hydro
system cannot provide all of the needed back-stop capability. Langley Gulch is the type
of resource that will enhance the Company's abilty to integrate renewable resources in
a way that does not threaten reliability; thereby allowing the Company to fulfill its legal
obligation to supply adequate and reliable electric service while at the same time
providing greenhouse gas reductions.
VI.
THE COMPANY'S DECISION TO SEEK AN EXTENSION OF THE
FILING DATE FOR THE 2009 INTEGRATED RESOURCE PLAN DOES NOT
INDICATE UNCERTAINTY AS TO THE NEED FOR LANGLEY GULCH.
The principal driving factor behind the Company's request for a delay in the filng
of its Integrated Resource Plan was the Company's decision to take a short "pause" in
its pursuit of an Oregon Energy Facilty Siting Council ("EFSC") permit and enter into a
major Community Advisory Process ("CAP") to develop routes for the Company's
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 12
Boardman to Hemingway transmission project ("B2H"). The Community Advisory
Process will involve local citizens in the determination of line routes to submit to the
Bureau of Land Management for its review consistent with the requirements of the
National Environmental Policy Act and to the EFSC for its review under Oregon state
law. It is no secret that there has been substantial opposition in both Idaho and Oregon
to potential routes for the B2H project. It was clear to the Company that additional local
education, consultation, and community involvement was needed to move forward with
the B2H line routing effort. Because most of the B2H line is located in Oregon, the line
routing decision is principally driven by the EFSC process. Since the B2H project is a
critical part of the Company's Integrated Resource Planning process, the fact that the
EFSC effort would be delayed to complete the CAP process, meant that the Company
had the opportunity to update its load forecast and its evaluation of the cost-
effectiveness of B2H and use them in preparing the 2009 IRP.
Intervenors state that "The reasons given for the delay include the widespread
economic turmoil facing the world and specifically its impact on Idaho's economy."
(Emphasis added.) Idaho Powets April 24, 2009, Petition for a change in the IRP due
date did not say that. On page 4 of its Motion, Intervenors also state, "This proposed
plant should not be reviewed when the Company itself contends that its own IRP data is
out of date and it wil require a substantial effort to correct this shortall." (Emphasis
added.) Again, Idaho Power has made no such contention. As noted previously, the
Company periodically updates its load forecast and is confident that the 2009 IRP wil
show the need for Langley Gulch in 2012.
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY -13
Ignoring Intervenors' hyperbole, what Idaho Power did say in it its Petition to
change the IRP due date was: "Substantial changes in economic conditions have
occurred since September of 2008 that may impact the future growth of Idaho Powets
customers' electric loads and the Company believes it would be prudent to update the
sales and load forecast prior to completing the 2009 IRP." (Idaho Power's Petition for
modification of the filing date for its 2009 IRP, pp. 2-3.)
The delay in the EFSC process has given the Company some time to further
update its sales and load forecast for use in the 2009 IRP. However, the Company
remains confident that the 2009 IRP wil show a need for a resource like Langley Gulch
in 2012.
VII.
GRANTING INTERVENORS' MOTION WILL INCREASE
CUSTOMER COSTS AND COULD JEOPARDIZE RELIABILITY.
Intervenors are suggesting a 10-month delay in the schedule for processing this
case. They argue that such a delay wil not be a problem because even with a 10-
month delay, the Langley Gulch project could be available for the summer of 2013.
Unfortunately, the summer of 2013 may be too late. As Attachments Nos. 1 and 2 to
this Response indicate, Idaho Power needs the Langley Gulch project on-line in 2012.
This need for a generating resource in 2012 has been made more acute by the fact that
the Boardman to Hemingway transmission project wil be delayed, probably to as late as
2015. This delay wil increase pressure on all the Company's generation resources.
Having Langley Gulch available as soon as possible in 2012 is more important now than
ever. In addition, depending on how quickly Idaho Power can obtain air quality and
other permits from federal, state, and local agencies, there is a reasonable likelihood
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 14
that Langley could be available for the summer of 2012. The enclosed Affidavit of Vern
Porter describes why Idaho Power believes it can have the Langley Gulch project
available in the summer of 2012. Mr. Portets Affidavit is Attachment NO.4.
At a minimum, granting the 10-month stay as requested by Intervenors will
increase the costs that Idaho Power wil incur to build the Langley Gulch project. On
page 5 of their Motion, Intervenors, without any evidence, facts, or support of any kind,
speculate that Idaho Power should be able to negotiate an extension of any payment
obligations it may have on equipment or services that it has contracted to receive in
order to make sure that this project is available when the Company's customers need it.
In fact, the Intervenors "confidence" that Siemens wil simply agree to an extension of
the date for payments is rank speculation unsupported by economic reality.
Siemens and Idaho Power have executed contracts for manufacture and delivery
of steam and gas turbines by a date certain. The contractual agreements were reached
at a time when the demand for this equipment was high, requiring Idaho Power to make
the prudent decision to secure the equipment in order to meet reasonably anticipated
delivery deadlines that would allow for construction of the Langley Gulch Plant in time to
meet then, and currently, anticipated loads in 2012. The market conditions for such
equipment at the time that these contracts were entered into were such that all of the
potential suppliers, including Siemens, required, even in the face of vigorous
negotiations by Idaho Power, that Idaho Power make interim deposits toward the
equipment and be subject to agreed upon cancellation charges. To argue, as
Intervenors do, that Siemens wil simply relinquish their contractual rights to payment is
unrealistic even if Siemens currently enjoyed a strong market for the equipment. The
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY -15
argument is especially unrealistic when, as Intervenors contend, the market for such
equipment has softened. In a soft market, Siemens' incentive to demand adherence to
existing contractual rights is even greater.
Delaying the decision on the CPCN beyond September 1, 2009, wil subject
Idaho Power to substantial cancellation fees and non-refundable contract payments
under the gas turbine and steam turbine purchase agreements with Siemens. The gas
turbine and steam turbine are the largest equipment items for Langley Gulch, with a
combined total purchase price of approximately $90 millon. Delay would also subject
Idaho Power to potential cancellation fees associated with its engineering, procurement,
and construction contract.
A detailed description of the potential cancellation fees and other payments
resulting from delay or cancellation are set out in Idaho Powets June 8, 2009, 8-K, the
pertinent portions of which are enclosed as Attachment NO.5. In the aggregate, these
cancellation fees and lost deposits would total approximately $25,500.00 on September
30, 2009. Most importantly, however, a 10-month delay in the case schedule would
almost certainly ensure that a new generating resource wil not be in service when
needed to meet reasonably anticipated 2012 loads. That is a risk that should concern
all of the Intervenors.
Before the Commission makes a decision that will certainly increase the cost of
the Langley Gulch project, and may result in cancellation of the project, it should at least
obtain evidence on the record regarding the impact of a delay; it should not rely on the
irresponsible speculation of the Intervenors to make its decision.
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 16
VII.
INTERVENORS INCORRECTLY REPRESENT IDAHO POWER'S ASSESSMENT OF
THE CONTRIBUTIONS OF ITS DSM PROGRAMS.
On page 7 of their Motion, Intervenors assert that Idaho Power has understated
the impact its DSM programs wil have on the Company's need to acquire new
resources. On page 8 of their Motion they say, "These demand response programs
need to be included in the IRP and their effects quantified in determining when supply
side resources are necessary." (Motion, p. 8.) In fact, Idaho Power has included
projections of the impact of its DSM programs in its updated load forecast. These
updated DSM amounts are shown in Attachments Nos. 1 and 2.
In their Motion, Intervenors speculate that Idaho Power may have understated
the impact that its DSM programs might have on reducing its peak loads. Idaho Power
certainly hopes so. To the extent the Company's customers respond to its DSM
programs positively, everyone benefits. However, as shown in Attachments Nos. 1 and
2, Idaho Power has included in its forecasts reasonable estimates of the amount of
DSM that wil be available in the future. Attachments Nos. 1 and 2 show that in the
summers of 2012 and 2013, even including the enhanced DSM programs discussed by
Intervenors in their Motion, the Company stil forecasts substantial demand and energy
shortalls. It is simply not realistic to expect that slightly higher levels of participation in
DSM programs wil in fact wipe out these significant deficits, particularly on the need for
increased amounts of energy. Idaho Power would be very pleased if its DSM programs
are more successful than it anticipates. This would allow the Company to reduce its off-
system purchases of energy, thereby reducing the risks that it cannot reserve suffcient
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 17
transmission for planned energy imports and reducing the risk of higher than expected
market purchase prices it must pass through to its customers.
ix.
IDAHO CODE § 61-541 STILL REQUIRES IDAHO POWER TO DEMONSTRATE
THAT THE LANGLEY GULCH PROJECT DESERVES A CERTIFICATE OF PUBLIC
CONVENIENCE AND NECESSITY.
On Page 4 of their Motion, Intervenors remind the Commission that issuance of a
Certificate of Public Convenience and Necessity is serious business. Intervenors
correctly note that Idaho Power has asked the Commission to utilze the authority it has
been given by the Legislature under the provisions of Idaho Code § 61-541, when
issuing a CPCN for Langley Gulch. The Company remains convinced that the
moderate ratemaking assurances the Company is requesting in this case will be very
important when the Company goes to the credit rating agencies and the financial
community to seek financing the Langley Gulch project. The Company has provided
testimony explaining why, in this time of financial uncertainty, it believes that a
supportive Order from the Commission granting the Company a CPCN for Langley
Gulch is needed to obtain financing for the Langley Gulch project at the lowest possible
cost.
Intervenors have provided no evidence that the ratemaking assurances the
Company is requesting are unreasonable or inconsistent with the public interest.
Intervenors have provided no evidence that the Commission will be unable to
conscientiously consider the evidence presented in this case within the time schedule
contained in the Commission's April 20, 2009, Scheduling Order.
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY -18
All Idaho Power is asking is for the Commission to give due consideration to the
customer benefits that moderate and responsible use of the ratemaking flexibility
authorized by Idaho Code § 61-541 could provide for financing Langley Gulch. Idaho
Power believes this is consistent with the public interest.
x.
PACIFICORP'S CANCELLATION OF ITS 2012 RFP PROVIDES
NO INSIGHT INTO IDAHO POWER'S NEED FOR LANGLEY GULCH.
On July 11, 2006, in Docket No. UM 1208, PacifiCorp filed a draft of its 2012
Requests for Proposals ("RFP") with the Oregon PUC. In its July 11, 2006, filng,
PacifiCorp noted that its filng was required to achieve compliance with the competitive
bidding guidelines imposed by the Oregon, Washington, and Utah Commissions.
Approximately two and a half years later, in February of 2009, PacifiCorp requested that
the Oregon Commission allow it to withdraw from the Oregon competitive bidding
proceeding.
Intervenors provide no data or other evidence that demonstrate that there is any
relevant comparison between PacifiCorp's and Idaho Powets respective needs for new
base load generating resources in 2012.
In their Motion, Intervenors portray PacifiCorp's decision to cancel its RFP
process as being due solely to uncertainty regarding load and economic conditions.
Intervenors are ignoring the rest of what PacifiCorp said in its filing. PacifiCorp also
noted in its filng with the Oregon Commission that "Given the dramatic global economic
downturn in late 2008 and the resulting reduction of customer loads, reduction in price
of commodities and potential reduction of future construction costs, the Company has
determined to further explore resource alternatives." (PacifiCorp Notice of Withdrawal,
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY -19
UM 1208, February 19, 2009, p. 1.) In April of 2008, right in the middle of its Oregon
2012 RFP case, PacifiCorp purchased an existing 520 MW gas-fired generating plant
from a merchant developer. Idaho Power wil not speculate on whether this acquisition
affected PacifiCorp's need for the resource to be procured by the RFP it has now
cancelled. A copy of the press release describing the merchant plant acquisition is
enclosed as Attachment NO.6.
It should also be noted that other regional utilties have announced plans to
pursue new gas-fired generation. Portland General Electric recently announced its
intention to construct a new 400 MW gas-fired power plant. Puget Sound Energy and
PacifiCorp have both included large amounts of gas-fired generation in their near and
intermediate term resource portolios. Copies of the news stories describing PGE's,
Puget Sound's, and PacifiCorp's announcements are enclosed as Attachment NO.7.
XI.
