CONFORMED

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Form 10-K

(Mark One)

     o       TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
                          EXCHANGE ACT OF 1934 FOR THE TRANSITION PERIOD FROM                     

Commission file number 1-3701

AVISTA CORPORATION

Registrant’s telephone number, including area code:           509-489-0500
Web site: http://www.avistacorp.com

Securities registered pursuant to Section 12(b) of the Act:

Securities registered pursuant to Section 12(g) of the Act:

Title of Class
Preferred Stock, Cumulative, Without Par Value

Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days:

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of Registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. [ ]

Indicate by check mark whether the Registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act):

The aggregate market value of the Registrant’s outstanding Common Stock, no par value (the only class of voting stock), held by non-affiliates is $876,757,918 based on the last reported sale price thereof on the consolidated tape on June 30, 2004.

As of February 28, 2005, 48,473,059 shares of Registrant’s Common Stock, no par value (the only class of common stock), were outstanding.

Documents Incorporated By Reference

AVISTA CORPORATION

INDEX

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ACRONYMS AND TERMS
(The following acronyms and terms are found in multiple locations within the document)

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PART I

This Annual Report on Form 10-K contains forward-looking statements, which should be read with the cautionary statements and important factors included in this Annual Report on Form 10-K at “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Forward-Looking Statements.” Forward-looking statements are all statements other than statements of historical fact, including, without limitation, those that are identified by the use of words such as, but not limited to, “will,” “may,” “could,” “should,” “intends,” “plans,” “seeks,” “anticipates,” “estimates,” “expects,” “projects,” “predicts,” and similar expressions. Such statements are subject to a variety of risks and uncertainties and other factors, most of which are beyond the control of Avista Corporation and many of which could have a significant impact on Avista Corporation’s operations, results of operations, financial condition or cash flows and could cause actual results to differ materially from those anticipated in such statements.

Available Information

The Web site address of Avista Corporation (Avista Corp. or the Company) is www.avistacorp.com. Avista Corp. makes available free of charge, on or through its Web site, its annual, quarterly and current reports, and any amendments to those reports, as soon as reasonably practicable after electronically filing such reports with the Securities and Exchange Commission. Information contained on Avista Corp.’s Web site is not part of this report.

Item 1. Business

Company Overview

Avista Corp., incorporated in the State of Washington in 1889, is an energy company engaged in the generation, transmission and distribution of energy as well as other energy-related businesses. As of December 31, 2004, the Company employed approximately 1,485 people in its utility operations and approximately 485 people in its subsidiary businesses. The Company’s corporate headquarters are in Spokane, Washington, center of the Inland Northwest geographic region. Agriculture, mining and lumber were the primary industries in the Inland Northwest for many years; today health care, education, finance, electronic and other manufacturing, tourism and the service sectors are growing in importance.

The Company’s operations are exposed to risks including, but not limited to, the price and supply of purchased power, fuel and natural gas, regulatory allowance of the recovery of power and natural gas costs, operating costs and capital investments, streamflow and weather conditions, the effects of changes in legislative and governmental regulations, changes in regulatory requirements, availability of generation facilities, competition, technology and availability of funding. Also, like other utilities, the Company’s facilities and operations may be exposed to terrorism risks or other malicious acts. In addition, the energy business exposes the Company to the financial, liquidity, credit and commodity price risks associated with wholesale purchases and sales.

The Company has four business segments – Avista Utilities, Energy Marketing and Resource Management, Avista Advantage and Other. Avista Capital, a wholly owned subsidiary of Avista Corp., is the parent company of all of the subsidiary companies in the non-utility business segments. As of December 31, 2004, the Company had common equity investments of $495.8 million and $257.4 million in Avista Utilities and Avista Capital, respectively.

Avista Utilities is an operating division of Avista Corp. comprising the regulated utility operations that started in 1889. Avista Utilities generates, transmits and distributes electricity and distributes natural gas. Avista Utilities also engages in wholesale purchases and sales of electric capacity and energy. Avista Utilities expects to continue to be among the industry leaders in performance, value and service in its electric and natural gas utility businesses. Avista Utilities expects to continue its modest, yet steady, combined growth of electric and natural gas customers of 2 to 3 percent per year, primarily from economic and population growth in its service territory. As part of Avista Utilities’ strategy to focus on its business in the northwestern United States, the Company has entered into an agreement to sell its natural gas distribution properties in South Lake Tahoe, California (see “Note 27 of the Notes to Consolidated Financial Statements”). Avista Utilities has operational strategies to have available resources sufficient to meet its energy requirements under a range of operating and weather conditions. In January 2005, the Company completed its acquisition of Mirant Oregon, LLC’s 50 percent ownership interest in the approximately 280 megawatt (MW) combined cycle natural gas-fired Coyote Springs 2 Generation Project (Coyote Springs 2) (see “Note 28 of the Notes to Consolidated Financial Statements”).

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The Energy Marketing and Resource Management business segment is comprised of Avista Energy, Inc. (Avista Energy) and Avista Power, LLC (Avista Power). Avista Energy, which commenced operations in 1997, is an electricity and natural gas marketing, trading and resource management business, operating primarily in the Western Electricity Coordinating Council (WECC) geographical area, which is comprised of eleven Western states and the provinces of British Columbia and Alberta, Canada. Avista Energy focuses on optimization of combustion turbines and hydroelectric assets owned by other entities, long-term electric supply contracts, natural gas storage, and electric transmission and natural gas transportation arrangements. Avista Energy is also involved in trading electricity and natural gas, including derivative commodity instruments. Avista Energy Canada, Ltd. (Avista Energy Canada) is a wholly owned subsidiary of Avista Energy that provides natural gas services to approximately 250 industrial and commercial customers that represent over 400 sites in British Columbia, Canada. Avista Energy’s marketing, trading and resource management activities are driven by its base of knowledge and experience in the operation of both electric energy and natural gas physical systems in the WECC, as well as its relationship-focused approach with its customers. Avista Power is an investor in certain generation assets, primarily its 49 percent interest in a 270 MW natural gas-fired combined cycle combustion turbine plant in northern Idaho (Lancaster Project), and owns a turbine and related equipment.

Avista Advantage, Inc. (Avista Advantage), which commenced operations in 1998, is a provider of utility bill processing, payment and information services to multi-site customers throughout North America. Its primary product lines include consolidated billing, resource accounting, energy analysis and load profiling services. Avista Advantage remains focused on increasing revenues, controlling operating expenses, continuously enhancing client satisfaction and developing complementary value-added services.

The Other business segment includes Avista Ventures, Inc. (Avista Ventures), Pentzer Corporation (Pentzer), Avista Development, Advanced Manufacturing and Development (AM&D) and certain other operations of Avista Capital. The Company continues to limit its future investment in the Other business segment. Over time as opportunities arise, the Company plans to continue to dispose of assets and phase out operations in the Other business segment.

The Company’s current business segments, and the companies included within them, are illustrated below:

¨ - denotes a business entity; Avista Advantage is also a business segment.

¡ - denotes business segment .

See “Item 6. Selected Financial Data” and “Schedule of Information by Business Segments in the Consolidated Financial Statements” for information with respect to the operating performance of each business segment.

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Avista Utilities

General

Avista Utilities generates, transmits and distributes electricity and distributes natural gas. Retail electric and natural gas customers include residential, commercial and industrial classifications. Avista Utilities also engages in wholesale purchases and sales of electric capacity and energy as part of its resource management and load-serving obligations.

Avista Utilities provides electric distribution and transmission as well as natural gas distribution services in a 26,000 square mile area in eastern Washington and northern Idaho with a population of approximately 855,000. It also provides natural gas distribution service in a combined 4,000 square mile area in northeast and southwest Oregon and the South Lake Tahoe region of California with a population of approximately 500,000. At the end of 2004, Avista Utilities supplied retail electric service to a total of 331,000 customers and retail natural gas service to a total of 305,000 customers across its entire service territory. The Company has entered into an agreement to sell its natural gas distribution properties in the South Lake Tahoe region of California (see “Note 27 of the Notes to Consolidated Financial Statements”), an area with a population of approximately 35,000 and total customers of 18,750 at the end of 2004. See “Item 2. Properties” for further information with respect to Avista Utilities’ electric distribution and transmission assets, as well as natural gas distribution assets.

See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Economic and Load Growth” for information with respect to projected load growth in Avista Utilities service territory.

The Company has experienced a decrease in usage per customer for both electric and natural gas retail customers exclusive of weather related factors. This appears to be due to the conservation efforts of individual customers, improved efficiency of appliances, improved energy efficiency in new construction, as well as customer response to rate increases.

Electric Operations

In addition to providing electric distribution and transmission services, Avista Utilities generates electricity from facilities that it owns or controls. It is Avista Utilities’ strategy to own or to have contracts that provide a sufficient amount of electric resources to meet its retail and wholesale energy requirements under a range of operating conditions. See “Item 2. Properties” for further information with respect to generation properties. In addition to company-owned resources, Avista Utilities has a number of long-term power purchase and exchange contracts that increase its available resources.

