20030829Acceptance of Filing.pdf

Office of the Secretary
Service Date
August 29, 2003
BEFORE THE IDAHO PUBLIC UTILITIES CO MMISSI 0 N
IN THE MATTER OF A VISTA CORPORATION)
DBA A VISTA UTILITIES' 2003 INTEGRATEDRESOURCE PLAN (IRP).
CASE NO. A VU-03-
ACCEPTANCE OF FILING
On April 30, 2003 , Avista Corporation dba Avista Utilities (Avista; Company) filed
its 2003 Electric Integrated Resource Plan (IRP) with the Idaho Public Utilities Commission
(Commission). The Company s filing complies with the Commission s direction in Order
No. 22299 Case No. U-1500-165, which requires Avista to file a biennial resource management
report (now IRP or Integrated Resource Plan) describing the status of the Company s electric
resource planning.
VISTA 2003 IRP
At this time, A vista states it has no immediate need for additional long-term
resources. The Company does not anticipate a significant deficit in energy, on an annual average
basis, until 2008. The Company does not anticipate a deficit in capacity until 2010. The
Company views this IRP as a resource evaluation process, rather than a specific resource
acquisition plan.
As reflected in a summary of its filing, for this IRP the Company undertook a
significant effort in computer modeling. This effort was initiated with the acquisition of
AURORA, an hourly production-cost model that dispatches resources and develops a set
forward market prices based on numerous conditions. This effort was substantiated through the
development of numerous spreadsheet-based models, and the incorporation of linear
programming (LP) module.
For the first 10 years of the IRP timeframe (2004-2013), the IRP modeling process
selected a combination of combined and simple cycle combustion turbines, wind and coal
resources. During the second 10-year period of the IRP planning horizon period (2014-2023),
the modeling process pointed toward acquisition of coal generation due to improvements and
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technology and its fuel costs relative to other resources. Given no need for immediate resources
the Company will continue to evaluate available options for future generating requirements.
Included in the Company s IRP filing is a 2003 Action Plan which details the studies
and actions the Company will take between now and the 2005 IRP. The Company s 2003
Action Plan contains the following elements:
Public Process
1. Propose changes to WUTC on the IRP /RFP process that will provide
improvements.
2. Continue to manage the free-flow of information with TAC participants.
Demand-Side Management
1. Evaluate the cost-effectiveness and resource potential of conservation voltage
reduction on the Company s system.
2. Acquire electric resources that are at least proportionate to the percentage of DSM
revenues being expended.
3. Field a DSM portfolio that continues to be cost-effective on a societal and utility
basis.
4. Prepare contingency plans for future emergency responses to unexpected fluc-
tuations in wholesale electric markets.
5. Prepare for a re-evaluation of continued participation in the Northwest Energy
Efficiency Alliance (NEEA) upon expiration of the current contract period
(expiring at the end of2004).
6. Convene a T AC meeting in the fall of 2003 to discuss the various alternatives for
integrating DSM into the 2005 IRP process.
Supply-Side Resource Options
1. Pursue a new license for the Spokane River projects by filing a new license
application by July 31 , 2005.
2. Continue to evaluate the effects and costs of integrating wind generation into the
Company s electrical system.
3. Consider and evaluate the potential to add coal facilities to the Company s mix of
existing generating resources.
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4. Determine the feasibility of entering into a medium-term firm power sale during
the Company s surplus years.
5. Initiate a study to determine the optimal reserve margIn for the Company,
including the benefits of additional peaking capacity.
6. Continue to assess the cost-effectiveness of new resource additions.
7. Continue to work with Commission Staff on methods whereby the Company can
acquire resources with development timelines beyond one or two years and
increase the probability for full rate recovery.
Resource Management Issues
1. Analyze the uncertainty of decisions as the Company confronts risks and
opportunities.
2. Continue to assess the electric marketplace and its effect on the Company.
On May 23, 2003 , the Commission issued Notices of Filing and Comment Deadline
in Case No. A VU-03-02. The deadline for filing written comments was July 3, 2003. The
Commission Staff was the only party to file comments.