CONCLUSION
Intervenors' failure to provide substantial, competent evidence in support of their
Motion means that the Commission must deny the Motion. Intervenors are still free to
raise their concerns and present evidence in support of their concerns by filing their
testimony and exhibits in accordance with the approved schedule. Idaho Power will
respond and the Commission is more likely to have a sufficient record upon which it can
make a decision based on evidence in the record.
If the Commission is reluctant to deny the Motion at this stage of the case and
believes that it would be desirable to have oral argument on Intervenors' Motion, it
should still require the parties to file their testimony and exhibits on schedule. The
Commission could then schedule oral argument for the first morning of the time set for
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 20
technical hearings in this proceeding. Under either approach, the Commission may
then have a sufficient record upon which to make its decision.
Respectfully submitted this 12th day of June 2009.
¿¿--l)~BARTON L. KL~ ~
Attorney for Idaho Power Company
L
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 21
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on this 12th day of June 2009 I served a true and
correct copy of the within and foregoing document IDAHO POWER COMPANY'S
RESPONSE TO INTERVENORS' JOINT MOTION TO STAY upon the following named
parties by the method indicated below, and addressed to the following:
Commission Staff
Scott Woodbury
Deputy Attomey General
Idaho Public Utilities Commission
472 West Washington
P.O. Box 83720
Boise, Idaho 83720-0074
Industrial Customers of Idaho
Power and Northwest and
Intermountain Power Producers
Coalition
Peter J. Richardson, Esq.
RICHARDSON & O'LEARY PLLC
515 North 27th Street
P.O. Box 7218
Boise, Idaho 83702
Dr. Don Reading
Ben Johnson Associates
6070 Hil Road
Boise, Idaho 83703
Snake River Allance
Ken Miler
Snake River Alliance
P.O. Box 1731
Boise, Idaho 83701
Idaho Irrigation Pumpers
Association, Inc.
Eric L. Olsen
RACINE, OLSON, NYE, BUDGE
& BAILEY, CHARTERED
P.O. Box 1391
201 East Center
Pocatello, Idaho 83204-1391
-X Hand Delivered
U.S. Mail
_ Overnight Mail
FAX
-X Email Scott.WoodburyCCpuc.idaho.gov
Hand Delivered
-X U.S. Mail
_ Overnight Mail
FAX
-X Email peterCCrichardsonandoleary.com
Hand Delivered
-X U.S. Mail
_ Overnight Mail
FAX
-X Email dreadingCCmindspring.com
Hand Delivered
-X U.S. Mail
_ Overnight Mail
FAX
-X Email kmillerCâsnakeriveralliance.org
Hand Delivered
-X U.S. Mail
_ Overnight Mail
FAX
-X Email eloCâracinelaw.net
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 22
Anthony Yankel
Yankel & Associates, Inc.
29814 Lake Road
Bay Vilage, Ohio 44140
Hand Delivered
-L U.S. Mail
_ Overnight Mail
FAX
-L Email tonyCâyankel.net
Idaho Conservation League
Betsy Bridge
Idaho Conservation League
710 North Sixth Street
P.O. Box 844
Boise, Idaho 83701
Hand Delivered
-LU.S.Mail
_ Overnight Mail
FAX
-L Email bbridgetãwildidaho.org
Northwest and Intermountain
Power Producers Coalition
Susan K. Ackerman
9883 NW Nottage Drive
Portland, Oregon 97229
Hand Delivered
-L U.S. Mail
_ Overnight Mail
FAX
-L Email Susan.k.ackermanCâcomcast.net
Community Action Partnership
Association Of Idaho
Brad M. Purdy
Attorney at Law
2019 North 1 ¡th Street
Boise, Idaho 83702
Hand Delivered
-L U.S. Mail
_ Overnight Mail
FAX
-L Email bmpurdy(Chotmail.com
IDAHO POWER COMPANY'S RESPONSE TO INTERVENORS' JOINT MOTION TO STAY - 23
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-09-03
IDAHO POWER COMPANY
ATTACHMENT NO.1
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sales and Load Forecast: SL OUT N09Al 03 - Expected Case
Average Load Peak Load
Percentile Percentile
50th 70th 90th 50th 90th 95th l00
January 2008 1,855 1,900 2,001 2,376 2,545 2,584 2,627
February 2008 1,713 1,758 1,850 2,236 2,426 2,472 2,555
March 2008 1,503 1,530 1,585 1,999 2,081 2,139 2,213
April 2008 1,506 1,549 1,613 1,883 1,939 1,950 1,958
May 2008 1,673 1,747 1,857 2,528 2,688 2,756 2,902
June 2008 2,072 2,156 2,292 3,051 3,223 3,255 3,341
July 2008 2,375 2,437 2,551 3,193 3,345 3,365 3,419
August 2008 2,195 2,235 2,300 2,950 3,029 3,036 3,084
September 2008 1,777 1,808 1,854 2,645 2,823 2,835 2,890
October 2008 1,456 1,475 1,498 1,948 2,001 2,038 2,068
November 2008 1,616 1,637 1,670 2,109 2,234 2,283 2,335
December 2008 1,911 1,94 2,023 2,363 2,615 2,718 2,911
January 2009 1,859 1,907 2,010 2,363 2,532 2,571 2,614
February 2009 1,714 1,760 1,854 2,212 2,402 2,44 2,531
March 2009 1,519 1,546 1,603 2,008 2,090 2,148 2,221
April 2009 1,504 1,547 1,613 1,890 1,946 1,957 1,965
May 2009 1,669 1,742 1,852 2,539 2,700 2,769 2,917
June 2009 2,076 2,162 2,302 3,032 3,207 3,240 3,328
July 2009 2,381 2,44 2,561 3,216 3,371 3,392 3,447
August 2009 2,198 2,237 2,304 2,962 3,042 3,049 3,098
september 2009 1,834 1,865 1,912 2,730 2,911 2,924 2,979
October 2009 1,567 1,587 1,611 2,058 2,111 2,148 2,178
November 2009 1,707 1,728 1,761 2,205 2,330 2,379 2,431
December 2009 1,996 2,030 2,110 2,420 2,675 2,779 2,975
January 2010 1,962 2,009 2,114 2,452 2,621 2,660 2,703
February 2010 1,813 1,860 1,955 2,303 2,494 2,540 2,622
March 2010 1,615 1,643 1,701 2,099 2,181 2,239 2,312
April 2010 1,588 1,632 1,699 1,943 1,999 2,010 2,018
May 2010 1,742 1,817 1,928 2,630 2,793 2,862 3,011
June 2010 2,116 2,202 2,344 3,076 3,253 3,286 3,376
July 2010 2,409 2,473 2,592 3,264 3,423 3,44 3,501
August 2010 2,238 2,278 2,346 3,024 3,106 3,113 3,163
September 2010 1,871 1,901 1,949 2,797 2,982 2,995 3,052
Ocober 2010 1,593 1,613 1,638 2,083 2,136 2,172 2,202
November 2010 1,741 1,762 1,796 2,246 2,371 2,420 2,472
December 2010 2,042 2,077 2,157 2,515 2,777 2,884 3,085
January 2011 2,009 2,057 2,164 2,525 2,695 2,734 2,776
February 2011 1,855 1,902 1,999 2,349 2,540 2,586 2,668
March 2011 1,649 1,677 1,736 2,152 2,234 2,292 2,365
April 2011 1,621 1,665 1,732 1,995 2,051 2,062 2,070
May 2011 1,776 1,851 1,964 2,676 2,841 2,910 3,060
June 2011 2,154 2,241 2,386 3,135 3,315 3,349 3,440
July 2011 2,458 2,523 2,645 3,338 3,501 3,523 3,581
August 2011 2,284 2,325 2,395 3,093 3,178 3,185 3,236
september 2011 1,911 1,941 1,990 2,840 3,028 3,042 3,100
October 2011 1,625 1,645 1,669 2,108 2,161 2,198 2,227
November 2011 1,778 1,800 1,834 2,283 2,409 2,457 2,509
December 2011 2,079 2,113 2,195 2,563 2,832 2,942 3,148
January 2012 2,031 2,080 2,188 2,554 2,724 2,763 2,805
February 2012 1,862 1,910 2,007 2,357 2,547 2,593 2,675
sales and Load Forecast: SL OUT N09Al 03 - Expectd Case
Average LoadPeak Load
PercntilePercntile
50th70th90th50t90th95th100th
March 20121,6641,6921,7522,1722,2542,3122,385
April 2012 1,6371,6811,7492,0112,0672,0782,086
May 20121,7951,8701,9842,7092,8742,943,096
June 20122,1922,2812,4273,2213,4033,4373,531
July 20122,5232,5902,7143,4333,6003,6223,681
August 20122,3372,3792,4503,1713,2573,2~53,317
September 20121,9391,9702,0192,8893,0823,0963,155
October 20121,6491,6701,6942,1302,1832,2202,249
November 20121,8081,8291,8642,3092,4352,4832,535
December 20122,1152,1502,2332,5712,8462,9593,170
January 20132,0632,1132,2222,5712,7402,7792,822
February 20131,9011,9502,0492,3782,5682,6142,696
March 20131,6871,7161,7762,1872,2692,3272,401
April 2013 1,6611,7051,7742,0132,0692,0802,089
May 20131,8191,8962,0112,7482,9152,9853,138
June 20132,2192,3082,4573,2733,4583,4933,588
July 20132,5552,6232,7513,4933,6633,6863,746
August 20132,3692,4112,4843,2263,3143,3223,375
September 20131,9651,9962,0462,9313,1283,1423,202
October 20131,6741,6941,7192,1522,2052,2422,272
November 20131,8371,8591,8942,3422,4672,5162,568
December 20132,1532,1892,2722,6122,8953,0103,227
January 20142,1002,1502,2612,6112,7802,8192,862
February 20141,9321,9812,0812,4052,5952,6412,723
March 20141,7121,7421,8022,2172,3002,3572,431
April 2014 1,6851,7301,7992,0342,0902,1012,109
May 20141,8411,9182,0352,7842,9523,0233,177
June 20142,2402,3302,4823,3223,5093,5453,642
July 20142,5842,6542,7833,5483,7223,7453,807
August 20142,3962,4402,5143,2703,3603,3683,422
September 20141,9872,0192,0692,9723,1733,1873,249
October 20141,6951,7151,7402,1712,2242,2612,290
November 20141,8621,8841,9202,3652,4912,5392,591
December 20142,1832,2192,3042,6252,9133,0303,251
January 20152,1262,1772,2882,6272,7962,8352,878
February 20151,9562,0052,1072,4192,6092,6552,738
March 20151,7331,7631,8242,2352,3172,3752,448
April 2015 1,7031,7481,8192,0382,0942,1052,113
May 20151,8571,9352,0532,8162,9853,0573,212
June 20152,2562,3482,5013,3673,5573,5933,692
July 20152,6072,6772,8103,5983,7763,7993,862
August 20152,4192,4632,5393,3123,4033,4113,467
September 20152,0052,0372,083,0133,2173,2323,294
October 20151,7111,7321,7572,1862,2392,2752,305
November 20151,8821,901,9402,3862,5112,5592,612
December 20152,2122,2482,3342,6412,9343,0543,279
January 20162,1572,2082,3212,6512,8202,8592,902
February 20161,9732,0232,1262,4352,6252,6712,754
March 20161,7591,7891,8512,2592,3412,3992,473
April 2016 1,7261,7721,8432,0492,1052,1162,124
sales and Load Forecast: SL OUT N09Al 03 - Expectd Case
Average Load Peak Load