Avista Utilities engages in an ongoing process of resource optimization, which involves the pursuit of economic resources to serve load obligations and using existing resources to capture available economic value. Avista Utilities sells and purchases wholesale electric capacity and energy to and from utilities and other entities as part of the process of acquiring resources to serve its retail and wholesale load obligations. These transactions range from a term as short as one hour up to long-term contracts that extend beyond one year. Avista Utilities makes continuing projections of (1) future retail and wholesale loads based on, among other things, forward estimates of factors such as customer usage and weather as well as historical data and contract terms and (2) resource availability based on, among other things, estimates of streamflows, generating unit availability, historic and forward market information and experience. On the basis of these continuing projections, Avista Utilities makes purchases and sales of energy on an annual, quarterly, monthly, daily and hourly basis to match expected resources to expected energy requirements. Resource optimization also includes transactions such as purchasing fuel to run thermal generation and, when economic, selling fuel and substituting electric wholesale market purchases for the operation of Avista Utilities’ own resources, as well as other wholesale transactions to capture the value of available generation and transmission resources. This optimization process includes entering into financial and physical hedging transactions as a means of managing risks.

Participants in the wholesale market include other utilities, federal power marketing agencies, energy marketing and trading companies, and independent power producers. The electric wholesale market continues to change with respect to the number and types of market participants involved, volume of buying and selling activity, price volatility, market liquidity, regulatory initiatives and challenges in regulatory and legal arenas, and credit strength by market participants. See “Industry Restructuring” and “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Competition, – Business Risk and – Risk Management” for more information.

Avista Utilities’ generation assets are interconnected through its transmission system and are operated on a coordinated basis to achieve a high level of load-serving capability and reliability. Avista Utilities offers transmission and ancillary services in eastern Washington, northern Idaho and western Montana. Avista Utilities’ Open Access Same-Time Information System (OASIS) is part of the Joint Transmission Services Information Network that covers much of the

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United States. Transmission revenues, which are included in Other Electric Revenues at “Avista Utilities Operating Statistics – Electric Operations,” totaled $13.9 million, $11.6 million and $11.5 million for 2004, 2003 and 2002, respectively. Avista Utilities is currently in the process of expanding and enhancing its 230 kV transmission system, which Avista Utilities expects to be completed by the end of 2007.

Challenges facing Avista Utilities’ electric operations include, among other things, the timing and approval of the recovery of deferred power costs, changes in the availability of and volatility in the prices of power and fuel, generating unit availability, legislative and governmental regulations, potential tax law changes, customer response to price increases and surcharges, streamflows and weather conditions. See “Industry Restructuring,” “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Business Risk and – Risk Management” and “Note 1 of Notes to Consolidated Financial Statements” for additional information.

Electric Requirements

The peak electric load requirement for 2004 was 2,220 MW (including retail native load of 1,766 MW, long-term wholesale obligations of 129 MW and short-term wholesale obligations of 325 MW). This peak occurred on January 5, 2004 at which time the maximum resource capacity available from Avista Utilities was 2,552 MW. The maximum resource capacity included 1,497 MW of company-owned electric generation, 167 MW of long-term hydroelectric contracts, 352 MW of other long-term wholesale purchases and 536 MW of short-term wholesale purchases. Variations in energy usage by Avista Utilities’ customers occur from year to year, from season to season and hour to hour as a result of varying weather conditions and other energy usage behaviors. This necessitates a continual balancing of loads and resources, and requires both purchases and sales of energy for annual, quarterly, monthly, daily and hourly periods in order to meet electric requirements and to prudently manage and optimize available resources.

Electric Resources

General Avista Utilities has a diverse electric resource mix of hydroelectric projects, thermal generating facilities, and power purchases and exchanges. At the end of 2004, Avista Utilities’ owned facilities had a total net capability of approximately 1,663 MW, of which 59 percent was hydroelectric and 41 percent was thermal. The addition of the remaining interest in Coyote Springs 2 changes Avista Utilities net capability mix to 54 percent hydroelectric and 46 percent thermal. See “Avista Utilities Operating Statistics – Electric Operations” for energy resource statistics.

Hydroelectric Resources Avista Utilities owns and operates six hydroelectric projects on the Spokane River and two hydroelectric projects on the Clark Fork River. See “Item 2. Properties” for detailed information with respect to hydroelectric facilities. Hydroelectric generation is Avista Utilities’ lowest cost source per megawatt-hour (MWh) of electricity and the availability of hydroelectric generation has a significant effect on its total power supply costs. Under normal streamflow and operating conditions, Avista Utilities projects that it would be able to meet approximately one-half of its total average electric requirements (both retail and long-term wholesale) with the combination of its own hydroelectric generation and long-term hydroelectric purchase contracts with certain Public Utility Districts (PUDs) in Washington state. Historically, under normal streamflow conditions, total hydroelectric resources (including resources purchased under long-term hydroelectric contracts) generate 550 average megawatts (aMW) (or 4.8 million MWhs) annually. Hydroelectric resources generated 523 aMW, 492 aMW and 553 aMW during 2004, 2003 and 2002, respectively. The streamflows to company-owned hydroelectric projects were 86 percent, 84 percent and 112 percent of normal in 2004, 2003 and 2002, respectively.

The following table shows Avista Utilities’ hydroelectric generation (in thousands of MWhs) during the years ended December 31:

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Thermal Resources At the end of 2004, Avista Utilities owned a 50 percent interest in Coyote Springs 2 located near Boardman, Oregon. In January 2005, the Company acquired the remaining 50 percent ownership interest in Coyote Springs 2 from Mirant Oregon, LLC. Avista Utilities owns a 15 percent interest in a twin-unit, coal-fired generating facility, the Colstrip 3 & 4 Generating Project (Colstrip) in southeastern Montana. Avista Utilities owns a wood-waste-fired generating facility known as the Kettle Falls Generating Station (Kettle Falls) in northeastern Washington and a two-unit natural gas-fired CT generating facility, located in northeast Spokane (Northeast CT). Avista Utilities leases and operates a two-unit natural gas-fired CT generating facility in northern Idaho (Rathdrum CT). WP Funding LP, an entity that is included in Avista Corp.’s consolidated financial statements and included in the Avista Utilities business segment, owns the Rathdrum CT. In addition, Avista Utilities owns two small generating facilities (Boulder Park and Kettle Falls CT) that were placed into operation in 2002.

Fuel Supply for Thermal Resources Coyote Springs 2, which is operated by Portland General Electric Corporation, is supplied with natural gas under both long-term contracts and spot market purchases, and transportation agreements with unilateral renewal rights are in place.

Colstrip, which is operated by PPL Montana, LLC, is supplied with fuel from adjacent coal reserves under coal supply and transportation agreements in effect through December 2019.

Kettle Falls’ primary fuel is wood-waste generated as a by-product and delivered by trucks from forest industry operations within 100 miles of the plant. Natural gas may be used as an alternate fuel. A combination of long-term contracts and spot purchases have provided, and are expected to meet, future fuel requirements for Kettle Falls.

The Northeast CT, Rathdrum CT, Boulder Park and Kettle Falls CT generating units are primarily used for peaking electric requirements and are also operated when marginal costs are below prevailing wholesale electric prices. These generating facilities have access to natural gas supplies that are adequate to meet their respective operating needs.

The following table shows Avista Utilities’ thermal generation (in thousands of MWhs) during the years ended December 31:

Purchases, Exchanges and Sales Avista Utilities purchases and sells power under various long-term contracts. Avista Utilities also enters into a significant number of short-term purchases and sales with terms of up to one year. See “Electric Operations” for additional information with respect to Avista Utilities’ use of wholesale purchases and sales as part of its resource optimization process.

Under the Public Utility Regulatory Policies Act of 1978 (PURPA), Avista Utilities is required to purchase generation from qualifying facilities, including small hydroelectric and cogeneration projects, at rates approved by the Washington Utilities and Transportation Commission (WUTC) and the Idaho Public Utilities Commission (IPUC). These contracts expire at various times between 2015 and 2022.

See “Avista Utilities Operating Statistics – Electric Operations – Electric Energy Resources” for annual quantities of purchased power, wholesale power sales and power from exchanges in 2004, 2003 and 2002.

Hydroelectric Relicensing

Avista Corp. is a licensee under the Federal Power Act as administered by the FERC, which includes regulation of hydroelectric generation resources. Except for the Little Falls Plant, all of the Company’s hydroelectric plants are regulated by the FERC through project licenses issued for 30-50 year periods. Avista Corp.’s licensed projects are subject to the provisions of Part I of the Federal Power Act. These provisions include payment for headwater benefits, condemnation of licensed projects upon payment of just compensation, and take-over of such projects after the

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expiration of the license upon payment of the lesser of “net investment” or “fair value” of the project, in either case, plus severance damages.

In March 2001, Avista Utilities received a 45-year operating license from the FERC for the Cabinet Gorge Hydroelectric Generating Project (Cabinet Gorge) and the Noxon Rapids Hydroelectric Generating Project (Noxon Rapids). The Clark Fork Settlement Agreement that was entered into during 1999 and incorporated into the FERC license preserved the projects’ economic peaking and load following operations. Also, as part of the Clark Fork Settlement Agreement, Avista Utilities initiated implementation of protection, mitigation and enhancement measures in March 1999. Measures in the agreement address issues related to fisheries, water quality, wildlife, recreation, land use, cultural resources and erosion. Previously deferred hydroelectric relicensing costs, as well as estimated levels of ongoing costs associated with implementation of the Clark Fork Settlement Agreement, were addressed by both the WUTC and IPUC and received recovery through retail rates.