Commission Staff Analysis and Recommendation
Staff in its analysis addresses the Company IRP load forecast, its use of the
AURORA model, demand-side management (DSM), supply-side resources, and the Company
near term Action Plan. Specific comments of Staff on the Company IRP can be summarized as
follows:
Load Forecast
Staff notes that A vista is proj ecting an overall average growth rate of retail electricity
sales of 3.4% per year over the 20-year planning period. On a monthly planning basis, the
Company expects to encounter energy deficits during some months in all years of the forecast.
The Company may balance its monthly positions through short-term market purchases or sales
exchanges or other resource arrangements. Over the long-term, however, the Company
strategy is to not rely on long-term market purchases to serve future base-load requirements.
Demand-Side Management (DSM)
Staff notes that the Company s 2003 IRP describes A vista s energy savings achieved
through 24 years of DSM programs. Going forward, the IRP forecasts between four and five
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aMW of new DSM savings being achieved annually after 2005. This amounts to over 6% of its
forecasted load growth from 2004 through 2023. A vista funds most of its DSM efforts through
tariff rider surcharges in Idaho and Washington, currently 1.95% and 1.48% of retail revenues
respectively.
According to the Company s IRP, Avista s future DSM activities funded from its
tariff rider are based on three priorities:
1. Satisfaction of least-cost resource requirements and expectations.
2. Overall DSM portfolio that is cost-effective on a societal and utility basis.
3. Return its tariff rider balance to zero in a timely manner.
In addition to DSM tariff rider revenues, A vista receives nearly $400 000 annually for
Conservation and Renewable Discount DSM program benefits from Bonneville Power
Administration. It will continue to receive this funding through 2006.
Supply-Side Resources
As a general guideline, the annual energy position of A vista is used to determine
when the Company needs to acquire additional base-load energy resources. The first significant
annual energy deficit is expected in 2008. This deficit is forecasted to grow to 411 aMW by
2013 and 976 aMW by 2023. Load growth and reduced mid-Columbia generation account for
the significant majority of increasing deficits during this period.
As reflected in the Company s IRP, A vista is in a surplus capacity position through
2009. The Company currently has sufficient capacity resources, due primarily to the relatively
large amount of hydroelectric generation in its resource portfolio. For the most part, future
capacity requirements will be met through the acquisition of new resources, which provide both
capacity and energy.
A vista contends that evaluation of the historical data shows that a superior planning
criteria is the use of a "confidence interval" based on 80% of the monthly variability in load and
hydroelectric generation. This means that for each month there is only a 10% chance that the
combination of load and hydro variability would exceed the planning criteria. In other words
for a given month there is a 10% chance the Company would need to purchase some energy from
the market. On a monthly basis, the 80% confidence level varies between 77 and 268 aMW.
The average of the 80% confidence interval across the 12 months of the year equals 153 aMW.
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This level is similar to critical water planning on an annual basis, but is more precise since it is
based on the chance of exceedance by month.
Staff believes that A vista s decision to employ 80% confidence interval planning is
acceptable. While not substantially different from its former planning criteria, Staff believes that
it does provide better assurance of resource adequacy by considering monthly, rather than
annual, conditions.
A vista s risk analysis considered variability and hydroelectric generation, natural gas
prices and WECC loads. For the first 10 years of the IRP timeframe (2004-2013), the IRP
modeling process selected a total of 411 aMW of new resources as follows:
149 aMW of Combined Cycle Combustion Turbines (CCCT).
25 aMW of wind
197 aMW of coal
40 aMW of Single Cycle Combustion Turbines (SCCT)
This combination of new resources contains planning reserve margins in excess of 12% through
2009.
During the second 10-year period of the IRP planning horizon (2014-2023), the
modeling process recommended acquisition of coal generation due to improvements and
technology and its fuel costs relative to other resources.
Staff is satisfied with the mix of resources selected by the Company. However, Staff
believes it is important to recognize that new resource additions are not needed for several years.