Percntile Percntile
50th 70t 90th 50th 90t 95th iOoth
May 2016 1,878 1,956 2,076 2,851 3,022 3,094 3,250
June 2016 2,278 2,370 2,526 3,416 3,608 3,645 3,746
July 2016 2,636 2,708 2,843 3,653 3,835 3,859 3,923
August 2016 2,446 2,492 2,569 3,362 3,456 3,464 3,521
September 2016 2,028 2,060 2,111 3,054 3,262 3,277 3,341
October 2016 1,732 1,753 1,779 2,205 2,258 2,294 2,324
November 2016 1,908 1,931 1,967 2,413 2,539 2,587 2,639
December 2016 2,236 2,273 2,359 2,665 2,963 3,084 3,313
January 2017 2,172 2,224 2,338 2,663 2,833 2,872 2,915
February 2017 1,999 2,049 2,153 2,449 2,639 2,685 2,767
March 2017 1,771 1,802 1,864 2,274 2,356 2,414 2,488
April 2017 1,737 1,783 1,855 2,058 2,113 2,124 2,133
May 2017 1,889 1,968 2,089 2,878 3,050 3,123 3,280
June 2017 2,288 2,381 2,539 3,457 3,652 3,689 3,792
July 2017 2,651 2,724 2,862 3,695 3,880 3,904 3,970
August 2017 2,461 2,507 2,586 3,379 3,474 3,483 3,541
september 2017 2,040 2,072 2,123 3,095 3,307 3,323 3,388
October 2017 1,742 1,764 1,789 2,214 2,267 2,303 2,333
November 2017 1,921 1,94 1,981 2,417 2,543 2,591 2,643
December 2017 2,260 2,297 2,384 2,629 2,931 3,055 3,287
January 2018 2,201 2,254 2,369 2,654 2,824 2,863 2,905
February 2018 2,026 2,077 2,181 2,452 2,643 2,689 2,771
March 2018 1,796 1,826 1,890 2,280 2,362 2,420 2,493
April 2018 1,759 1,806 1,878 2,041 2,097 2,108 2,116
May 2018 1,910 1,989 2,112 2,913 3,087 3,160 3,319
June 2018 2,309 2,403 2,564 3,506 3,703 3,741 3,845
July 2018 2,679 2,753 2,894 3,750 3,939 3,964 4,031
August 2018 2,488 2,535 2,616 3,439 3,536 3,545 3,604
September 2018 2,062 2,094 2,146 3,135 3,352 3,367 3,433
October 2018 1,764 1,785 1,811 2,233 2,286 2,323 2,353
November 2018 1,947 1,970 2,007 2,450 2,575 2,624 2,676
December 2018 2,290 2,327 2,415 2,68 2,992 3,118 3,355
January 2019 2,229 2,282 2,399 2,697 2,867 2,906 2,949
February 2019 2,051 2,103 2,209 2,481 2,671 2,717 2,799
March 2019 1,818 1,849 1,913 2,315 2,397 2,455 2,528
April 2019 1,781 1,827 1,900 2,072 2,127 2,138 2,147
May 2019 1,929 2,009 2,134 2,948 3,123 3,197 3,356
June 2019 2,328 2,424 2,587 3,554 3,753 3,792 3,898
July 2019 2,705 2,780 2,924 3,802 3,995 4,020 4,08
August 2019 2,514 2,562 2,64 3,472 3,571 3,580 3,640
September 2019 2,082 2,115 2,168 3,177 3,397 3,413 3,481
October 2019 1,785 1,806 1,832 2,252 2,305 2,341 2,371
November 2019 1,972 1,995 2,032 2,469 2,595 2,643 2,695
December 2019 2,319 2,357 2,446 2,673 2,986 3,115 3,355
January 2020 2,259 2,313 2,431 2,700 2,869 2,908 2,951
February 2020 2,068 2,120 2,227 2,503 2,694 2,740 2,822
March 2020 1,843 1,874 1,938 2,328 2,410 2,467 2,541
April 2020 1,803 1,850 1,924 2,067 2,123 2,134 2,142
May 2020 1,950 2,030 2,156 2,983 3,159 3,234 3,394
June 2020 2,349 2,445 2,611 3,602 3,804 3,843 3,951
sales and Load Forecast: SLOUT _N09AI 03 - Expected case
Average LoadPeak Load
PercntilePercentile
50t70t90t50th90th95th100th
July 20202,7332,8102,9563,8574,0534,0794,149
August 20202,5422,5902,6753,5233,6243,6333,695
September 20202,1062,1392,1923,2203,443,4613,529
October 20201,8071,8281,8542,2722,3252,3612,391
November 20201,9982,0212,0592,4982,6232,6722,724
December 20202,3572,3952,4852,7123,0323,1633,408
January 20212,3002,3542,4732,7412,9102,9492,992
February 20212,1172,1702,2782,5222,7122,7582,840
March 20211,8751,9071,9722,3642,4462,5042,578
April 2021 1,8321,8801,9542,0902,1462,1572,166
May 20211,9772,0582,1853,0243,2023,2773,439
June 20212,3772,4742,6423,6563,8603,8994,010
July 20212,7702,842,9973,9214,1204,1474,218
August 20212,5782,6272,7133,5833,6863,6953,758
September 20212,1362,1692,2233,2633,4913,5073,577
October 20211,8361,8581,882,2992,3522,3882,418
November 20212,0342,0572,0952,5372,6622,7112,763
December 20212,4002,4392,5302,7633,0903,2233,475
January 20222,3432,3972,5182,7902,9592,9983,041
February 20222,1562,2102,3192,5572,7482,7942,876
March 20221,9091,9402,0062,4052,4872,5442,618
April 2022 1,8631,9101,9862,1182,1742,1852,193
May 20222,0042,0862,2163,0663,2453,3213,484
June 20222,4052,5042,6753,7103,9163,9574,069
July 20222,8082,8883,0413,9874,1904,2174,289
August 20222,6152,6652,7533,643,7493,7583,822
September 20222,1672,2012,2553,3053,5373,5533,624
October 20221,8671,8891,9152,3272,3802,4162,446
November 20222,0692,0932,1312,5772,7022,7512,803
December 20222,4432,4822,5732,8123,1473,2833,540
January 20232,3862,4422,5632,8393,0083,0473,090
February 20232,1962,2502,3602,5932,7842,8302,912
March 20231,9421,9742,0412,4452,5272,5852,658
April 2023 1,8931,9412,0172,1472,2022,2132,222
May 20232,0342,1162,2473,1103,2903,3663,530
June 20232,4352,5352,7083,7643,9744,0144,128
July 20232,8472,9293,0844,0534,2604,2874,360
August 20232,6532,7042,7943,7033,8093,8193,884
September 20232,2002,2342,2883,3483,5843,6013,673
October 20231,8981,9201,9472,3552,4082,4452,475
November 20232,1062,1302,1682,6152,7412,7892,841
December 20232,4852,5242,6172,8543,1953,3353,597
January 20242,4292,4852,6072,8813,0513,0903,132
February 20242,2242,2782,3892,6292,8202,8662,94
March 20241,9762,0082,0752,4822,5642,6222,695
April 2024 1,9241,9732,0502,1712,2272,2382,246
May 20242,0632,1462,2793,1533,3353,4113,577
June 20242,4652,5662,7423,8204,0314,0734,188
July 20242,8852,9683,1264,1174,3284,3564,430
August 20242,6912,7432,8343,7623,8703,8803,946
sales and Load Forecast: SL OUT NogAl 03 - Expected Case
Average Load Peak Load
Percentile Percntile
50th 70th 90t 50th 90th 95th IOOth
september 2024 2,231 2,265 2,321 3,391 3,631 3,64 3,721
October 2024 1,930 1,952 1,979 2,385 2,438 2,474 2,504
November 2024 2,142 2,166 2,205 2,654 2,779 2,828 2,880
December 2024 2,528 2,568 2,661 2,897 3,245 3,388 3,655
January 2025 2,471 2,527 2,650 2,923 3,093 3,132 3,175
February 2025 2,274 2,329 2,441 2,658 2,849 2,895 2,977
March 2025 2,009 2,041 2,109 2,519 2,601 2,659 2,732
April 2025 1,954 2,003 2,081 2,195 2,251 2,262 2,270
May 2025 2,091 2,175 2,309 3,196 3,378 3,456 3,622
June 2025 2,493 2,595 2,774 3,873 4,088 4,129 4,247
July 2025 2,923 3,008 3,169 4,183 4,397 4,425 4,501
August 2025 2,729 2,782 2,875 3,821 3,931 3,941 4,008
September 2025 2,264 2,298 2,354 3,435 3,678 3,696 3,770
October 2025 1,961 1,983 2,010 2,413 2,466 2,502 2,532
November 2025 2,177 2,201 2,240 2,691 2,817 2,865 2,917
December 2025 2,572 2,612 2,706 2,941 3,296 3,442 3,715
January 2026 2,513 2,570 2,694 2,967 3,137 3,176 3,218
February 2026 2,312 2,368 2,480 2,691 2,882 2,928 3,010
March 2026 2,041 2,074 2,142 2,556 2,638 2,696 2,770
April 2026 1,984 2,033 2,112 2,219 2,275 2,286 2,294
May 2026 2,119 2,203 2,339 3,238 3,422 3,500 3,668
June 2026 2,522 2,625 2,807 3,928 4,144 4,187 4,306
July 2026 2,961 3,047 3,212 4,248 4,466 4,495 4,572
August 2026 2,766 2,820 2,915 3,879 3,992 4,002 4,070
September 2026 2,296 2,330 2,387 3,478 3,725 3,743 3,819
October 2026 1,991 2,014 2,040 2,440 2,493 2,530 2,560
November 2026 2,212 2,236 2,276 2,729 2,855 2,903 2,955
December 2026 2,615 2,655 2,749 2,983 3,346 3,495 3,773
January 2027 2,555 2,612 2,738 3,010 3,179 3,218 3,261
February 2027 2,351 2,406 2,520 2,724 2,914 2,960 3,042
March 2027 2,075 2,108 2,177 2,594 2,676 2,734 2,807
April 2027 2,014 2,064 2,143 2,243 2,299 2,310 2,318
May 2027 2,146 2,232 2,370 3,280 3,466 3,544 3,713
June 2027 2,550 2,655 2,839 3,982 4,201 4,244 4,365
July 2027 2,999 3,087 3,255 4,314 4,535 4,565 4,643
August 2027 2,803 2,858 2,955 3,937 4,052 4,062 4,131
september 2027 2,327 2,361 2,419 3,520 3,771 3,790 3,866
October 2027 2,021 2,04 2,070 2,468 2,521 2,557 2,587
November 2027 2,247 2,272 2,312 2,768 2,893 2,941 2,994
December 2027 2,658 2,698 2,793 3,025 3,395 3,547 3,831
January 2028 2,598 2,655 2,782 3,053 3,222 3,261 3,304
February 2028 2,377 2,433 2,548 2,760 2,950 2,996 3,079
March 2028 2,108 2,141 2,210 2,631 2,713 2,771 2,845
April 2028 2,04 2,094 2,174 2,266 2,322 2,333 2,341
May 2028 2,175 2,261 2,401 3,324 3,510 3,589 3,759
June 2028 2,579 2,684 2,872 4,036 4,257 4,301 4,424
July 2028 3,038 3,127 3,298 4,380 4,605 4,635 4,715
August 2028 2,840 2,896 2,995 3,995 4,111 4,122 4,192
September 2028 2,359 2,393 2,451 3,563 3,818 3,836 3,914
Ocober 2028 2,052 2,074 2,101 2,496 2,548 2,585 2,615
Sales and Load Forecast: SLOUT_ NogAl 03 - Expectd Case
Average LoadPeak Load
PercentilePercentile
50th70thgOth50th90th95thiOOth
November 20282,2822,3072,3472,8052,9312,9793,031
December 20282,7002,7402,8363,0663,443,5983,888
January 20292,6422,7002,8273,0973,2663,3053,348
February 20292,4292,4862,6012,7892,9793,0253,108
March 20292,1422,1752,2452,6692,7512,8092,883
April 2029 2,0752,1252,2062,2912,3472,3582,366
May 20292,2042,2912,4333,3673,5553,6343,806
June 20292,6092,7162,9064,0914,3154,3594,484
July 20293,0773,1683,3424,4454,6744,7054,786
August 20292,8792,9353,0364,0544,1724,1834,254
September 20292,3912,4262,4843,6063,8653,883,963
October 20292,0842,1062,1342,5252,5782,6152,64
November 20292,3192,342,3842,842,9693,0183,070
December 20292,7442,7852,8813,1103,4953,6523,947
January 20302,6862,7442,8723,1403,3093,3483,391
February 20302,4692,5262,6422,8223,0123,0583,140
March 20302,1762,2092,2792,7072,7892,8472,920
April 2030 2,1072,1572,2392,3162,3722,3832,392