See “Clark Fork Settlement Agreement” in “Note 25 of the Notes to Consolidated Financial Statements” for disclosure of dissolved atmospheric gas levels that exceed state of Idaho and federal water quality standards downstream of the Cabinet Gorge during periods when excess river flows must be diverted over the spillway and the Company’s mitigation plans and efforts.

The Company operates six hydroelectric plants on the Spokane River, and five of these (Long Lake, Nine Mile, Upper Falls, Monroe Street and Post Falls) are under one FERC license and referred to herein as the Spokane River Project. The sixth, Little Falls, is operated under separate Congressional authority and is not licensed by the FERC. The license for the Spokane River Project expires in August 2007; the Company filed a Notice of Intent to Relicense in July 2002. The formal consultation process involving planning and information gathering with stakeholder groups has been underway since that time. The Company’s goal is to develop with the stakeholders a comprehensive and cost-effective settlement agreement to be filed as part of the Company’s license application to the FERC in July 2005. The Company provided a Draft License Application for public comment in February 2005. The Company intends to seek recovery of relicensing costs through the rate making process.

Future Resource Needs

Avista Utilities has operational strategies to have available resources sufficient to meet its energy requirements under a range of operating conditions. These operational strategies consider the amount of energy needed over hourly, daily, monthly and annual durations, which vary widely because of the factors that influence demand. The following is a forecast of Avista Utilities’ average annual energy requirements and resources for 2005, 2006, 2007 and 2008:

Forecasted Electric Energy Requirements and Resources
(aMW)

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(2)

Additional available resources are the Northeast CT and Rathdrum CT, which are generally only used to meet electric load requirements due to either below normal hydroelectric generation or increased loads or outages at other generating facilities, and/or when operating costs are lower than short-term wholesale market prices. The combined maximum capacity of the Northeast CT and Rathdrum CT is 243 MW, with estimated available energy production as indicated for each year.

Natural Gas Operations

General Avista Utilities provides natural gas distribution services to retail customers in parts of eastern Washington, northern Idaho, northeast and southwest Oregon, and the South Lake Tahoe region of California. The Company has entered into an agreement to sell its natural gas distribution properties in the South Lake Tahoe region of California (see “Note 27 of the Notes to Consolidated Financial Statements”). Natural gas commodity costs in excess of, or which fall below, the amount recovered in current retail rates are deferred and recovered or refunded as a pass-through to customers in future periods with applicable regulatory approval through adjustments to rates.

During recent years, natural gas prices have been volatile with a general upward trend. Avista Utilities’ average prices per dekatherm were $6.62, $5.50 and $4.95 in 2004, 2003 and 2002, respectively. This continued upward price trend has caused the recovery period for deferred natural gas costs to lengthen. Market prices for natural gas continue to be competitive compared to alternative fuel sources for residential, commercial and industrial customers. Avista Utilities believes that natural gas should sustain its long-term market advantage over competing energy sources based on the levels of existing reserves and potential natural gas development in the future. Growth has occurred in the natural gas business in recent years due to increased demand for natural gas in new construction, as well as conversions from competing space and water heating energy sources to natural gas.

Challenges facing Avista Utilities’ natural gas operations include, among other things, volatility in the price of natural gas, changes in the availability of natural gas, legislative and governmental regulations, weather conditions and the timing and approval of recovery for increased commodity costs.

Avista Utilities offers natural gas sales and transportation service to large natural gas customers. The majority of Avista Utilities’ large industrial customers purchase natural gas through marketers. For these customers, Avista Utilities provides transportation services for a fee to move the customers’ natural gas through Avista Utilities distribution system from the natural gas transmission pipeline delivery points to the customers’ premises. Several of Avista Utilities’ largest natural gas customers are provided natural gas transportation service under individual contracts. All individual contracts are subject to regulatory review and approval. The total volume transported on behalf of transportation customers for 2004, 2003 and 2002 was 154.4, 153.4 and 174.9 million therms, which represented approximately 31 percent, 31 percent and 34 percent of Avista Utilities’ total system deliveries, respectively.

Natural Gas Supply Avista Utilities does not have any natural gas reserves and purchases all of its natural gas in the wholesale market. Avista Utilities is connected to multiple supply basins in the western United States and western Canada and believes there will be sufficient supplies of natural gas to meet its customers’ needs. However, natural gas prices in the Pacific Northwest are increasingly affected by supply and demand factors in other regions of the United States and Canada because of growth in transcontinental pipeline capacity. Global energy markets also affect natural gas prices. Avista Utilities has capacity delivery rights on seven pipelines and owns natural gas storage facilities. Access to a diverse portfolio of natural gas resources allows Avista Utilities to make natural gas procurement decisions that benefit its natural gas customers. Approximately 25 percent of Avista Utilities’ natural gas supplies are obtained from domestic sources, with the remaining 75 percent from Canadian sources.

Starting in 1999, the Company’s energy marketing, trading and resource management subsidiary, Avista Energy, was responsible for the daily management and optimization of these resources for the requirements of customers in the states of Washington, Idaho and Oregon under an Agency Agreement with Avista Utilities. Under this relationship, Avista Utilities retained ownership of its transportation, storage and long-term contracts and Avista Energy acted as an agent to optimize these resources. In February 2004, the WUTC ordered that the Natural Gas Benchmark Mechanism and related Agency Agreement be terminated for Washington customers and ordered Avista Utilities to file a transition plan to move management of these functions back into Avista Utilities. In April 2004, the WUTC approved Avista Utilities’ transition plan, which provides for the movement of these functions back into Avista Utilities to be completed by March 31, 2005. Effective April 1, 2005, the Company will also be moving these functions from Avista Energy to Avista Utilities for Idaho and Oregon natural gas customers with the expiration of the current agreements. See “Regulatory Issues — Natural Gas Benchmark Mechanism” for additional information.

Natural Gas Storage Avista Utilities owns a one-third interest in the Jackson Prairie Natural Gas Storage Project (Jackson Prairie), an underground natural gas storage field located near Chehalis, Washington. Jackson Prairie has a total peak day deliverability of 8.8 million therms, with a total working natural gas inventory of 213.6 million therms.

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The role of Jackson Prairie in providing flexible natural gas supplies is important to Avista Utilities’ natural gas operations. It enables Avista Utilities to place natural gas into storage when prices are low or to meet minimum natural gas purchasing requirements, as well as to meet high demand periods or to withdraw natural gas from storage when spot prices are high. Avista Energy controls a portion of the capacity at Jackson Prairie for a ten-year period ending in 2009. During 2002, a multi-year project to further increase the capacity at Jackson Prairie commenced. Avista Utilities has contracted to release a total of approximately 37 percent of its Jackson Prairie capacity to two other utilities. One of these contracts requires two-years notice for termination and one contract is renewed on a year-to-year basis.

Regulatory Issues

General Avista Corp., as a regulated public utility, is currently subject to regulation by state utility commissions with respect to prices, accounting, the issuance of securities, and other matters. The retail electric and natural gas operations are subject to the jurisdiction of the WUTC, the IPUC, the Oregon Public Utility Commission (OPUC), the California Public Utilities Commission (CPUC) and the Public Service Commission of the State of Montana (Montana Commission). Approval of the issuance of securities is not required from the CPUC and the Montana Commission. If the Company’s sale of its South Lake Tahoe natural gas distribution properties is completed as planned in 2005, the Company will no longer be subject to the jurisdiction of the CPUC. The Company is also subject to the jurisdiction of the FERC for its wholesale natural gas rates charged for the release of capacity from Jackson Prairie, licensing of hydroelectric generation resources, and for electric transmission service and wholesale electric sales.

In each regulatory jurisdiction, rates for retail electric and natural gas services (other than specially negotiated retail rates for industrial or large commercial customers, which are subject to regulatory review and approval) are determined on a “cost of service” basis and are designed to provide, after recovery of allowable operating expenses, an opportunity to earn a reasonable return on “rate base.” “Rate base” is generally determined by reference to the original cost (net of accumulated depreciation) of utility plant in service, subject to various adjustments for deferred taxes and other items. Over time, rate base is increased by additions to utility plant in service and reduced by depreciation and retirement of utility plant. Rates for wholesale electric and natural gas transmission services are based on the “cost of service” principles and are set forth in tariffs on file with the FERC. See “Note 1 of Notes to Consolidated Financial Statements” for additional information about regulation, depreciation and deferred income taxes. See “Industry Restructuring” for additional information about deregulation, as well as changes with respect to transmission and wholesale electricity markets.

Power Cost Deferrals Avista Utilities defers the recognition in the income statement of certain power supply costs that are in excess of the level currently recovered from retail customers as authorized by the WUTC and the IPUC. A portion of power supply costs are recorded as a deferred charge on the balance sheet for future review and the opportunity for recovery through retail rates. See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Avista Utilities – Regulatory Matters – Power Cost Deferrals and Recovery Mechanisms” and “Note 1 — Power Cost Deferrals and Recovery Mechanisms of the Notes to Consolidated Financial Statements” for detailed information on Avista Utilities power cost deferrals and recovery mechanisms in Washington and Idaho.