Consequently, the quantity and mix of Avista s resource selections will likely change in future
IRPs as conditions change, fuel prices become more certain, and technology improves.
In analyzing new resource options for this IRP, one notable conclusion made by the
Company, Staff states, is that wind cannot be relied on to meet peak load obligations. Avista
contends that it would most likely need to invest in other capacity resources (e., Simple Cycle
Combustion Turbines) to meet peaking requirements if significant wind resources are required.
Alternatively, it could purchase wind from other sources that already include shaping services.
Given the uncertainty around wind, Avista has elected to limit the preferred strategy to 75 MW
of this resource, or around 25 aMW of energy. The Company proposes to continue the study of
wind to stay well informed on issues, potential declining costs, and any future opportunities.
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In developing its IRP, Avista made a considerable analytical effort to evaluate the
preferred resource strategy (the combination of new resources listed previously) against several
alternative strategies under various scenarios. Staff concurs that the preferred resource strategy
selected by the Company is superior to the other resource strategies considered in the IRP.
Staff notes that it actively participated in each of the public meetings held during the
course of Avista s development of its 2003 IRP. Moreover, Staff states that it was in close
contact with A vista throughout the IRP process and provided its opinions and input. Staff states
that it thoroughly reviewed the draft IRP and provided extensive comments. Staff believes that
the Company satisfactorily addressed its comments in the final IRP.
Staff believes that A vista has done a good job in assessing its load resource
conditions, incorporating demand-side management, evaluating new resource alternatives
analyzing risk, programs and in selecting a reasonable portfolio of new resources.More
importantly, especially since Avista does not need to acquire any new resources for some time
Staff believes that the Company has made impressive strides in developing new tools and
refining analysis techniques that Staff believes will prove valuable in the future. Staff
recommends that A vista s 2003 IRP be accepted and acknowledged.
COMMISSION FINDINGS
The Commission has reviewed the filings of record in Case No. A VU-O3-
including A vista s 2003 Integrated Resource Plan and related comments. We find that the
Company s biennial IRP contains the required information and is in the appropriate format as
directed by the Commission in Order No. 22299. We recognize and commend Avista for its
efforts in preparing its 2003 IRP.
As reflected in the Company s 2003 IRP, A vista has no immediate need for
additional long-term resources, no significant deficit in energy on an annual basis until 2008 and
no deficit in capacity until 2010. The Company views this filing as a resource evaluation process
and not a specific resource acquisition plan. The Commission notes that we regard an Integrated
Resource Plan as a utility planning document that incorporates assumptions and projections as of
a point in time. It is the Company s ongoing planning process that we acknowledge, not the
conclusions or results. We encourage A vista to regard its IRP as an actual planning document.
As such, we expect the IRP to accurately represent the Company s best estimate of future
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changes in loads, resources and contract obligations, and to be indicative of how the Company
through supply and demand side resources intends to meet its statutory obligation to serve its
native load. To such end, we encourage the Company to regard its IRP as a living document and
not allow its planning document to grow stale. This is especially important, we find, in a time of
regulatory change, industry restructuring and market volatility.
CONCLUSIONS OF LAW
The Idaho Public Utilities Commission has jurisdiction over Avista Corporation dba
Avista Utilities, an electric utility, pursuant to Title 61 of the Idaho Code and the Commission
Rules of Procedure, IDAPA 31.01.01.000 et seq.
ACCEPTANCE OF FILING
Based on our review, we find it reasonable to accept and acknowledge Avista s filed
2003 Integrated Resource Plan. Our acceptance of the 2003 IRP should not be interpreted as an
endorsement of any particular element of the Plan, nor does it constitute approval of any resource
acquisition contained in the Plan.
DATED at Boise, Idaho this :2~-r" day of August 2003.
MARSHA H. SMITH, COMMISSIONER
~LO.Je D. Jewell
ission Secretary
Vld/N:AVUEO302 sw2
ACCEPTANCE OF FILING