May 20302,2342,3222,4653,4113,6003,6803,853
June 20302,6392,7472,9404,1464,3724,4174,544
July 20303,1153,2083,3854,5114,7434,7744,857
August 20302,9172,9753,0784,1134,2334,2444,317
September 20302,4232,4592,5183,6503,9133,9324,012
October 20302,1162,1382,1652,5542,6072,642,673
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BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-09-03
IDAHO POWER COMPANY
ATTACHMENT NO.2
MWaMW
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saies and Lod Forest: SL OUT N09Al 03 - Expe case
Average Lod Pek Lod
Percntile Percntile
50th 70t 90th 50th 90th 95th 100th
January 2008 1,855 1,90 2,001 2,376 2,545 2,584 2,627
February 2008 1,713 1,758 1,850 2,236 2,426 2,472 2,555
March 2008 1,503 1,530 1,585 1,999 2,081 2,139 2,213
April 2008 1,S06 1,549 1,613 1,883 1,939 1,950 1,958
May 2008 1,673 1,747 1,857 2,528 2,688 2,756 2,902
June 2008 2,072 2,156 2,292 3,051 3,223 3,255 3,341
July 2008 2,375 2,437 2,551 3,193 3,345 3,365 3,419
August 200 2,195 2,235 2,300 2,950 3,029 3,036 3,084
september 2008 1,777 1,80 1,854 2,645 2,823 2,835 2,890
October 2008 1,456 1,475 1,498 1,948 2,001 2,038 2,068
November 2008 1,616 1,637 1,670 2,109 2,234 2,283 2,335
December 2008 1,911 1,94 2,023 2,363 2,615 2,718 2,911
January 2009 1,859 1,907 2,010 2,363 2,532 2,571 2,614
February 2009 1,714 1,760 1,854 2,212 2,402 2,44 2,531
March 2009 1,519 1,546 1,603 2,008 2,090 2,148 2,221
April 2009 1,504 1,547 1,613 1,890 1,94 1,957 1,965
May 2009 1,669 1,742 1,852 2,539 2,700 2,769 2,917
June 2009 2,076 2,162 2,302 3,032 3,207 3,240 3,328
July 2009 2,381 2,44 2,561 3,216 3,371 3,392 3,447
August 2009 2,198 2,237 2,304 2,962 3,042 3,049 3,098
September 2009 1,834 1,865 1,912 2,730 2,911 2,924 2,979
October 2009 1,567 1,587 1,611 2,058 2,111 2,148 2,178
November 2009 1,707 1,728 1,761 2,205 2,330 2,379 2,431
December 2009 1,996 2,030 2,110 2,420 2,675 2,779 2,975
January 2010 1,962 2,009 2,114 2,452 2,621 2,660 2,703
February 2010 1,813 1,860 1,955 2,303 2,494 2,540 2,622
March 2010 1,615 1,643 1,701 2,099 2,181 2,239 2,312
April 2010 1,588 1,632 1,699 1,943 1,999 2,010 2,018
May 2010 1,742 1,817 1,928 2,630 2,793 2,862 3,011
June 2010 2,116 2,202 2,344 3,076 3,253 3,286 3,376
July 2010 2,409 2,473 2,592 3,264 3,423 3,44 3,501
August 2010 2,238 2,278 2,346 3,024 3,106 3,113 3,163
september 2010 1,871 1,901 1,949 2,797 2,982 2,995 3,052
Ocober 2010 1,593 1,613 1,638 2,083 2,136 2,172 2,202
November 2010 1,741 1,762 1,796 2,246 2,371 2,420 2,472
December 2010 2,042 2,077 2,157 2,515 2,777 2,884 3,085
January 2011 2,009 2,057 2,164 2,525 2,695 2,734 2,776
February 2011 1,855 1,902 1,999 2,349 2,540 2,586 2,668
March 2011 1,649 1,677 1,736 2,152 2,234 2,292 2,365
Apn12011 1,621 1,665 1,732 1,995 2,051 2,062 2,070
May 2011 1,776 1,8S1 1,964 2,676 2,841 2,910 3,06
June 2011 2,154 2,241 2,386 3,135 3,315 3,349 3,44
July 2011 2,458 2,523 2,645 3,338 3,501 3,523 3,581
August 2011 2,284 2,325 2,395 3,093 3,178 3,185 3,236
september 2011 1,911 1,941 1,99 2,840 3,028 3,042 3,100
October 2011 1,625 1,645 1,669 2,108 2,161 2,198 2,227
November 2011 1,778 1,800 1,834 2,283 2,409 2,457 2,509
December 2011 2,079 2,113 2,195 2,563 2,832 2,942 3,148
January 2012 2,031 2,080 2,188 2,554 2,724 2,763 2,805
February 2012 1,862 1,910 2,007 2,357 2,547 2,593 2,675
March 2012 1,664 1,692 1,752 2,172 2,254 2,312 2,385
April 2012 1,637 1,681 1,749 2,011 2,067 2,078 2,086
May 2012 1,795 1,870 1,984 2,709 2,874 2,94 3,096
June 2012 2,192 2,281 2,427 3,221 3,403 3,437 3,531
July 2012 2,523 2,590 2,714 3,433 3,600 3,622 3,681
saies and Lod Forest: SL_OULN09AL03 - Ex~ case
Average LodPek Lo
PercntlePercntile
50th70t90th50th90t95thlOO
August 20122,3372,3792,4503,1713,2573,2653,317
September 20121,9391,9702,0192,8893,0823,0963,155
October 20121,6491,6701,6942,1302,1832,2202,249
November 20121,8081,8291,862,3092,4352,4832,535
December 20122,1152,1502,2332,5712,842,9593,170
January 20132,0632,1132,2222,S712,7402,7792,822
February 20131,9011,9502,0492,3782,5682,6142,696
March 20131,6871,7161,7762,1872,2692,3272,401
April 2013 1,6611,7051,7742,0132,0692,0802,089
May 20131,8191,8962,0112,7482,9152,9853,138
June 20132,2192,3082,4S73,2733,4S83,4933,588
July 20132,5552,6232,7513,4933,6633,6863,746
August 20132,3692,4112,483,2263,3143,3223,375
september 20131,9651,992,042,9313,1283,1423,202
October 20131,6741,6941,7192,1522,2052,2422,272
November 20131,8371,8591,892,3422,4672,5162,568
December 20132,1532,1892,2722,6122,8953,0103,227
January 20142,1002,1502,2612,6112,7802,8192,862
February 20141,9321,9812,0812,4052,5952,6412,723
March 20141,7121,7421,8022,2172,3002,3572,431
April 2014 1,6851,7301,7992,0342,0902,1012,109
May 20141,8411,9182,0352,7842,9523,0233,177
June 20142,2402,3302,4823,3223,5093,5453,642
July 20142,5842,6542,7833,5483,7223,7453,807
August 20142,3962,442,5143,2703,3603,3683,422
September 20141,9872,0192,0692,9723,1733,1873,249
October 20141,6951,7151,7402,1712,2242,2612,290
November 20141,8621,8841,9202,3652,4912,5392,591
December 20142,1832,2192,3042,6252,9133,0303,251
January 20152,1262,1772,2882,6272,7962,8352,878
February 20151,9562,0052,1072,4192,602,6552,738
March 20151,7331,7631,8242,2352,3172,3752,448
April 20151,7031,7481,8192,0382,0942,1052,113
May 20151,8571,9352,0532,8162,9853,0573,212
June 20152,2562,3482,5013,3673,5573,5933,692
July 20152,6072,6772,8103,5983,7763,7993,862
August 20152,4192,4632,5393,3123,4033,4113,467
September 20152,0052,0372,083,0133,2173,2323,294
October 20151,7111,7321,7572,1862,2392,2752,305
November 20151,8821,901,942,3862,5112,5592,612
December 20152,2122,2482,3342,6412,9343,0543,279
January 20162,1572,2082,3212,6512,8202,8592,902
February 20161,9732,0232,1262,4352,6252,6712,754
March 20161,7591,7891,8512,2592,3412,3992,473
April 2016 1,7261,7721,8432,0492,1052,1162,124
May 20161,8781,9562,0762,8513,0223,0943,250
June 20162,2782,3702,5263,4163,6083,6453,746
July 20162,6362,7082,8433,6533,8353,8593,923
August 20162,442,4922,5693,3623,4563,4643,521
september 20162,0282,062,1113,0543,2623,2773,341
October 20161,7321,7531,7792,2052,2582,2942,324
November 20161,9081,9311,9672,4132,5392,5872,639
December 20162,2362,2732,3592,6652,9633,0843,313
January 20172,1722,2242,3382,6632,8332,8722,915
February 20171,9992,0492,1532,4492,6392,6852,767
Sales and Lod Forest: SL OUT N09A1 03 - Expe case
Average Lod Peak Load
Percntile Percntile
50h 70t 90t 50 90th 95th 100th
March 2017 1,771 1,802 1,86 2,274 2,356 2,414 2,488
April 2017 1,737 1,783 1,855 2,058 2,113 2,124 2,133
May 2017 1,889 1,968 2,089 2,878 3,050 3,123 3,280
June 2017 2,288 2,381 2,539 3,457 3,652 3,689 3,792
July 2017 2,651 2,724 2,862 3,695 3,880 3,904 3,970
August 2017 2,461 2,507 2,586 3,379 3,474 3,483 3,541
september 2017 2,04 2,072 2,123 3,095 3,307 3,323 3,388
October 2017 1,742 1,764 1,789 2,214 2,267 2,303 2,333
November 2017 1,921 1,94 1,981 2,417 2,543 2,591 2,643
December 2017 2,260 2,297 2,384 2,629 2,931 3,055 3,287
January 2018 2,201 2,254 2,369 2,654 2,824 2,863 2,905
February 2018 2,026 2,077 2,181 2,452 2,643 2,689 2,771
March 2018 1,796 1,826 1,890 2,280 2,362 2,420 2,493
April 2018 1,759 1,806 1,878 2,041 2,097 2,108 2,116
May 2018 1,910 1,989 2,112 2,913 3,087 3,160 3,319
June 2018 2,309 2,403 2,564 3,506 3,703 3,741 3,845
July 2018 2,679 2,753 2,894 3,750 3,939 3,964 4,031
August 2018 2,488 2,535 2,616 3,439 3,536 3,545 3,604
september 2018 2,062 2,094 2,146 3,135 3,352 3,367 3,433
October 2018 1,764 1,785 1,811 2,233 2,286 2,323 2,353
November 2018 1,947 1,970 2,007 2,450 2,575 2,624 2,676
December 2018 2,290 2,327 2,415 2,68 2,992 3,118 3,355
January 2019 2,229 2,282 2,399 2,697 2,867 2,906 2,949
February 2019 2,051 2,103 2,209 2,481 2,671 2,717 2,799
March 2019 1,818 1,849 1,913 2,315 2,397 2,455 2,528
April 2019 1,781 1,827 1,900 2,072 2,127 2,138 2,147
May 2019 1,929 2,009 2,134 2,94 3,123 3,197 3,356
June 2019 2,328 2,424 2,587 3,554 3,753 3,792 3,898
July 2019 2,705 2,780 2,924 3,802 3,995 4,020 4,088
August 2019 2,514 2,562 2,64 3,472 3,S71 3,580 3,640
september 2019 2,082 2,115 2,168 3,177 3,397 3,413 3,481
Octber 2019 1,785 1,806 1,832 2,252 2,305 2,341 2,371
November 2019 1,972 1,995 2,032 2,469 2,595 2,643 2,695
December 2019 2,319 2,357 2,44 2,673 2,986 3,115 3,355
January 2020 2,259 2,313 2,431 2,700 2,869 2,908 2,951
February 2020 2,068 2,120 2,227 2,503 2,694 2,740 2,822
March 2020 1,843 1,874 1,938 2,328 2,410 2,467 2,541
April 2020 1,803 1,850 1,924 2,067 2,123 2,134 2,142
May 2020 1,950 2,030 2,156 2,983 3,159 3,234 3,394
June 2020 2,349 2,445 2,611 3,602 3,804 3,843 3,951
July 2020 2,733 2,810 2,956 3,857 4,053 4,079 4,149
August 2020 2,542 2,590 2,675 3,523 3,624 3,633 3,695
september 2020 2,106 2,139 2,192 3,220 3,44 3,461 3,529
October 2020 1,807 1,828 1,854 2,272 2,325 2,361 2,391
November 2020 1,998 2,021 2,059 2,498 2,623 2,672 2,724
December 2020 2,357 2,395 2,485 2,712 3,032 3,163 3,40
January 2021 2,300 2,354 2,473 2,741 2,910 2,949 2,992
February 2021 2,117 2,170 2,278 2,522 2,712 2,758 2,840
March 2021 1,875 1,907 1,972 2,364 2,44 2,504 2,578
April 2021 1,832 1,880 1,954 2,090 2,146 2,157 2,166