General Rate Cases Avista Utilities regularly reviews the need for electric and natural gas rate changes in each state in which it provides service. See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Avista Utilities – Regulatory Matters – General Rate Cases” for information on general rate case activity in 2004 and 2003.

Purchased Gas Adjustment (PGA or Natural Gas Trackers) Under established regulatory practices in each respective state, Avista Utilities is allowed to adjust its natural gas rates periodically (with regulatory approval) to reflect increases or decreases in the cost of natural gas purchased. Differences between actual natural gas costs and the natural gas costs already included in retail rates are deferred and charged or credited to expense when regulators approve inclusion of the cost changes in rates. See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Avista Utilities – Regulatory Matters – Purchased Gas Adjustments” for information on natural gas rate increases to recover increased natural gas costs in 2004 and 2003.

Natural Gas Benchmark Mechanism The IPUC, WUTC and OPUC approved Avista Utilities’ Natural Gas Benchmark Mechanism in 1999. The mechanism eliminated the majority of natural gas procurement operations within Avista Utilities and placed responsibility for natural gas procurement operations with Avista Energy, the Company’s non-regulated subsidiary. The ownership of the natural gas assets remains with Avista Utilities; however, the assets have been managed by Avista Energy through an Agency Agreement. Avista Utilities has continued to manage natural gas procurement for its California operations, which the Company has entered into an agreement to sell (see “Note 27 of the Notes to Consolidated Financial Statements”).

In the first quarter of 2002, the IPUC and the OPUC approved the continuation of the Natural Gas Benchmark Mechanism and related Agency Agreement through March 31, 2005. In February 2004, the WUTC ordered that the

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Natural Gas Benchmark Mechanism and related Agency Agreement be terminated for Washington customers and ordered Avista Utilities to file a transition plan to move management of these functions back into Avista Utilities. In April 2004, the WUTC approved Avista Utilities’ transition plan, which provides for the movement of these functions back into Avista Utilities to be completed by March 31, 2005. Effective April 1, 2005, the Company will also be moving these functions from Avista Energy to Avista Utilities for Idaho and Oregon natural gas customers with the expiration of the current agreements.

Residential Exchange Program The Residential Exchange Program provides access to the benefits of low-cost federal hydroelectricity to residential and small-farm customers of the region’s investor-owned utilities. The Bonneville Power Administration (BPA) administers the Residential Exchange Program in accordance with federal law. Avista Corp. has executed an agreement with the BPA in settlement of each party’s rights and obligations under the Residential Exchange Program for the period October 1, 2001 through September 30, 2011. The benefits that Avista Corp, receives under the agreement with the BPA are passed through directly to residential and small-farm customers via a credit to their monthly electric bills. The current BPA rate period began on October 1, 2001 and continues through September 30, 2006. In 2004, Avista Corp. and other investor-owned utilities entered into amended agreements to provide benefits to customers during the rate period from October 1, 2006 through September 30, 2011.

Numerous parties have filed Petitions for Review in the Ninth Circuit Court of Appeals challenging the agreements between Avista Corp. and the BPA, as well as the BPA’s agreements with other investor-owned utilities. This could possibly affect the amount of benefits paid by the BPA to Avista Corp. that are passed through to residential and small-farm customers. However, since these benefits are passed through to customers as adjustments to electric rates, which must be approved by the WUTC and the IPUC, the outcome of these Petitions for Review is not expected to have a significant effect on Avista Corp.’s financial condition or results of operations.

Industry Restructuring

Federal Level Industry restructuring to open the electric wholesale energy market to competition was initially promoted by federal legislation. The Energy Policy Act of 1992 (Energy Act) expanded the authority of the FERC to issue orders requiring electric utilities to transmit power and energy to or for wholesale purchasers and sellers, and to require electric utilities to enlarge or construct additional transmission capacity for the purpose of providing these services. It also created “exempt wholesale generators,” a class of independent power plant owners that are able to sell generation only at the wholesale level. This permits public utilities and other entities to participate through subsidiaries in the development of independent electric generating plants for sales to wholesale customers.

FERC orders issued in the mid-1990’s require public utilities operating under the Federal Power Act to provide access to their transmission systems to third parties and establish an OASIS to provide transmission customers with information about available transmission capacity and other information by electronic means. FERC orders also require each public utility subject to the rule to functionally separate its transmission and wholesale power merchant functions.

In November 2003, the FERC issued a final rule (FERC Order No. 2004) revising the standards of conduct applicable to jurisdictional electric transmission providers and natural gas pipelines (collectively defined by the rule as “transmission providers”) and their “energy affiliates.” FERC Order No. 2004 replaces the previous natural gas and electricity standards of conduct with new unified standards of conduct applicable to both electric and natural gas transmission providers, and dramatically expands the range of affiliated entities covered by the standards. The standards of conduct are designed to ensure that transmission providers do not provide preferential access to service or information to affiliated entities. FERC Order No. 2004 became effective in February 2004 upon each transmission provider completing its filing with the FERC and posting on its OASIS or its Internet Web site its plan for implementing the revised standards of conduct. By June 2004, each transmission provider was required to comply with the new rule’s requirements and post procedures enabling customers and the FERC to determine whether the transmission provider complies with the new standards. Avista Utilities has complied with the revised standards, which have not had any substantive impact on the operation, maintenance and marketing of its transmission system or Avista Utilities’ ability to provide service to its customers.

The North American Electric Reliability Council (NERC) and the WECC have undertaken initiatives to establish a series of security coordinators to oversee the reliable operation of the regional transmission system. Accordingly, Avista Utilities, in cooperation with other utilities in the Pacific Northwest, established the Pacific Northwest Security Coordinator (PNSC) in the late-1990’s, which oversees daily and short-term operations of the Northwest sub-regional transmission grid and has limited authority to direct certain actions of control area operators in the case of a pending transmission system emergency.

The utility industry experienced a significant blackout in August 2003, when 50 million people lost power in the northeastern United States and eastern Canadian provinces. As a result of this outage, the NERC, in conjunction with the

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FERC, conducted a comprehensive investigation of the outage and issued certain reliability related recommendations. These recommendations addressed compliance with existing national and regional standards and initiatives to prevent or mitigate future blackouts. Utilities in the western United States, including Avista Utilities, had already been following the provisions of approximately half of these NERC recommendations and Avista Utilities already complies with many of the remaining NERC recommendations.

In February 2005, the NERC Board of Trustees approved reliability standards, to become effective April 1, 2005, which have the goal of restating existing standards in a manner that is clear, unambiguous, measurable and enforceable. In February 2005, the FERC issued an order to supplement its April 2004 policy statement, which interprets the term “Good Utility Practice”, as that term is used in the Open Access Transmission Tariff, to include compliance with reliability standards developed by the NERC.

Avista Utilities believes that it has implemented appropriate operating practices and processes with respect to its transmission system, which provide for compliance with the NERC reliability standards. Avista Utilities implemented the majority of these procedures prior to the August 2003 blackout in the northeastern United States. The Company is now reviewing the NERC reliability standards issued in February 2005 for possible amendments to operating policies and practices.

Regional Transmission Organizations FERC Order No. 2000 required all utilities subject to FERC regulation to file a proposal to form a Regional Transmission Organization (RTO), or a description of efforts to participate in an RTO, and any existing obstacles to RTO participation. FERC Order No. 2000 is a follow-up to FERC Orders No. 888 and No. 889 issued in 1996, which required transmission owners to provide non-discriminatory transmission service to third parties.

Avista Corp. is in continuing discussions with utilities and others in the Pacific Northwest to define how such an RTO might work in the region. The Company has participated in negotiations with nine other utilities in the western United States on the possible formation of an RTO, RTO West, a non-profit organization. These utilities and other regional stakeholders have since shifted their approach to developing a regional platform that would incorporate an initial or beginning state of an RTO structure. Interim bylaws governing continuing developmental activities for this non-profit corporation, under the new name Grid West, were adopted on December 9, 2004. The next phase of the development of Grid West would be the establishment of a board of directors, which is currently planned for late-2005.

The Company and two other western utilities also discussed the formation of a for-profit Independent Transmission Company, TransConnect. In March 2005, the companies decided to no longer pursue the formation of TransConnect.

The final proposal for any RTO must be filed with the FERC and approved by the boards of directors of the filing companies and regulators in various states. The Company’s decision to move forward with the formation of any RTO-like structure serving the Pacific Northwest region, as well as the legal, financial and operating implications of such decisions, will ultimately depend on the terms and conditions related to the formation of the entities and conditions established in the regulatory approval processes. The Company cannot predict these implications.

In September 2003, a new organization called Western Interconnection L.L.C. (WI) filed an application with the FERC for certification as an RTO to provide transmission service in the western United States. As part of its application, WI requested that FERC order each jurisdictional utility in the western United States (including Avista Corp.) to provide escrow funding to WI in the amount of $4.0 million per year. In February 2005, WI filed a notice of its intent to withdraw its application with the FERC for certification as an RTO.