May 2021 1,977 2,058 2,185 3,024 3,202 3,277 3,439
June 2021 2,377 2,474 2,642 3,656 3,860 3,899 4,010
July 2021 2,770 2,848 2,997 3,921 4,120 4,147 4,218
August 2021 2,578 2,627 2,713 3,583 3,686 3,695 3,758
september 2021 2,136 2,169 2,223 3,263 3,491 3,507 3,577
saies and Lo Forest: SL_OULN09AL03 - ~ ca -Average LoPek Lo
PercntlePercntile
50t70th90th50th90th95th100h
October 20211,8361,8581,8842,2992,3522,3882,418
November 20212,0342,0572,0952,5372,6622,7112,763
December 20212,4002,4392,5302,7633,0903,2233,475
January 20222,3432,3972,5182,7902,9592,9983,041
February 20222,1562,2102,3192,5572,7482,7942,876
March 20221,9091,942,0062,4052,4872,5442,618
April 2022 1,8631,9101,9862,1182,1742,1852,193
May 20222,0042,0862,2163,0663,2453,3213,48
June 20222,4052,5042,6753,7103,9163,9574,069
July 20222,8082,8883,0413,9874,1904,2174,289
August 20222,6152,6652,7533,643,7493,7583,822
september 20222,1672,2012,2553,3053,5373,5S33,624
October 20221,8671,8891,9152,3272,3802,4162,44
November 20222,0692,0932,1312,5772,7022,7512,803
December 20222,4432,4822,5732,8123,1473,2833,540
January 20232,3862,4422,5632,8393,003,0473,090
February 20232,1962,2502,3602,5932,7842,8302,912
March 20231,9421,9742,0412,4452,5272,5852,658
April 2023 1,8931,9412,0172,1472,2022,2132,222
May 20232,0342,1162,2473,1103,2903,3663,530
June 20232,4352,5352,7083,7643,9744,0144,128
July 20232,8472,9293,0844,0534,2604,2874,360
August 20232,6532,7042,7943,7033,803,8193,884
september 20232,2002,2342,2883,3483,5843,6013,673
October 20231,8981,9201,9472,3552,4082,4452,475
November 20232,1062,1302,1682,6152,7412,7892,841
December 20232,4852,5242,6172,8543,1953,3353,597
January 20242,4292,4852,6072,8813,0513,0903,132
February 20242,2242,2782,3892,6292,8202,8662,94
March 20241,9762,002,0752,4822,5642,6222,695
April 2024 1,9241,9732,0502,1712,2272,2382,246
May 20242,0632,1462,2793,1533,3353,4113,577
June 20242,4652,5662,7423,8204,0314,0734,188
July 20242,8852,9683,1264,1174,3284,3564,430
August 20242,6912,7432,8343,7623,8703,8803,946
september 20242,2312,2652,3213,3913,6313,6483,721
October 20241,9301,9521,9792,3852,4382,4742,504
November 20242,1422,1662,2052,6542,7792,8282,880
December 20242,5282,5682,6612,8973,2453,3883,655
January 20252,4712,5272,6502,9233,0933,1323,175
February 20252,2742,3292,4412,6582,8492,8952,977
March 20252,0092,0412,1092,5192,6012,6592,732
April 2025 1,9542,0032,0812,1952,2512,2622,270
May 20252,0912,1752,3093,1963,3783,4563,622
June 20252,4932,S952,7743,8734,0884,1294,247
July 20252,9233,003,1694,1834,3974,4254,501
August 20252,7292,7822,8753,8213,9313,9414,008
september 20252,2642,2982,3543,4353,6783,6963,770
October 20251,9611,9832,0102,4132,462,5022,532
November 20252,1772,2012,2402,6912,8172,8652,917
December 20252,5722,6122,7062,9413,2963,4423,715
January 20262,5132,5702,6942,9673,1373,1763,218
February 20262,3122,3682,4802,6912,8822,9283,010
March 20262,0412,0742,1422,5562,6382,6962,770
April 2026 1,9842,0332,1122,2192,2752,2862,294
sales and Lod Forest: SL OUT N09Al 03 - Expe case
Average Load Pek Lo
Percntile Percntile
50h 70t 90t 50th 90th 95th 100th
May 2026 2,119 2,203 2,339 3,238 3,422 3,500 3,668
June 2026 2,522 2,625 2,807 3,928 4,144 4,187 4,306
July 2026 2,961 3,047 3,212 4,248 4,466 4,495 4,572
August 2026 2,766 2,820 2,915 3,879 3,992 4,002 4,070
September 2026 2,296 2,330 2,387 3,478 3,725 3,743 3,819
October 2026 1,991 2,014 2,040 2,44 2,493 2,530 2,560
November 2026 2,212 2,236 2,276 2,729 2,855 2,903 2,955
Deæmber 2026 2,615 2,655 2,749 2,983 3,34 3,495 3,773
January 2027 2,555 2,612 2,738 3,010 3,179 3,218 3,261
February 2027 2,351 2,406 2,520 2,724 2,914 2,960 3,042
March 2027 2,075 2,108 2,177 2,594 2,676 2,734 2,807
April 2027 2,014 2,064 2,143 2,243 2,299 2,310 2,318
May 2027 2,146 2,232 2,370 3,280 3,466 3,544 3,713
June 2027 2,550 2,655 2,839 3,982 4,201 4,244 4,365
July 2027 2,999 3,087 3,255 4,314 4,535 4,565 4,643
August 2027 2,803 2,858 2,955 3,937 4,052 4,062 4,131
September 2027 2,327 2,361 2,419 3,S20 3,771 3,790 3,866
October 2027 2,021 2,044 2,070 2,468 2,521 2,557 2,587
November 2027 2,247 2,272 2,312 2,768 2,893 2,941 2,994
December 2027 2,658 2,698 2,793 3,025 3,395 3,547 3,831
January 2028 2,598 2,655 2,782 3,053 3,222 3,261 3,304
February 2028 2,377 2,433 2,548 2,760 2,950 2,99 3,079
March 2028 2,108 2,141 2,210 2,631 2,713 2,771 2,845
April 2028 2,04 2,094 2,174 2,266 2,322 2,333 2,341
May 2028 2,175 2,261 2,401 3,324 3,510 3,589 3,759
June 2028 2,579 2,684 2,872 4,036 4,257 4,301 4,424
July 2028 3,038 3,127 3,298 4,380 4,605 4,635 4,715
August 2028 2,840 2,896 2,995 3,995 4,111 4,122 4,192
September 2028 2,359 2,393 2,451 3,S63 3,818 3,836 3,914
October 2028 2,052 2,074 2,101 2,496 2,548 2,585 2,615
November 2028 2,282 2,307 2,347 2,805 2,931 2,979 3,031
December 2028 2,700 2,740 2,836 3,066 3,44 3,598 3,888
January 2029 2,642 2,700 2,827 3,097 3,266 3,305 3,34
February 2029 2,429 2,486 2,601 2,789 2,979 3,025 3,108
March 2029 2,142 2,175 2,245 2,669 2,751 2,809 2,883
April 2029 2,075 2,125 2,206 2,291 2,347 2,358 2,366
May 2029 2,204 2,291 2,433 3,367 3,555 3,634 3,806
June 2029 2,609 2,716 2,906 4,091 4,315 4,359 4,48
July 2029 3,077 3,168 3,342 4,445 4,674 4,705 4,786
August 2029 2,879 2,935 3,036 4,054 4,172 4,183 4,254
September 2029 2,391 2,426 2,484 3,606 3,865 3,884 3,963
October 2029 2,084 2,106 2,134 2,525 2,578 2,615 2,64
November 2029 2,319 2,344 2,384 2,84 2,969 3,018 3,070
December 2029 2,744 2,785 2,881 3,110 3,495 3,652 3,947
January 2030 2,68 2,744 2,872 3,140 3,309 3,348 3,391
February 2030 2,469 2,526 2,642 2,822 3,012 3,058 3,140
March 2030 2,176 2,209 2,279 2,707 2,789 2,847 2,920
April 2030 2,107 2,157 2,239 2,316 2,372 2,383 2,392
May 2030 2,234 2,322 2,465 3,411 3,600 3,680 3,853
June 2030 2,639 2,747 2,94 4,146 4,372 4,417 4,544
July 2030 3,115 3,208 3,385 4,511 4,743 4,774 4,857
August 2030 2,917 2,975 3,078 4,113 4,233 4,244 4,317
September 2030 2,423 2,459 2,518 3,650 3,913 3,932 4,012
October 2030 2,116 2,138 2,165 2,554 2,607 2,64 2,673
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BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-09-03
IDAHO POWER COMPANY
ATTACHMENT NO.3
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MAnER OF IDAHO POWER
COMPANY'S APPLICATION FOR A
CERTIFICATE OF PUBLIC
CONVENIENCE AND NECESSITY FOR
THE LANGLEY GULCH POWER PLANT.
)
) CASE NO. IPC-E-09-03
)
) AFFIDAVIT OF KARL BOKENKAMP
)
)
STATE OF IDAHO)
) ss.County of Ada )
Karl Bokenkamp, of Idaho Power Company, being first duly sworn, deposes and
states as follows:
1. That I am the General Manager of Power Supply Operations &
Planning for Idaho Power Company ("Idaho Power" or the "Company").
2. That this Affdavit is made in support of the Company's Response
to Intervenors' Joint Motion to Stay which has been filed in this proceeding
("Response").
3. That the load and resource balances enclosed with the Response
as Attachments Nos. 1 and 2 were prepared by the Power Supply Planning department
I manage.
4. That, in my opinion, the load and resource balance contained in
Attachment NO.2 is a reasonable forecast that indicates that the Company wil need a
resource, like Langley Gulch, in 2012.
FURTHER YOUR AFFIANT SAYETH NAUGHT.~~~~~
SUBmR1MJ.~D SWORN to before me this (' thday of June 2009.~r- S ,--.. ~, C~.,tt '\~ . "¡/l.. "" hM
" ~ .. J. ~ -+n Rt /Ì fì . . _ _ v-U ~U~ \ U )U~I V ~.- .. æ Notary Public lo Ic;ah~. - ,Cl E Residing at: ,W j,Q i -bclOD"6
\.. PU9" .~ ¡ My commission expires: 02/0Y /201 5,. ~;.:,. .r :' ~. ....
"'",/"A TE 0\1 \",....'............,.,
AFFIDAVIT OF KARL BOKENKAMP
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-09-03
IDAHO POWER COMPANY
ATTACHMENT NO.4
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF IDAHO POWER
COMPANY'S APPLICATION FOR A
CERTIFICATE OF PUBLIC
CONVENIENCE AND NECESSITY FOR
THE LANGLEY GULCH POWER PLANT.
)
) CASE NO. IPC-E-09-03
)
) AFFIDAVIT OF VERNON PORTER
)
)
STATE OF IDAHO )
) ss.County of Ada )
Vernon Porter, of Idaho Power Company, being first duly sworn, deposes and
states as follows:
1. That I am the General Manager of Power Production for Idaho
Power Company ("Idaho Powet' or the "Company").
2. That this Affidavit is made in support of the Company's Response
to Intervenors' Joint Motion to Stay which has been filed in this proceeding
("Response").
3. That Idaho Power has been advised by its engineering,
procurement, and construction service provider, a joint venture of Kiewit Power
Engineers and The Industrial Company ("TIC"), that there is a reasonable likelihood that
Langley could be available for the summer of 2012. Availabilty would depend on how
quickly Idaho Power can obtain air quality and other permits from federal, state, and
local agencies.
FURTHER YOUR AFFIANT SAYETH NAUGHT.\~~
VERNON PORTER
S~~ AND SWORN to before me this IO-fh day of June 2009.
~1" S. lh. ~..#.~~.. "-1.p"\ t~ ExIJ oTAIl )1'..\ ) a Q~, .. ~ I' ¡ Notary Public r Inàho _
:. ..... *: Residing at: i? ISQ. ..ctú'oo
\ ~V8\.\C I = Mycommissionexpires: DZ(0'1/2015--.. "0 ~ ,~ ~ ...~.. ....~....