Wholesale Power Market Design In April 2003, the FERC issued a White Paper presenting a revised version of proposed wholesale power market rules. The White Paper emphasizes a focus on the formation of RTOs and on ensuring that all independent transmission organizations have sound market rules. The White Paper further indicates that the implementation schedule will vary depending on regional needs and will also allow for regional differences. The White Paper reflects significant concerns raised with respect to the FERC’s initial proposal of a Standard Market Design in July 2002. The FERC’s stated goals with respect to wholesale power markets include: reliable and reasonably priced electric service for all customers; sufficient electric infrastructure; transparent markets with fair rules for all market participants; stability and regulatory certainty for customers, the electric power industry, and investors; technological innovation; and efficient use of the nation’s resources. At this time, the Company cannot predict the ultimate impact any related structural changes in the Pacific Northwest may have on its operations as well as how any such changes may impact Grid West development.

State Level While the Energy Act precludes the FERC from mandating retail wheeling, state regulators and legislators could open service territories to full competition at the retail level. Legislative action at the state level would be required for full retail wheeling and customer choice to occur in Washington and Idaho. For the past several years, the

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legislatures and public utility commissions in Washington and Idaho have conducted a series of hearings and several studies regarding electric industry restructuring. Issues such as unbundling, deregulation, reliability and consumer protection were examined. Impacts on customer service quality and system reliability (generation, transmission and distribution) were considered on a “macro” basis under various restructuring scenarios. Public policy makers in Washington and Idaho continue to examine other states’ experiences with restructuring, while cognizant that the Pacific Northwest generally benefits from electric rates that are among the lowest in the country. There is currently no movement toward deregulation in Washington or Idaho.

Environmental Issues

General The Company is subject to environmental regulation by federal, state and local authorities. The generation, transmission, distribution, service and storage facilities in which Avista Utilities has an ownership interest were designed to comply with all applicable environmental laws. Furthermore, the Company conducts periodic reviews of all its facilities and operations to respond to or to anticipate emerging environmental issues. The Company’s Board of Directors has a committee to oversee environmental issues.

Since December 1991, a number of species of fish in the Northwest, including the Snake River sockeye salmon and fall chinook salmon, the Kootenai River white sturgeon, the upper Columbia River steelhead, the upper Columbia River spring chinook salmon and the bull trout, have been listed as threatened or endangered under the Federal Endangered Species Act. Thus far, measures that were adopted and implemented to save the Snake River sockeye salmon and fall chinook salmon have not directly impacted generation levels at any of Avista Utilities’ hydroelectric facilities. Avista Utilities does, however, purchase power under long-term contracts with PUDs on the Columbia River that are directly impacted by ongoing mitigation measures for salmon and steelhead. The reduction in generation at these projects is relatively minor, resulting in minimal economic impact on Avista Utilities at this time. It is currently not possible to accurately predict the likely economic costs to the Company resulting from future actions. The Company received a 45-year FERC operating license for Cabinet Gorge and Noxon Rapids in March 2001 that incorporates a comprehensive settlement agreement. The restoration of native salmonid fish, particularly bull trout, is a principal focus of the agreement. The result is a collaborative bull trout recovery program with the U.S. Fish and Wildlife Service, Native American tribes and the states of Idaho and Montana on the lower Clark Fork River, consistent with requirements of the FERC license. See “Hydroelectric Relicensing” for further information.

Air Quality The most significant impact on the Company related to the Clean Air Act (CAA) and the 1990 Clear Air Act Amendments (CAAA) pertains to Colstrip, which is a “Phase II” coal-fired plant under the CAAA. Avista Utilities does not expect Colstrip to be required to implement any additional sulfur dioxide (SO2) mitigation in the foreseeable future in order to continue operations. Avista Utilities’ other thermal projects are subject to various CAAA standards. Every five years each of the other thermal projects requires an updated operating permit (known as a Title V permit), which addresses, among other things, the compliance of the plant with the CAAA. The operating permit for the Rathdrum CT was renewed in 2001 (expires 2006) and the operating permit for Kettle Falls was renewed in 2002 (expires 2007). The Northeast CT was issued a Title V permit in February 2004 (expires 2009). Boulder Park does not require a Title V permit based on its limited output and instead has a synthetic minor permit that does not expire. Coyote Springs 2 has a Title V permit that was issued in 2003 (expires in 2008).

In 1999, the Environmental Protection Agency (EPA) initiated enforcement actions against several utilities, asserting that older, coal-fired power plants operated by those utilities have, over the years, been modified in ways that subject them to more stringent requirements under the CAA. The EPA has since issued notices of violation and commenced enforcement activities against other utilities. The future direction of the EPA’s enforcement initiative is presently unclear. Therefore, at this time, Avista Utilities is unable to predict whether such EPA enforcement actions will be brought with respect to Colstrip. However, the EPA regional office that regulates plants in Montana has indicated an intention to issue information requests to all utilities in their jurisdiction and issued such a request to Colstrip in 2003. The owners of Colstrip began the process of responding to this information request. However, the EPA has stayed further production of Colstrip documents pending discussion among the Colstrip owners and the EPA. Avista Utilities cannot presently predict what action, if any, the EPA might take in this matter.

Water Quality See “Clark Fork Settlement Agreement” in “Note 25 of the Notes to Consolidated Financial Statements” for disclosure of dissolved atmospheric gas levels that exceed state of Idaho and federal water quality standards downstream of the Cabinet Gorge during periods when excess river flows must be diverted over the spillway and the Company’s mitigation plans and efforts.

Other Environmental Issues See “Colstrip Generating Project Complaint,” “Environmental Protection Agency Administrative Compliance Order,” “Hamilton Street Bridge,” “Spokane River” and “Other Contingencies” in “Note 25 of the Notes to Consolidated Financial Statements” for additional information with respect to environmental issues.

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Energy Marketing and Resource Management

The Energy Marketing and Resource Management business segment includes Avista Energy and Avista Power, both subsidiaries of Avista Capital.

Avista Energy

Avista Energy is an electricity and natural gas marketing, trading and resource management business, operating primarily within the WECC. Avista Energy’s headquarters are in Spokane, Washington, and it also has an office in Vancouver, British Columbia, Canada. Avista Energy focuses on optimization of combustion turbines and hydroelectric assets owned by other entities, long-term electric supply contracts, natural gas storage, and electric transmission and natural gas transportation arrangements. Avista Energy is also involved in trading electricity and natural gas, including derivative commodity instruments. Avista Energy Canada is a wholly owned subsidiary of Avista Energy that provides natural gas services to approximately 250 industrial and commercial customers that represent over 400 sites in British Columbia, Canada. Avista Energy’s marketing, trading and resource management activities are driven by its base of knowledge and experience in the operation of both electric energy and natural gas physical systems in the WECC, as well as its relationship-focused approach with its customers. Avista Energy’s earnings are primarily derived from the following activities:

•	Marketing and managing the output and availability of combustion turbines and hydroelectric assets owned by other entities.
•	Capturing price differences between commodities (spark spread) by converting natural gas into electricity through the power generation process.
•	Purchasing and storing natural gas for later sales to seek gains from seasonal price variations and demand peaks.
•	Transmitting electricity and transporting natural gas between locations, including moving energy from lower priced/demand regions to higher priced/demand markets and hub locations within the WECC.
•	Taking speculative positions on future price movements within established risk management policies.

Avista Energy trades electricity and natural gas, along with derivative commodity instruments including futures, options, swaps and other contractual arrangements. Most transactions are conducted on an “over-the-counter” basis. Avista Energy’s trading operations are affected by, among other things, volatility of prices within the electric energy and natural gas markets, the demand for and availability of energy, changing regulation of the electric and natural gas industries, the creditworthiness of counterparties and variations in liquidity in energy markets. See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Business Risk and — Risk Management” for further information.

The following table provides operating statistics for Avista Energy for the years ended December 31:

In September 1999, Avista Energy began managing Avista Utilities’ natural gas storage assets, transportation contracts and natural gas purchasing operations. Under an Agency Agreement, Avista Energy served as agent for Avista Utilities, managing its pipeline transportation rights and natural gas storage assets, as well as purchasing natural gas for Avista Utilities’ retail customers. The assets continued to be owned by Avista Utilities; however, they were fully integrated operationally into Avista Energy’s portfolio. In February 2004, the WUTC ordered that the Natural Gas Benchmark Mechanism and related Agency Agreement be terminated for Washington customers and ordered Avista Utilities to file a transition plan to move management of these functions back into Avista Utilities. In April 2004, the WUTC approved Avista Utilities’ transition plan, which provides for the movement of these functions back into Avista Utilities to be completed by March 31, 2005. Effective April 1, 2005, the Company will also be moving these functions from Avista Energy to Avista Utilities for Idaho and Oregon natural gas customers with the expiration of the current agreements.

Avista Energy is subject to the various risks inherent in commodity trading including, particularly, market risk, liquidity risk, commodity price risk and credit risk, as well as possible risks resulting from the imposition of market controls by federal and state regulatory agencies. See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations — Business Risks and — Risk Management,” and “Notes 1, 2, 7 and 8 of Notes to

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Consolidated Financial Statements” for additional information regarding the market and credit risks inherent in the energy trading business, Avista Energy’s risk management policies and procedures, accounting practices, and positions held by Avista Energy as of December 31, 2004.