'#",./'S 0 F \\) ~~"",,,'",........,',.
AFFIDAVIT OF VERNON PORTER
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-09-03
IDAHO POWER COMPANY
ATTACHMENT NO.5
Langley Gulch Intervenor Request for Stay
As previously reportd, on March 6, 2009 !PC fied an application with the IPUC for a Certificate of
Public Convenience and Necessity (CPCN authorizing IPC to constrct, own and operate the Langley
Gulch power plant (Langley Gulch). Lanley Gulch will be a natual gas-fired combined cycle
combustion tubine generating plant to be constrcted in Payette County, Idao, with a generating
capacity of approximately 300 MW in the sumer and 330 MW in the winter. WC requested in its
CPCN application that the WUC issue its order in the Lanley Gulch CPCN case (Langley Gulch Case)
by September 1, 2009.
On May 29,2009 ajoint motion was fied in the Langley Gulch Case by the Industrial Customers of
Idaho Power, the Idao Irigation Pumpers Association, the Snake River Allance, the Idaho Conservation
League and the Northwest & Intermountain Power Producers Coalition, requesting that the IPUC stay the
Langley Gulch Case for at least ten month (Request for Stay). The Request for Stay assert that the stay
should be granted by the IPUC because (1) IPC should first respond to the advisory shareholder proposal
adopted by IDACORP's shareholders in May 2009, relating to reductions in WC greenhouse gas
4
emissions, (2) IPC's 2009 Integrated Resource Plan is not scheduled to be fied until December 2009, (3)
IPC's request for IPUC ratemaking preapproval for Langley Gulch, based on Idaho's newly adopted rate
commtment statute, increases the importance ofthe IPUC's decision on Langley Gulch, (4) IPC should
be able to negotiate an extension, perhaps at additional cost, of the September 1,2009 payment dates for
the purchase of the Siemens tubines for Langley Gulch, (5) IPC has already delayed the on-line date for
Langley Gulch from the sumer of2012 to December 2012, and IPC's next peak load followig the
summer of2012 wil not occur until the sumer of2013, (6) the continuing recession ha reduced the
demand for new IPC generation facilties, and the need for Langley Gulch should be reassessed when a
general economic recovery has begu, (7) PacifiCorp is "mothballing" planed generation expanions,
and (8) the impacts ofIPC's demand response programs have not been ascertined.
IPC plans to oppose the Request for Stay. Delaying the IPUC decision date on the Langley Gulch CPCN
for at least 10 months beyond September 1,2009 would delay the 2012 in-service date for the project and
jeopardize IPC's abilty to meet customer loads in 2012 and beyond. Langley Gulch is scheduled to fill
the key 2012 base load resource requirement identified in IPC's curent Integrated Resource Plan. IPC's
updated customer load projections continue to show the need for Langley Gulch generation capacity by a
2012 project in-servce date. Based on these curent load projections, and based on IPC's discussions
with the contractors performing the Langley Gulch Engineering, Procurement and Constrction Services
Agreement discussed below, IPC is workig to advance the Langley Gulch in-servce date from
December 2012 to June 2012.
Delaying the IPUC CPCN decision beyond September 1,2009 would also increase IPC's exposure to
cancellation fees and non-refudable contract payments under IPC's gas tubine and steam tubine
purchase agreements for Langley Gulch, as discussed below. The gas turbine and steam tubine are the
largest equipment items for Langley Gulch, with a combined total purchase price of approximately $90
milion.
Under the gas tubine purchase agreement with Siemens Energy (Gas Turbine Agreement), IPC's
purchase of the gas tubine is subject to IPUC issuace of the CPCN by September 1,2009, among other
conditions. In the event IPC does not receive the CPCN by September 1,2009, the Gas Turbine
Agreement would automatically terminate, unless IPC and Siemens Energy reach an agreement within 30
days afer that date to modify the contract price, equipment delivery schedule and other affected terms
and conditions of the Gas Turbine Agreement. Upon such termination, IPC would be required to pay a
cancellation fee of35 percent of the tota purchase price of the gas tubine, less any payments already
made by IPC under the Gas Turbine Agreement. The Gas Turbine Agreement also contain a schedule of
cancellation fees IPC must pay if it termnates the Gas Turbine Agreement at any time during the contract
term, absent assignent of the Gas Turbine Agreement by IPC with the wrtten consent of Siemens
Energy. The cancellation fees are based on a percentage of the tota gas tubine purchase price and
increase monthly from 20 percent on July 1,2009 to 100 percent on or after September 1,2010.
The steam turbine purchae ageement with Siemens Energy (Stea Turbine Agreement) also contans a
cancellation fee schedule. IPC has the right to terminate the Steam Turbine Agreement at any time upon
paying a cancellation fee to Siemens Energy based on a percentage ofthe total purchae price of the
steam tubine, absent assignent of the Steam Turbine Agreement by IPC with the written consent of
Siemens Energy. The Steam Turbine Agreement cancellation fee percentage increases monthly from 10
percent on Februar 1,2009 to 100 percent on or afer May 1,2011. The cancellation fee is 15 percent on
September 1, 2009.
IPC must also make non-refudable contract payments to Siemens Energy tUder the Gas Turbine
Agreement beginning on September 1,2009, in addition to its previous non-refudable reservation fee
payment of$2.75 milion. IPC's September 1,2009 contract payment is approximately 20 percent of the
5
tota gas tubine purchase price, with additiona monthy payments thereafer, concludig with the fial
contract payment on Jaiua 1,2011. The cumulative amount ofIPC's contract payments under the Gas
Turbine Agreement would be offset agait any cacellation fees owed by IPC under the Gas Turbine
Agreement.
IPC must also make non-refudable contrt payments to Siemens Energy under the Steam Turbine
Agreement beginng on September 11,2009, in addition to its previous non-refudable payments for the
steam tubine - the reservation fee payment of approxiately $2.9 milion and the initial contract payment
of approxitely $3.1 millon. IPC's September 11, 2009 contrt paytent is 14 percent of the total
steam tubine purhase price, with additional contract payments due in March 2010, September 2010 and
April 20 11, and a smaller fial contract payment due at final acceptance of the steam turbine. The
cumulative amount ofIPC's contract payments under the Stea Turbine Agreement would be offset
against any cancellation fees owed by IPC under the Steam Turbine Agreement.
On May 7, 2009, IPC entered into an Enginerig, Procurement and Constrtion Servces Agreement
(EPC Agreement) with Boise Power Parers Joint Ventue, a joint ventue consisting of Kiewit Power
Engineers Co. and TIC-The Industrial Company (collectively, the Contractor), for design, engineering,
procurement, constrction management and constrction services for Lagley Gulch.
The EPC Agreement is the primar ageement governg the proposed development of Langley Gulch, ..
providing for the specific design, engineering and constrction work to be perormed for Langley Gulch,
as well as the equipment procurement required for the project. The total contract price to be paid by !PC
under the EPC Agreement is approximately one-half ofthe projected $427 milion total project cost for
Langley Gulch.
The EPC Agreement provides that IPC is to issue a Full Notice to Proceed (FNTP) to the Contractor no
later than September 1, 2009 to authorize the Contractor to commence and complete all work under the
EPC Agreement. IPC plan to issue the FNT by September 1,2009 if it ha (i) received an acceptable
CPCN from the ¡PUC, (ii) received board approval and (ii) identified satisfactory financing options for
the project at that time. The EPC Agreement provides that if IPC does not issue the FNTP by November
1,2009, the Contractor may termnate the EPC Agreement, which termination will be without liabilty to
either par other than for the Contractor's costs properly incured pursuant to any work performed under
the Master Services Agreement between IPC and the Contractor dated October 3,2008. The amounts
payable under the Master Services Agreeent are not expected to be material to !PC.
IPC is requied to make monthy progress payments to the Contractor under the EPC Agreement
beginng in October 2009. The first twelve monthly progress payments between October 2009 and
September 2010 will represent approxitely one-four of the total payments scheduled to be made by
IPC under the EPC Agreement. IPC may termte the EPC Agreement at any time if it abandons the
Langley Gulch project. Upon such termition, the Contractor is entitled to keep the progress payments
previously paid by IPC, and IPC would be requid to pay the value of the work completed to the date of
termination not previously covered by IPC progress payments, plus a 15 percent markup on such costs.
6
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-09-03
IDAHO POWER COMPANY
ATTACHMENT NO.6
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BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-09-03
IDAHO POWER COMPANY
ATTACHMENT NO.7
CLEARING UP. June 8, 2009 . No. 1393 . Page 2
Week in
Summary
proceeding. The intervenors--
environmental groups, power developers
and large customers--say they aren't
necessarily opposed to the proposed gas-fired plant, but
the Idaho PUC should not rule on it by Sept. 1, as the
utility has requested. Intervenors say the commission
should take more time to assess utility's largest capital
investment since Hells Canyon, at (17).
(6) Idaho PUC OKs Four Rate IncreasesTotaling 14.1 Percent, $116 Milion
The Idaho PUC approved four rate increases May 29 for
Idaho Power customers that together wil add about
$116 milion to annual revenues and increase overall rates
by about 14.1 percent. The largest of the four bumps comes
from the anual power cost adjustment, which averaged
10.24 percent for an overall $84-milion increase. Another
$15.6 millon came from an energy effciency rider,
$10.5 milion from an automated-meters installation rider,
and $5.2 milion from a fixed-cost adjustment. At (20), the
PUC takes a long view of rate increase benefit.
(7) Oregon Muni's Experience ShowsLoad Control Works
About 20 years before Pacific Northwest Labs
conducted its now-famous GridWise demonstration
project, the city of Milton-Freewater, Ore., initiated
demand reduction programs to reduce the peak-demand
charges the muni paid to BPA. The first--a voltage-
reduction program--saved the muni enough money in the
initial year to pay for its newly installed SCADA
system. The second employed a one-way commun-
ications system that successfully reduced peak demand
even more. Lessons the region could learn from
Milton-Freewater, at (18).
(8) BPA Asked for Federal Money toStudy Pumped Storage
The Bonnevile Power Administration has asked the
U.S. Department of Energy for a grant to study pumped
storage technology as way to help balance the region's
growing wind portfolio. The governors of the four
Pacific Northwest states are also on board. They sent a
letter to DOE late last month supporting BPA's request.
At (21), wind and water.
(9) Senate Committee Adds 1S-PercentRenewables Standard to Energy Bil
The Senate Energy and Natural Resources
Committee added a 15-percent renewables portfolio
standard to the panel's comprehensive energy bil. The
stadard would allow utilities to meet one-four of the
requirement with energy effciency. Meanwhile, House
Ways and Means Committee Republicans sent a letter to
committee Chairan Charles Ragel (D-N.Y.) urging him
to schedule a markup on the climate and energy bil cleared
May 21 by the Energy and Commerce Committee. The
Interior Deparment's Mineras Management Servce is
holdig West Coast workshops ths month on new
offhore rmewable energy regulations, at (22).
Briefs
(10) PGE to Seek 40o-MW BaseloadResource Near Boardman
Portland General Electric intends to issue a request
for bids next ear callin tor a 400-MW naturaI- as-
ired combined-cycle combustion tu ine that would
locate in orrow ounty, Ore., near the Boardman coal-
fired power plant. 'lhe baseload resource wil be the self-
build benchmark bid in the utility's request for proposals.
Construction of the winning bid could "possibly"
start in 2012, Steve Corson, PGE spokesman, told
Clearing Up, but a lot of other things would have to
happen first, he added.
"This is a process." Corson said of the RFP. "It's not
a done deaL. "
Resource planning must be based on an integrated
resource plan acknowledged by the Oregon PUC, which
must also sign off on RFPs that stem from the plan.
Corson said PGE would submit a draft IRP to the
commission this summer for a 30-day comment period,
and a final version in the fall for a nominal 6-month
review process. The base load resource would address
future needs and supplement its current portfolio of
resources and contracts.
As par of the plang for the self-build bid project--
dubbed the Car Generatig Facilty--PGE will submit it to
Oregon's Energy Facilty Siting Council for site certfication.
The council wil take up the matter for the first time
at its June 12 meeting, where it wil start the process for
authorizing Morrow County to review the project and to
serve as a special advisory group for it.
The 400-MW baseload project is among several PGE
has pursued in recent months. The utilty announced in
December that it would retool a proposed baseload
project at its Port Westward site to serve as a peaking
unit that could be used to smooth out its growing wind
holdings (CU No. 1367 (3/12)).
The original Port Westward base load project was
certified as a pair of CCCTs with total net capacity of
650 MW, which later morphed into a two-part
project. The 400-MW first phase broke ground in
2004 (CU No 1155 (9.4)), and went on line in 2007
(CU No. 1292 (11.2)) (Rick Adair).
(10.1 J Grant County PUD Considering 250.MW
Gas.Fired CCCT
Grant County PUD is studying whether a 250-MW
natural-gas~fired combined-cycle combustion turbine
makes sense for meeting its near-term load growth,
which is dominated by large industrial customers such
as server farms.
As an early step, the PUD has issued a request for
bids on engineering services to help conduct a feasibility
study of the resource.
"Through our integrated resource planning, we can
see where natural gas might be the right resource
choice," Kevin Nordt, the PUD's director of power
management, told Clearing Up, adding that the district
is probably the fastest growing utilty in Northwest.
Copyright (92009. Energy NewsData Corporation
AN INDEPENDENT NEWS SERVICE FROM ENERGY NEWSDATA
. Monday, June 8, 2009 . No. 1393 .
NORTHWEST
ENERGY
MARKETS
Energy and Utiity News for the U.S. Pacifc Nortwest
and Western Canada
Inside.. .
Courts &
Commissions
. Idaho PUC OKs Four Rate
Increases Totaling
14.1 Percent, $116 Milion..... (6120)
Supply &
Demand
. Oregon Muni's Experience
Shows Load Control Works.... (7/18)
. BPA Asked for Federal Money to
Study Pumped Storage.. .. . .. . .. . .. .. .. .. .. .. .. .. .
. Senate Committee Adds 15-Percent
Renewables Standard to Energy Bil . . . . . . . . . . . . .
. PGE to Seek 400-MW Baseload Resource
N ear Boardman ..................................."
(821)
(9/22)
(10)
. Grant County PUD Considering 250-MW
Gas-Fired CCCT.................................."
. FERC, Washington Sign MOU on
Hydrokinetic Projects. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. Sea Lions Split for the Season.. .. .. . .. .. .. .. .. .
. Featherweight Wind Blades May Soon Be
Made in SE Washington...........................
. Resource Future Perspectives
Vary--But Not as Much as
They Appear.... .. .. .. .. .. .. .. .. .
. Employment Data Hint at
Leveling Out. . . . . . . . . . . . . . . . . . . . .
(10.1)
(10.2)
(10.3)
(10.4)
Notes &
Comments (11)
Northwest
, Numbers (12)
Price
Report
. As Rain Falls and Hydro
Flows, Power Prices Fall.
Details on page 5.
I The Week in Summary I
(1) ENW Asks Members to Help Fund NewNuke Feasibility Study
Energy Northwest is asking its members if they are
interested in contributing $25,000 to join a "participants
committee" to complete pre-development work on a
modular nuclear reactor project. The joint operating
agency says it needs between $250,000 and $500,000 to
move forward with the pre-development work for the
project, which would use as-yet-unapproved technology
to build a baseload plant consisting of 40-MW modular
nuclear units at a site near the Columbia Generating
Station. At (13), ENW says it's too early to tell if the
study--much less a new nuke--will go forward.
(2) DSM, Wind, Gas Prominent in Puget,
PacifiCorp IRPs
Demand-side resources, wid energy and natur gas-
fired power figue prominently as new resources in the just-
releaed PacifCorp and Puget Sound Energy integrated
resource plans. Both featue stagnant load levels for the
next few year as the economy recovers, then a resumption
of growt. At (14), Puget sees a huge range ofhicr-
menta pordolio costs fìm $14 bilon to $28 bilon,
whie at (15), onl a whiper of coal remais hi
PaciñCorp's long-rage road map hi the form of coal-
plant tubhie upgrades.
(3) Northwest IOUs Report ModerateLoad Effects Amid Troubled Economy
Nortwest investor-owned utilities report a range of
moderate load effects amid the distressed economy, ranging
from slightly decliing to flat and even projections of
growt. All fall within a relatively narow band, suggestingtroubled economic times do not necessarily directly
correlate to significant load reductions, at least in the
absence of major industrial closures or slowdowns.
Lowdown on Nortwest iou loads, at (16).
(4) DEQ Puts Boardman on Path toClean Up or Closure
The staff of the Oregon Department of
Environmental Quality is standing firm on its plan to
clean up Portland General Electric's Boardman power
plant. Under DEQ's Regional Haze Plan, PGE would
have to upgrade Boardman's emissions controls in thee
stages between 2011 and 2018. PGE says the upgrades wil
cost between $545 milion to $645 milion, raising
questions about the future of Oregon's only coal-frred
power plant. At (19), rate incrases cut thugh the haz.
(5) Intervenors Want IPUC to Take MoreTime on IPC's Langley Gulch Proposal
Five of the six intervenors in Idaho Power's petition
for Idaho PUC approval of its proposed Langley Gulch
power plant have fied a joint motion to stay the
CLEARING UP _ June 8, 2009 - No. 1393 _ Page 8
combine their interests and jointly contribute $25.000
would be able to do so. but would have only one
representative on the committee.
"I remain optimistic about this option and believe it
should be seriously considered as a future power supply
option." Baker says in the letter. "I believe it wil have a
cost and carbon advantage as a base-load resource."
If enough ENW members come forward with
funding. the group wil further determine such items as
the initial electrical generation size of the project, as
well as expansion planning; adequacy of the proposed
site; amount of existing information that could be used
for the combined operating license; best financing
strategy; construction and operational costs of the
project; political and public acceptance; and best time
for commercial operation.
The phase 1 due-diligence study would take from
three to six months, ENW estimates. Phase 2--
preparation of the license--would take from 18 to
24 months and cost from $18 milion to $20 milion.
Phase 3--NRC approval of the license--would take
36 to 48 months to complete. with projected costs of
$25 milion to $30 milion. Phase 4--construction and
commissioning--would take another 36 to 48 months.
The final cost per KW is estimated at between $3,500
and $4.500.
Seattle City Light. Snohomish County PUD and
Chelan County PUD are not interested in the project.
according to sources. (Jude Noland).
(14) DSM, Wind, Gas Feature in Puget
Draft Resource Plan - from 121
Demand-side resources, wind power and natural gas-
fired power all feature prominently in Puget Sound
Energy's 20-year new-resource outlook.
By 2020, according to Puget' s draft 2009 Integrated
Resource Plan, the utility's needs include 808 MW of
new demand-side resources and 1000 MW of new wind
capacity. ~nother 1580 MW wil be new gas-fired supgbl,
comttsing 1100 MW ot combined-cycle capacity and
580 W of peãk¡. The gas component would Wow to
3150 MW cumulative additions by 2029. while DSM
Would expand to 1030 MW and wind to 1200 MW.
"Options for resource additions remain limited." said
an executive summary of the plan. "Wind is stil the
only renewable resource capable of generating utility-
scale power for PSE. new hydroelectric projects are not
feasible at this time. nuclear projects are unlikely to gain
approval, and coal remains constrained by
environmental concerns."
The summary also noted that "the plan recommends
additonal wind resources to fulfil renewables
requirements, as much demand-side resources as
possible (38 aMW per year for the first 12 years), and
more natural gas-fired generating plants to fil the
remainder of need."
The draft IRP is under review by outside parties, and
the final IRP is scheduled for July 31 fiing with the
Washington Utilities and Transportation Commission,
according to a company release.
PSE spokesman Roger Thompson said the final
version might contain "some tweaks here and there,"
but no additional major analysis.
Pugets new-resource necessities are fueled primarily
by expiring purchased-power contracts and prospective
retirements of existing plants. Expiring resources
account for 819 MW of need by 2012, 1685 MW by
2020 and 2322 MW by 2029. Based on a revised low-
growth forecast, load-related resource needs are
projected at 105 MW by 2012, 955 MW by 2020 and
2054 MW by 2029.
These combine for an anticipated total resource need of
924 MW by 2012,
2640 MW by 2020 and
4376 MW by 2029.
Puget s peak is
projected to grow
from about 4850 MW
in 2009 to nearly
5550 MW in 2017.
Annual electric sales--now at about 2450 aMW--are
expected to be virtually flat through 2010, then
eventually rise to roughly 2800 aMW by 2017,
according to the draft demand forecast.
The proposed effciency levels in the draft IRP are
22 percent higher than under the 2007 IRP, which called
for about 30 aMW annual targets.
"Energy effciency is stil the best strategy for
avoiding the costs and the risks of a volatile energy
market." said PSE Chief Resource Officer Kimberly
Haris. in the news release.
Pugets wid portfolio would expand to nearly
1600-MW capacity over 20 year, just about quadrpling
its current 386 MW of capacity at two Washington sites.
The investor-owned utility has relied on developers to
build or signifcantly prepare wind projects for it. but given
the current financial constraints on independent power
producers, Puget may have to get in the development game
earlier and asume more risk, the summar said.
Conservation and renewables would account for
41 percent of the added capacity by 2029. with natural
gas accounting for virtually the entire remainder.
Pugets 2007 fuel-supply mix was nearly 42 percent
hydro, 37 percent coaL. 19 percent natural gas and a
smattering of other resources. accordig to utility-reported
data compiled by Washington state governent.
Estimated incremental cost of Puget s prospective new
resource portfolio varies hugely, from $14 bilion on a
20-year net-present-value basis to $28 bilion. About
60 percent of this yawning gap is attibuted to uncertain
future natural-gas prices, and most of the remainder owes
to unowns over the impact of cap-and-trade carbon
legislation on energy costs and market prices, according to
the silmar. Puget' s 2007 IRP portolio was pegged at
$14 bilion, which in tum had risen from $8.1 bilion in the
2005 plan and $4.4 bilion in the 2003 version.
PSE projects at least a 50-percent growt in its overal
resource needs for natual gas, which it said now accounts
for about 30 percent of electrc generation, in addition to
serving the utility's 750.000 retail gas customers.
'Energy efficiency is stil
the best strateg for
avoiding the costs and
the risks of a volatile
energy market.'
Copyright (92009. Energy NewsData Corporation
CLEARNG UP . June 8, 2009 . No. 1393 . Page 7
Continued from page 5
it veers around the documented shortcomings of wind
power to serve peak loads. as the region grows
increasingly concerned about capacity, not just energy.
It also fails to effectively address the seeming inconsistency
between pushing for GHG emissions cuts while tag out
some 3000 MW of carbon-free hydro capacity.
On the other side. while the utility response has
emphasized the imperative of real-world system
operations and reliable/affordable power. some of it
seems to give short shrift to certain reasonable
possibilities in the Bright Future vision. For
example, wind shaping and integration might be
feasibly accomplished while maintaining system
reliability and affordability. Or. smart grid
applications indeed could bring substantial peak-
leveling benefits to the region.
Let's take Bright Future for what it is (and isn't), and
give NWEC credit for outlining a vision. The Pacific
Northwest Utilties Conference Committee is developing
its own vision piece. which wil undoubtedly serve as a
major contribution.
And. of course. the big kahuna of regional resource
planning is the council's endeavor. now scheduled for
draft release in July. BPA's resource program also
promises a key perspective.
There seems to be broad agreement on at least one
general theme: a greener energy future is coming.
Energy effciency is a fundamental and growing piece in
many utilty and other outlooks, along with renewables.
Natural gas remains the new fossil fuel of choice; new
coal is effectively out of the game, until-and if--carbon
capture/sequestration becomes a reality.
While the pace and countless other aspects of this
green-power trend remain to be seen. we are generally
heading in a similar direction for new resources.
Whether in the council or other venues. the differing
maps should be brought together and common features
highlighted. A truly regional vision of a resource future
would be powerful indeed (Mark OhrenschallJ.
Supply & Demand I
(13) ENW Asks Members to Help Fund New
Nuke Feasibility Study. from f1
Energy Northwest is asking its members if they are
interested in contributing $25,000 to join a "participants
committee" to complete pre-development work on a
modular nuclear reactor project.