Avista Power

Avista Power is an investor in certain generation assets, primarily its 49 percent ownership interest in the Lancaster Project, as well as a turbine and related equipment. The Lancaster Project capacity is contracted to Avista Energy through 2026 through a power purchase agreement. The power purchase agreement gives Avista Energy the right to purchase natural gas for generation, and convert to electricity for a fixed fee. Avista Power is not seeking additional investment opportunities.

Avista Advantage

Avista Advantage is a provider of utility bill processing, payment and information services to multi-site customers throughout North America. Avista Advantage’s solutions are designed to provide multi-site companies with critical and easy-to-access information that enables them to proactively manage and reduce their facility-related expenses.

Avista Advantage analyzes and presents consolidated bills on-line, and pays utility and other facility-related expenses for multi-site customers. Information gathered from invoices, providers and other customer-specific data allows Avista Advantage to provide its customers with in-depth analytical support, real-time reporting and consulting services with regard to facility-related energy, waste, repair and maintenance, and telecom expenses.

Avista Advantage has secured five patents on its two critical business systems: the Facility IQä system, which provides operational information drawn from facility bills, and the AviTrackä database, which processes and reports on information gathered from service providers to ensure customers are receiving the most effective services at the proper price. Avista Advantage is not aware of any claimed or threatened infringement on any of its patents issued to date and will continue to expand and protect its existing patents, as well as file additional patent applications for new products, services and process enhancements.

As of December 31, 2004, Avista Advantage serviced 323 customers, having 141,442 billed sites throughout North America. This is an increase from 292 customers and 109,583 billed sites as of December 31, 2003. As of December 31, 2002, Avista Advantage serviced 247 customers and 98,251 billed sites. During 2004, Avista Advantage processed $7.6 billion of bills, an increase from $6.4 billion in 2003 and $4.9 billion in 2002.

Other

The Other business segment includes Avista Ventures, Pentzer, Avista Development and certain other operations of Avista Capital. Included in this business segment is AM&D doing business as METALfx, a subsidiary of Avista Ventures that performs custom sheet metal manufacturing of electronic enclosures, parts and systems for the computer, telecom and medical industries. AM&D also provides complete fabrication and turnkey assembly for arcade games, kiosks, store fixtures and displays. Other significant investments in this segment include commercial office buildings, investments in low income housing and venture capital partnerships, the remaining investment in a previous fuel cell subsidiary of the Company, and notes receivable from the sale of property and investments. Over time as opportunities arise, the Company plans to continue to dispose of assets and phase out operations in the Other business segment.

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Item 2. Properties

Avista Utilities

Avista Utilities’ electric properties, located in the states of Washington, Idaho, Montana and Oregon, include the following:

Generation Properties (1)

Electric Distribution and Transmission Plant

Avista Utilities operates approximately 17,000 miles of primary and secondary electric distribution lines. Avista Utilities has an electric transmission system of approximately 623 miles of 230 kV line and 1,537 miles of 115 kV line. Avista Utilities also owns an 11 percent interest (representing 465 MW capacity) in 495 miles of a 500 kV line between Colstrip, Montana and Townsend, Montana. The transmission and distribution system also includes numerous substations with transformers, switches, monitoring and metering devices, and other equipment related to its operation.

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The 230 kV lines are used to transmit power from Noxon Rapids and Cabinet Gorge to major load centers in Avista Utilities’ service area, as well as to transfer power between points of interconnection with adjoining electric transmission systems. These lines interconnect at various locations with the BPA, PacifiCorp, NorthWestern Energy and Idaho Power Company. These interconnections serve as points of delivery for power from generating facilities outside of the Company’s distribution territory, including the Colstrip generating station, Coyote Springs 2, and to integrate Mid-Columbia hydroelectric generating facilities, as well as for the interchange of power with entities within and outside the Pacific Northwest. Avista Utilities is currently in the process of expanding and enhancing its 230 kV transmission system, which Avista Utilities expects to be completed by the end of 2007.

The 115 kV lines provide for transmission of energy and the integration of the Spokane River hydroelectric and Kettle Falls wood-waste generating stations with service-area load centers. These lines interconnect with the BPA, Grant County PUD, Puget Sound Energy, the South Columbia Basin Irrigation District, Chelan County PUD, PacifiCorp and NorthWestern Energy. Both the 115 kV and 230kV interconnections with the BPA are used to exchange energy with the BPA to facilitate the General Transfer Agreement (GTA). The GTA allows the Company to serve its native load from the BPA’s transmission system and allows the BPA to serve their customers from the Company’s system.

Natural Gas Plant

Avista Utilities has natural gas distribution mains of approximately 2,660 miles in Washington, 1,550 miles in Idaho, 1,790 miles in Oregon and 230 miles in California. The natural gas distribution system includes numerous regulator stations, service distribution lines, monitoring and metering devices, and other equipment related to its operation.

Avista Utilities owns a one-third interest in Jackson Prairie, which has a total peak day deliverability of 8.8 million therms, with a total working natural gas inventory of 213.6 million therms. Avista Utilities has contracted to release a total of approximately 37 percent of its Jackson Prairie capacity to two other utilities. One of these contracts requires two-years notice for termination and one contract is renewed on a year-to-year basis.

Item 3. Legal Proceedings

See “Note 25 of Notes to Consolidated Financial Statements” for information with respect to legal proceedings.

Item 4. Submission of Matters to a Vote of Security Holders

None.

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PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Outstanding shares of common stock are listed on the New York and Pacific Stock Exchanges. As of February 28, 2005, there were approximately 15,219 registered shareholders of the Company’s no par value common stock.

The Board of Directors considers the level of dividends on the Company’s common stock on a regular basis, taking into account numerous factors, including, without limitation, the Company’s results of operations, cash flows and financial condition, as well as the success of the Company’s strategies and general economic and competitive conditions. The Company’s net income available for dividends is derived primarily from the operations of Avista Utilities and Avista Energy.

On February 11, 2005, the Board of Directors declared a quarterly dividend of $0.135 per common share payable on March 15, 2005 to shareholders of record on February 25, 2005. This is an increase of $0.005 per common share over the previous quarterly dividend declared in November 2004 and the third such increase authorized by the Board of Directors in the last 18 months.

Covenants under the Company’s 9.75 percent Senior Notes that mature in 2008 limit the Company’s ability to increase its common stock cash dividend to no more than 5 percent over the previous quarter.

Avista Energy holds a significant portion of cash and cash equivalents reflected on the Consolidated Balance Sheet. Covenants in Avista Energy’s credit agreement, certain counterparty agreements and current market liquidity conditions result in Avista Energy maintaining certain levels of cash and therefore effectively limiting the amount of cash dividends that are available for distribution to Avista Capital and ultimately to Avista Corp. During 2004, Avista Energy paid $2.5 million in dividends to Avista Capital. In March 2005, Avista Energy paid $10.0 million in dividends to Avista Capital.

For additional information, refer to “Notes 1, 22, 23 and 24 of Notes to Consolidated Financial Statements.” For high and low stock price information, refer to “Note 29 of Notes to Consolidated Financial Statements.”

For information with respect to securities authorized for issuance under equity compensation plans see “Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.”

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Item 6. Selected Financial Data
(in thousands, except per share data and ratios)

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Forward-Looking Statements

Avista Corporation (Avista Corp. or the Company) from time to time makes forward-looking statements such as statements regarding future financial performance, capital expenditures, dividends, capital structure and other financial items, including the underlying assumptions (many of which are based, in turn, upon further assumptions), as well as strategic goals and objectives and plans for future operations. Such statements are made both in Avista Corp.’s reports filed under the Securities Exchange Act of 1934, as amended (including this Annual Report on Form 10-K), and elsewhere. Forward-looking statements are all statements other than statements of historical fact, including, without limitation, those that are identified by the use of words such as, but not limited to, “will,” “may,” “could,” “should,” “intends,” “plans,” “seeks,” “anticipates,” “estimates,” “expects,” “projects,” “predicts,” and similar expressions.

All forward-looking statements (including those made in this Annual Report) are subject to a variety of risks and uncertainties and other factors, most of which are beyond the control of Avista Corp. and many of which could have a significant impact on Avista Corp.’s operations, results of operations, financial condition or cash flows and could cause actual results to differ materially from those anticipated in such statements. Such risks, uncertainties and other factors include, among others:

•	changes in the utility regulatory environment in the individual states and provinces in which the Company operates as well as the United States and Canada in general, which can impact allowed rates of return, financings, or industry and rate structures;
•	the impact of regulatory decisions including Federal Energy Regulatory Commission (FERC) price controls, and including possible retroactive price caps and resulting refunds;
•	the potential effects of any legislation or administrative rulemaking passed into law;
•	the impact from the potential formation of a Regional Transmission Organization and/or an Independent Transmission Company;
•	the impact from the potential implementation of the FERC’s proposed wholesale power market rules;
•	the ability to relicense the Spokane River Project at a cost-effective level with reasonable terms and conditions;
•	volatility and illiquidity in wholesale energy markets, including the availability and prices of purchased energy and demand for energy sales;
•	changes in wholesale energy prices that can affect, among other things, the market value of derivative assets and liabilities and unrealized gains and losses, as well as cash requirements to purchase electricity and natural gas for retail customers;
•	changes in global energy markets that can affect, among other things, the price of natural gas purchased for retail customers and purchased as fuel for electric generation;
•	wholesale and retail competition (including, but not limited to, electric retail wheeling and transmission costs);
•	future streamflow conditions that affect the availability of hydroelectric resources;
•	unplanned outages at any Company-owned generating facilities;
•	unanticipated delays or changes in construction costs with respect to present or prospective facilities;
•	changes in weather conditions that can affect customer demand, result in natural disasters and/or disrupt energy delivery;
•	changes in industrial, commercial and residential growth and demographic patterns in the Company’s service territory;
•	the loss of significant customers and/or suppliers;
•	failure to deliver on the part of any parties from which the Company purchases and/or sells capacity or energy;
•	changes in the creditworthiness of customers and energy trading counterparties;
•	the Company’s ability to obtain financing through the issuance of debt and/or equity securities, which can be affected by various factors including the Company’s credit ratings, interest rate fluctuations and other capital market conditions;
•	the impact of any potential change in the Company’s credit ratings, including the effect on Avista Energy’s credit facility;
•	changes in future economic conditions in the Company’s service territory and the United States in general, including inflation or deflation and monetary policy;
•	changes in rapidly advancing technologies, possibly making some of the current technology quickly obsolete;
•	the potential for future terrorist attacks, particularly with respect to utility plant assets;
•	changes in tax rates and/or policies;

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•	changes in, and compliance with, environmental and endangered species laws, regulations, decisions and policies, including present and potential environmental remediation costs;
•	the outcome of legal and regulatory proceedings concerning the Company or affecting directly or indirectly its operations, including the potential disallowance of previously deferred costs;
•	employee issues, including changes in collective bargaining unit agreements, strikes, work stoppages or the loss of key executives, as well as the ability to recruit and retain employees;
•	changes in actuarial assumptions and the return on assets with respect to the Company’s pension plan, which can impact future funding obligations, costs and pension plan liabilities;
•	increasing health care costs and the resulting effect on health insurance premiums paid for employees and on the obligation to provide postretirement health care benefits; and
•	increasing costs of insurance, changes in coverage terms and the ability to obtain insurance.

The Company’s expectations, beliefs and projections are expressed in good faith and are believed by the Company to have a reasonable basis including, without limitation, management’s examination of historical operating trends, data contained in the Company’s records and other data available from third parties. However, there can be no assurance that the Company’s expectations, beliefs or projections will be achieved or accomplished. Furthermore, any forward-looking statement speaks only as of the date on which such statement is made. The Company undertakes no obligation to update any forward-looking statement or statements to reflect events or circumstances that occur after the date on which such statement is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time, and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the Company’s business or the extent to which any such factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statement.

The following discussion and analysis is provided for the consolidated financial condition and results of operations of Avista Corp., including its subsidiaries. This discussion focuses on significant factors concerning the Company’s financial condition and results of operations and should be read along with the consolidated financial statements.

Avista Corp. Business Segments

Avista Corp. is an energy company engaged in the generation, transmission and distribution of energy as well as other energy-related businesses. The Company has four business segments — Avista Utilities, Energy Marketing and Resource Management, Avista Advantage and Other. Avista Utilities is an operating division of Avista Corp. comprising the regulated utility operations. Avista Utilities generates, transmits and distributes electricity and distributes natural gas. Avista Capital, a wholly owned subsidiary of Avista Corp., is the parent company of all of the subsidiary companies in the non-utility business segments. As of December 31, 2004, the Company had common equity investments of $495.8 million and $257.4 million in Avista Utilities and Avista Capital, respectively.

The Energy Marketing and Resource Management business segment is comprised of Avista Energy, Inc. (Avista Energy) and Avista Power, LLC (Avista Power). Avista Energy is an electricity and natural gas marketing, trading and resource management business, operating primarily in the Western Electricity Coordinating Council (WECC) geographical area, which is comprised of eleven Western states and the provinces of British Columbia and Alberta, Canada. Avista Power is an investor in certain generation assets, primarily its 49 percent interest in a 270 MW natural gas-fired combined cycle combustion turbine plant in northern Idaho (Lancaster Project).

Avista Advantage, Inc. (Avista Advantage) is a provider of utility bill processing, payment and information services to multi-site customers throughout North America. Its primary product lines include consolidated billing, resource accounting, energy analysis and load profiling services.

The Other business segment includes Avista Ventures, Inc. (Avista Ventures), Pentzer Corporation (Pentzer), Avista Development and certain other operations of Avista Capital. Included in this business segment is Advanced Manufacturing and Development (AM&D) doing business as METALfx, a subsidiary of Avista Ventures that performs custom sheet metal manufacturing of electronic enclosures, parts and systems for the computer, telecom and medical industries. AM&D also provides complete fabrication and turnkey assembly for arcade games, kiosks, store fixtures and displays. Other significant investments in this segment include commercial office buildings, investments in low income housing and venture capital partnerships, the remaining investment in a previous fuel cell subsidiary of the Company, and notes receivable from the sale of property and investments.

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Executive Level Summary

Avista Corp.’s net income and operating cash flows are derived primarily from Avista Utilities and Avista Energy (included in the Energy Marketing and Resource Management segment). Avista Corp. intends to continue to focus on improving earnings and operating cash flows, controlling costs and reducing debt while working to restore an investment grade credit rating.

Avista Utilities expects to continue to be among the industry leaders in performance, value and service in its electric and natural gas utility businesses. Avista Utilities expects to continue its modest, yet steady, combined growth of electric and natural gas customers of 2 to 3 percent per year primarily from economic and population growth in its service territory. As part of Avista Utilities’ strategy to focus on its business in the northwestern United States, the Company has entered into an agreement to sell its natural gas distribution properties in South Lake Tahoe, California (see “Note 27 of the Notes to Consolidated Financial Statements”).

It is Avista Utilities’ strategy to own or to have contracts that provide a sufficient amount of electric resources to meet its retail and wholesale energy requirements under a range of operating conditions. Available resources and the costs of those resources are significantly affected by Avista Utilities’ hydroelectric generation, which was 95 percent of normal in 2004. Based on forecasts as of March 1, 2005, Avista Utilities expects hydroelectric generation will be approximately 84 percent of normal in 2005 assuming normal precipitation for the remainder of the year. This expectation may change based upon precipitation, temperatures and other variables. The earnings impact of below normal hydroelectric generation is mitigated through power cost deferral and recovery mechanisms in Washington and Idaho. The expected reduction in hydroelectric generation is estimated to have a negative effect on operating cash flows of approximately $25 million from the amount originally forecasted, with approximately $2.5 million impacting pre-tax earnings. Avista Utilities believes that it has adequate liquidity through cash flows generated from operations and funds available under its committed line of credit to meet increased cash requirements for purchased power or fuel as a result of reduced hydroelectric generation.

Customer loads and resulting revenues are also significantly affected by weather, which causes changes in energy usage from season to season and from month to month within a season. Changes in wholesale electric prices and the amount of hydroelectric generation available to Avista Utilities also make quarter-to-quarter comparisons difficult. Avista Utilities normally experiences its highest retail energy sales during the heating season in the first and fourth quarters of the year. Although there were differences with respect to quarter-to-quarter comparisons, total heating and cooling degree days at Spokane, Washington for both 2004 and 2003 were similar with both warmer than normal heating and cooling seasons. As such, electric and natural gas loads, revenues and net income were not significantly affected by weather when comparing 2004 to 2003 results.

As is the case with most regulated entities, Avista Utilities generally has ongoing regulatory proceedings. Avista Utilities continues to make progress with respect to resolving its regulatory matters; however, certain issues remain unresolved. Avista Utilities received the following general rate increases in 2004 and 2003: (1) Oregon natural gas in September 2003; (2) Idaho electric and natural gas in September 2004; and (3) Washington natural gas in November 2004. These general rate increases have increased revenues and net income for 2004 as compared to 2003 and should result in increased net income in 2005 as compared to 2004. Avista Utilities will continue to file for rate adjustments to provide recovery of its costs and to more closely align earned returns with those allowed by regulatory agencies in each jurisdiction.

Avista Utilities’ net income decreased in 2004 as compared to 2003 primarily due to write-offs related to the Idaho general electric rate case, which was partially offset by the general rate increases described above. The Company expects Avista Utilities’ net income for 2005 to increase as compared to 2004 primarily due to the continued effect of general rate increases, subject to the influence of weather.

The Company has management succession plans that work towards ensuring that executive officer and key management positions can be appropriately filled as vacancies occur. The Company has taken similar steps in key technical and craft areas.

Avista Energy focuses on optimization of combustion turbines and hydroelectric assets owned by other entities, long-term electric supply contracts, natural gas storage, and electric transmission and natural gas transportation arrangements. Avista Energy is also involved in trading electricity and natural gas, including derivative commodity instruments. Avista Energy Canada, Ltd. (Avista Energy Canada) is a wholly owned subsidiary of Avista Energy that provides natural gas services to approximately 250 industrial and commercial customers that represent over 400 sites in British Columbia, Canada. In addition to earnings and resulting cash flows from settled or realized

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transactions, Avista Energy records unrealized or mark-to-market adjustments for the change in the value of derivative commodity instruments. Avista Energy’s marketing, trading and resource management activities are driven by its base of knowledge and experience in the operation of both electric energy and natural gas physical systems in the WECC, as well as its relationship-focused approach with its customers.