In a May 27 letter to the public power consortium's
25 members, ENW VP Jack Baker says ENW wants to
form the committee to complete pre-development work and
"decide if there is enough interest to purue the Combined
Operating License. which is estiated to cost $50 milion. "
Pre-development money would be refunded if the
project gets financed, and project participants would get
first choice at the inital project allocation.
According to the letter. Energy Northwest needs
between $250.000 and $500,000 to move forward with
the pre-development work for the project, which would
use as-yet -unapproved technology to build a baseload
plant comprised of 40-MW modular nuclear units.
NuScale Power of Corvalls. Ore.. is
commercializing the technology. which was developed
and tested by Oregon State University, Idaho National
Lab and Nexant-Bechtel under DOE-funded research.
The company, founded in 2007. is in the process of
licensing its technology and has had three pre-
application meetings with the NRC, with a fourth
scheduled in August.
NuScale's standard design is for a power plant with
up to 12 40-MW modules. generating 480 aMW. It's
too soon to say how many modules ENW would
construct. said spokeswoman Rochelle Olson.
Olson added that ENW is "just seeing if there is
utility interest. . . we don't even know if this wil go
forward. "
If there is interest. the joint agency is proposing that
such a project be built on property near the Columbia
Generating Station. on leased land at the Hanford site.
NuScale's design involves a small nuclear reactor.
positioned vertically inside its own containment pooL.
Each reactor has its own turbine generator and
feedwater system. and is cooled by natural circulation.
The entire nuclear system is 60 feet by 15 feet and
weighs 300 tons. according to a company presentation.
The reactor. the control room and fuel pool would all be
built underground. enhancing security and safety. Major
components would be prefabricated.
Olson said nuclear waste from the reactor would be
stored on site. just as spent fuel from the Columbia
Generating Station is stored--in above-ground concrete
and steel casks--" until a national repository is identified,
or recycling of used fuel begins."
ENW does not characterize disposal of the spent fuel
as an issue, she added. "We know where the waste is;
we don't even consider it waste, but a valuable
resource" that wil be useful in the future, with fuel
recycling. And "unlike waste issued from carbon-
emitting resources. we know where we store our used
fuel and have complete control over it. "
Olson added that ENW has a responsibility to look at
a mix of technologies. especially those that emit little or
no carbon. and reiterated that its consideration of this
one is in the very. very early stages. She said the
agency has also looked into a 1600-MW reactor
designed by Unistar. but that the scalability of
NuScale's design makes it "the best option for public
power in our region."
Baker's letter asks ENW members to respond by
June 23 if they are interested in participating in the pre-
development work. Smaller utilities that want to
Copyright (92009, Energy NewsData Corporation
CLEARING UP. June 8, 2009 . No. 1393 . Page 9
e
(15) PacifiCorp IRP Focuses on Renewables,Gas, Efficiency and DSM . from (2)
PacifiCorp continued its trend of stripping coal from
its long-range resource roadmap, and adding wind, gas,
efficiency and conservation in the latest version fied in
late May with regulators in its six-state service territory.
The roadmap--the 2008 Integrated Resource Plan--
looks out 20 years to plan PacifiCorp's resources, but
focuses on the next 10 years for portfolio development.
PacifiCorp's existing coal-fired portfolio has a
capacity of 6128 MW, which currently accounts for
46.6-percent of its capacity and 58 percent of its
generation. The only hint of any new coal in the utility's
preferred portolio is 170 MW from increasing the
effciency at its existing coal plants. The preferred portfolio
would also drop coal's capacity in the mix to 42.6 percent
in 2018, and the generation to 40.6 percent.
It would also drop PacifiCorp's C02 emissions
intensity 15 percent by 2018, and 32 percent by 2028,
from 0.8 tons of C02 per MWh in 2009, to about
0.66 in 2018, and to about 0.54 in 2028.
The bulk of new generation would come from
1313 MW of new wind capacity, with the lion's share--
1048 MW--to be located in PacifiCorp's eastern control
area, corresponding roughly to its range in Wyoming,
Utah and Idaho. There, increments of mostly 100 MW
are planned from 2012 to 2018.
No new wind in the western region--Washington,
Oregon and California--is contemplated after 2011.
Other renewables include 75 MW of hydroelectric
upgrades in 2012 to 2014, and a 35-MW geothermal
expansion to come online in 2013.
Also accounting at times for large amounts of
acquired generation are firm-market purchases that
range from 50 to 1400 MW on an annual basis, and are
contingent on the timing and amounts of long-term
resource acquisitions. After 2012, plans call for this
resource never dropping below 900 MW.
Demand-side management accounts for between
about 1110 and 1230 MW in the lO-year planning
period, with 904 MW from effciency measures, and
205 to 325 MW from dispatchable load control.
Another 831 MW of new gas-fired generation would
be brought online between 2014 and 2016.,
Rounding out the resource map is 46 MW of
combined heat and power acquired in 1-, 2- or 4-MW
increments annually.
The trend of diminishing coal made its first mark in the
2007 IRP, which although it stared out with considerable
plan for new coal--parcularly in the utilty's eastern
servce area (CU No. 1285 (2/13))--this dwindled as
climate regulations were implemented in some Western
states, and the cost of new coal projects crept up, stoked by
carbon emissions reguations (CU No. 1317 (3/16)).
Other changes in the 2008 IRP compared to the 2007
IRP include the acquisition of the 520-MW Chehalis gas
plant and 175-MW of additional wind resources added
in 2008, and the incorporation of the Energy Gateway
Transmission project in the portfolio analysis
Also new is the use of recent IRP guidelines issued
by the Oregon PUC on the treatment of carbon dioxide
regulatory risk, as well as modeling changes and
expansion of resource options, per regulatory orders in
the states PacifiCorp serves.
Recent economic events have also impacted the new
IRP, causing a reduction of resource need, with the system
becoming short on capacity in 2011 rather than 2010 due to
lower forecasted loads and new resource additions.
Because regulatory constraints on fiing dates in
some of PacifiCorp' s jurisdictions meant the IRP would
be based on load predictions from last November, the
results of the plan wil likely alter, the utilty said, once
updated data is used.
For example, using load forecast data from Februar
2009 to conduct a sensitivity analysis, PacifCorp found that
a 2016 intercooled aeroderivative SCCT in the preferred
portfolio was no longer needed, and that deferral and
modest reductions in firm market purchases was cost-
effective combined with an increase in customer standby
generation and addition of utility-scale biomass resources,
based on using the capacity expansion modeL.
Nevertheless, PacifiCorp said, since the relative
resource impact of the February 2009 load forecast is
"minimal" until 2016, it decided to retain the IC aero
SCCT in the preferred portfolio.
Also supporting this decision, PacifCorp said, is the
uncertainty over the timing and pace of an economic
recovery, combined with the short lead-time for a gas-
peaking resource and the potential need for such
resources to support wind integration.
Consideration of the timing and tye of gas resources
and other resource changes wil be handled as par of an
asumptions update and portolio analysis to be conducted
for the next business plan and 2008 IRP update.
Also accounted for in the 2008 IRP is the Energy
Gateway Transmission project, whose eight planned
segments are treated as existing resources for portfolio
modeling purposes. The $6-bilion project would
develop 2,000 miles of new transmission line across the
West (CU No. 1361 (3/14); CU No. 1379 (13)).
Copyright ~2009, Energy NewsData Corporation
CLEARNG UP . June 8, 2009 . No. 1393 . Page 10
Going forward. PacifiCorp said, Gateway
transmission segments wil be reevaluated from an
integrated resource planning perspective during the IRP
and annual business planning cycles (Rick Adair).
(16) NW IGUs Report Moderate LoadImpacts in Distressed Economy. from (31
The slumping economy is having only moderate impact
on loads of the region's investor -owned utilities. ranging
from slightly declining to projections of modest growt.
This indicates troubled economic times do not
necessarily directly correlate to significant load
reductions, at least in the absence of major industrial
closures or shutdowns.
Nationally. the U. S. Energy Information
Administration reported in its May 12 short-term energy
outlook. "The drag on industrial retail sales of
electricity as a result of the ongoing recession is
expected to decrease total electricity consumption by
o . 8 percent this year. Consumption is projected to return to
a more normal growt rate of 1.5 percent in 2010."
By region, EIA calls out a 3-percent projected 2009
decline in retail electric sales in California. Oregon and
Washington compared to 2008, but a 0.5-percent
increase in the Mountain region states that include Idaho
and Montana.
By sector, in the Pacific states. residential and
commercial consumption is forecast to vary by less than
1 percent. but industrial consumption is expected to
drop by 12 percent. The Mountain region is envisioned
to experience 1-2 percent growth in both residential and
commercial sectors, and about a I-percent decline in
industrial consumption this year.
The Northwest Power Pool, which encompasses all
or some of eight Western U.S. states and two Canadian
provinces. predicts a summer peak of 54.500 MW with
normal weather conditions. That's only slightly above
the 2008 coincident peak of 54.190 MW. set during
below-normal temperature conditions Aug. 14.
This year's projection "reflects the prevailing
economic climate (down-tum)," according to NWPP's
March 13 assessment of reliability and adequacy for
summer 2009.
"We don't forecast a very big load growth." Power
Pool President/Director Jerry Rust told Clearing Up in
late March.
Industrial closures or slowdowns are generally the
source of any significant near-term load losses during
economic travails. Rust said.
"Until we see a mass movement of people out of the
area, you don't see an impact on residentiaL. Until
there's a mass change in commercial operations, you
don't see a change in commercial load, " at least from a
broad regional perspective. Rust said.
The Nortwest Power and Conservtion Council
affirmed this in a recent example cited in its Februar draft
demand forecast for its upcoming 6th regional plan.
"As a result of the energy crisis of 2000-2001 and the
recession of 2001-2002, regional load decreased by
3700 aMW between 2000 and 2001." it said. "Loss of
many of the aluminum and chemical companies that were
direct service industries contributed to this load reduction."
Although total Northwest electric sales rebounded
and grew 2.5 percent annually on average. from 2002-
2007. they hadn't reached 2000 levels as of year-end 2007.
a council char showed. Durng thatperiod. residential
loads grew 888 aMW and commercial loads rose
285 aMW. but industrial loads declined by 337 aM.
Rust suggested checking with individual utilties.
Investor-owned utilties serve about half of Washington
state's retail load. and large majorities of load in
Oregon. Idaho and Montana.
"We have not seen anything out of the ordinary at
all with regard to load as a result of the economic
slowdown." Steve Reynolds. president and CEO of
Puget Sound Energy. told Clearing Up in early April.
Weather-adjusted residential and commercial electric
sales "are about right on target" Reynolds said. He
noted Puget's larger customers "tend to be big
campuses." such as Microsoft and the state capitol in
Olympia. "and they have not reduced their loads."
For 2009's first quarer. Puget experienced a
0.5-percent decrease in
total retail electric sales
compared to first
quarer 2008. according
to its May 5 lO-Q fiing
with the Securties and
Exchange Commission.
PSE's Form lO-K
for 2008 showed a 1.8-percent increase in total electric
sales biled to customers, from 21.5 milion MWh in
2007 to 21.9 milion MWh in 2008. Its average electric-
customer numbers rose 1.4 percent. from 1. 048 milion
to 1.063 milion.
Reynolds said Puget is seeing fewer new customers
hooking into its system.
"What we've seen over the last year, both gas and
electric. is the pace of new customer additions for
residential and commercial is much lower than it has
been. . . We're stil connecting a large number of new
customers. but not at the pace we've seen during the
boom times" of recent years.
"I thnk the economic health of our region--we're
fortunate--is reasonably healthy." Reynolds said, adding.
"We wil contiue probably to see some slowdown."
PSE has delayed until July 30 the planned fiing of its
latest integrated resource plan, to better gauge economic
factors and their potential effects on load forecasts and
resource needs (CU No. 1384 (9)).
PacifiCorp, meanwhile, has made substantial
changes to its resource plans, based to an extent on load
reductions.
The six-state utilty in February announced
cancellation of plans to acquire 600 MW of baseload
generation and capacity for its eastern control area
starting in 2012 (CU No. 1379 (4/16)), and also that
month suspended a 2008 all-source request for proposals
for up to 2000 MW of baseload. intermediate load and
summer-peak resources for 2012-2016 (CU No. 1380 (9)).
'I think the ecnomic
health of our region--
we're fortunate-is
reasonably healthy.'
Copyright (92009. Energy NewsData Corporation