Avista Energy is subject to certain regulatory proceedings that remain unresolved; however, Avista Energy believes that it has adequate reserves established for refunds that may be ordered. The wholesale power markets in which Avista Energy operates continue to change with respect to market participants involved, level of activity, volatility in market prices, liquidity, regulatory imposed price caps and counterparty credit issues.

Net income for Avista Energy and the Energy Marketing Resource Management segment decreased for 2004 as compared to 2003. This was primarily due to the positive effects in 2003 of accounting for energy trading activities under Statement of Financial Accounting Standards (SFAS) No. 133, “Accounting for Derivative Instruments and Hedging Activities” and the settlement of positions with certain Enron Corporation (Enron) affiliates. Both 2004 and 2003 net income for the Energy Marketing and Resource Management segment were decreased by impairment charges for a turbine and related equipment owned by Avista Power. The Company does not expect these factors to occur in 2005.

Avista Advantage remains focused on increasing revenues, controlling operating expenses, continuously enhancing client satisfaction and developing complementary value-added services. The Company expects that net income for Avista Advantage for 2005 will increase as compared to 2004 based on improving revenues and stabilized operating expenses from processing efficiencies.

Over time as opportunities arise, the Company plans to continue to dispose of assets and phase out operations in the Other business segment. The Company expects the net loss in the Other business segment to be less for fiscal year 2005 as compared to 2004 due to decreased losses from asset impairments and write-offs.

During 2005, the Company expects cash flows from operations and Avista Corp.’s five-year $350.0 million committed line of credit to provide adequate resources to fund capital expenditures, maturing long-term debt (excluding $54.6 million of maturing WP Funding LP debt) and other contractual commitments. However, if market conditions warrant such actions, the Company may issue securities to fund these obligations, refinance existing debt and repurchase long-term debt scheduled to mature in future years to reduce its overall debt service costs, as well as to manage the risk associated with future changes in interest rates on debt maturities scheduled for 2007 and 2008.

Avista Utilities — Electric Resources

As of December 31, 2004, Avista Utilities’ facilities had a total net capability of approximately 1,663 MW, of which 59 percent was hydroelectric and 41 percent was thermal. The addition of the remaining interest in Coyote Springs 2 changes Avista Utilities net capability mix to 54 percent hydroelectric and 46 percent thermal. In addition to company owned resources, Avista Utilities has a number of long-term power purchase and exchange contracts that increase its available resources. See “Note 7 of the Notes to Consolidated Financial Statements” for information with respect to Avista Utilities’ resource optimization process.

Avista Utilities — Regulatory Matters

General Rate Cases

Avista Utilities regularly reviews the need for electric and natural gas rate changes in each state in which it provides service. Avista Utilities plans to file an electric general rate case in Washington during March or April of 2005.

In January 2005, the Washington Utilities and Transportation Commission (WUTC) issued its final order with respect to a natural gas general rate case filed by Avista Utilities in Washington. The final order authorized, among other things, an increase in natural gas rates of 3.9 percent, which is designed to increase annual revenues by $5.4 million. The final order authorized an overall rate of return of 8.68 percent. The natural gas rate increase was implemented in November 2004 resulting from a settlement agreement reached among the Company, the staff of the WUTC and the Northwest Industrial Gas Users in October 2004. The increase was approved by the WUTC in November 2004 on a “subject to refund” basis to allow the non-settling parties the opportunity to further review the case.

In October 2004, the Idaho Public Utilities Commission (IPUC) issued its final order with respect to electric and natural gas general rate cases filed by Avista Utilities in Idaho. The final order authorized, among other things,

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Avista Utilities to increase its electric base rates by 16.9 percent, which is designed to increase annual revenues by $24.7 million, and increase its natural gas base rates by 6.4 percent, which is designed to increase annual revenues by $3.3 million. Due to a decrease implemented concurrently in Avista Utilities’ power cost adjustment (PCA) surcharge and certain other minor adjustments, the net increase in electric rates for Idaho customers was 1.9 percent above rates in effect at that time. The decrease in the PCA surcharge reduces the rate increase impact to customers and extends the period for recovery of deferred power costs. The final order authorized an overall rate of return of 9.25 percent and a return on common equity of 10.4 percent based on an authorized equity level of approximately 43 percent. The final order required Avista Utilities to write off a total of $14.4 million. The write-off included the disallowance of $12.0 million of certain deferred power costs, including associated interest, related to natural gas contracts entered into by Avista Utilities to provide fuel for its generating facilities and the disallowance of $2.4 million (net of $0.3 million of accumulated depreciation) of certain capitalized utility plant costs. Avista Utilities believes that such costs were prudently incurred and reasonable given the market conditions at the time. Avista Utilities filed a petition for reconsideration of certain portions of the final order including the disallowance of $4.8 million of certain deferred power costs and $2.6 million of certain utility plant costs. In November 2004, the IPUC denied the petition for reconsideration with the exception of certain minor technical corrections, which reduced the total write-off by $0.3 million. As such, the matter is closed.

In September 2003, the Oregon Public Utility Commission (OPUC) approved a natural gas general rate increase for Oregon customers, which was designed to increase annual revenues by $6.3 million effective October 1, 2003. The order authorized, among other things, an overall rate of return of 8.88 percent and a return on equity of 10.25 percent based on an authorized equity level of approximately 48 percent.

Other Regulatory Filings

In January 2005, Avista Utilities filed a request with the IPUC to include the acquisition of the remaining 50 percent of Coyote Springs 2 in base electric rates. Avista Utilities requested a 1.9 percent increase in base electric rates, which is designed to increase annual revenues by $3.2 million. At the same time, Avista Utilities requested that the IPUC approve a 1.9 percent reduction in the company’s current PCA rate surcharge. These two requests together would result in no overall change to customers’ existing rates. On March 1, 2005, the IPUC Staff filed comments in support of Avista Utilities’ request and one other party filed comments opposing Avista Utilities’ request. Avista Utilities plans to file reply comments by March 15, 2005. In Washington, the acquisition of Coyote Springs 2 will be addressed in the expected general rate case filing.

Avista Utilities is also involved in regulatory proceedings before the California Public Utilities Commission (CPUC) with respect to the sale of its South Lake Tahoe, California natural gas distribution properties. See “Note 27 of the Notes to Consolidated Financial Statements.”

Power Cost Deferrals and Recovery Mechanisms

Avista Utilities defers the recognition in the income statement of certain power supply costs that are in excess of the level currently recovered from retail customers as authorized by the WUTC and the IPUC. A portion of power supply costs are recorded as a deferred charge on the Consolidated Balance Sheets for future review and the opportunity for recovery through retail rates.

In Washington, the Energy Recovery Mechanism (ERM) allows Avista Utilities to increase or decrease electric rates periodically with WUTC approval to reflect changes in power supply costs. The ERM provides for Avista Utilities to incur the cost of, or receive the benefit from, the first $9.0 million in annual power supply costs above or below the amount included in base retail rates. Under the ERM, 90 percent of the power supply costs exceeding or below the initial $9.0 million are deferred for future surcharge or rebate to Avista Utilities’ customers. The remaining 10 percent of power supply costs are an expense of, or benefit to, the Company. The Company expensed the initial $9.0 million of power supply costs above the amount included in base retail rates during 2004, 2003 and 2002 ($4.5 million due to mid-year implementation on July 1, 2002) and expects to expense the initial $9.0 million during 2005.

Under the ERM, Avista Utilities agreed to make an annual filing on or before April 1st of each year to provide the opportunity for the WUTC and other interested parties to review the prudence of and audit the ERM deferred power cost transactions for the prior calendar year. The ERM provides for a 90-day review period for the filing; however, the period may be extended by agreement of the parties or by WUTC order. In August 2004, the WUTC issued an order, which approved the recovery of $22.8 million of deferred power costs incurred in 2003. On or before December 31, 2006, Avista Utilities will make a filing with the WUTC that will allow interested parties the opportunity to review and propose changes to the ERM.

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Avista Utilities has a PCA mechanism in Idaho that allows it to modify electric rates periodically with IPUC approval. Under the PCA mechanism, Avista Utilities defers 90 percent of the difference between certain actual net power supply expenses and the authorized level of net power supply expense approved in the last Idaho general rate case. As disclosed at “General Rate Cases” above, the IPUC issued its final order with respect to general electric and natural gas rate cases filed by Avista Utilities in Idaho. The final order required Avista Utilities to write off a total of $12.0 million of certain deferred power costs, including associated interest, related to natural gas contracts entered into by Avista Utilities to provide fuel for its generating facilities. The IPUC authorized the recovery of the remaining deferred power costs over a two-year period through a PCA rate surcharge to customers of 4.4 percent. See “Other Regulatory Filings” with respect to Avista Utilities’ request to decrease the PCA rate surcharge.

The following table shows activity in deferred power costs for Washington and Idaho during 2003 and 2004 (dollars in thousands):