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Document And Entity Information - shares	3 Months Ended
Document And Entity Information - shares	Mar. 31, 2012	Apr. 23, 2012
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q1
Trading Symbol	ava
Entity Registrant Name	AVISTA CORP
Entity Central Index Key	0000104918
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		58,674,851

Condensed Consolidated Statements Of Income - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Operating Revenues:
Utility revenues	$ 405,460	$ 437,697
Non-utility revenues	46,797	38,889
Total operating revenues	452,257	476,586
Utility operating expenses:
Resource costs	211,012	248,121
Other operating expenses	63,357	59,682
Depreciation and amortization	27,318	25,852
Taxes other than income taxes	25,142	24,993
Non-utility operating expenses:
Other operating expenses	43,702	31,246
Depreciation and amortization	3,004	1,867
Total operating expenses	373,535	391,761
Income from operations	78,722	84,825
Interest expense	19,137	18,440
Interest expense to affiliated trusts	140	151
Capitalized interest	(525)	(438)
Other expense-net	619	632
Income before income taxes	59,351	66,040
Income tax expense	21,138	23,637
Net income	38,213	42,403
Net loss (income) attributable to noncontrolling interests	175	(485)
Net income attributable to Avista Corporation	$ 38,388	$ 41,918
Weighted-average common shares outstanding (thousands), basic	58,581	57,342
Weighted-average common shares outstanding (thousands), diluted	58,950	57,414
Earnings per common share attributable to Avista Corporation:
Basic	$ 0.66	$ 0.73
Diluted	0.65	0.73
Dividends paid per common share	$ 0.29	$ 0.275

Condensed Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Condensed Consolidated Statements Of Comprehensive Income [Abstract]
Net income	$ 38,213	$ 42,403
Other Comprehensive Income (Loss):
Unrealized investment gains - net of taxes of $39	69
Reclassification adjustment for realized gains on investment securities included in net income - net of taxes of $(5)	(11)
Change in unfunded benefit obligation for pension and other postretirement benefit plans - net of taxes of $82 and $(106), respectively	153	(196)
Total other comprehensive income (loss)	211	(196)
Comprehensive income	38,424	42,207
Comprehensive loss (income) attributable to noncontrolling interests	175	(485)
Comprehensive income attributable to Avista Corporation	$ 38,599	$ 41,722

Condensed Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Condensed Consolidated Statements Of Comprehensive Income [Abstract]
Unrealized investment gains - taxes	$ 39
Reclassification adjustment for realized gains on investment securities included in net income - taxes	(5)
Change in unfunded benefit obligation for pension and other postretirement benefit plans - taxes	$ 82	$ (106)

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2012	Dec. 31, 2011
Current Assets:
Cash and cash equivalents	$ 72,703	$ 74,662
Accounts and notes receivable-less allowances of $45,198 and $43,958	188,726	203,452
Utility energy commodity derivative assets	2,282	1,139
Regulatory asset for utility derivatives	79,232	69,685
Investments and funds held for clients	164,363	118,536
Materials and supplies, fuel stock and natural gas stored	36,354	52,006
Deferred income taxes	36,598	30,473
Income taxes receivable		15,378
Other current assets	26,943	49,225
Total current assets	607,201	614,556
Net Utility Property:
Utility plant in service	3,921,154	3,887,384
Construction work in progress	80,023	79,322
Total	4,001,177	3,966,706
Less: Accumulated depreciation and amortization	1,128,237	1,105,930
Total net utility property	2,872,940	2,860,776
Other Non-current Assets:
Investment in exchange power-net	18,171	18,783
Investment in affiliated trusts	11,547	11,547
Goodwill	73,783	39,045
Long-term energy contract receivable of Spokane Energy	59,985	62,525
Other intangibles, property and investments-net	99,825	80,309
Total other non-current assets	263,311	212,209
Deferred Charges:
Regulatory assets for deferred income tax	81,709	84,576
Regulatory assets for pensions and other postretirement benefits	256,542	260,359
Other regulatory assets	108,492	119,738
Non-current utility energy commodity derivative assets	2,183	185
Non-current regulatory asset for utility derivatives	40,523	40,345
Other deferred charges	21,103	21,787
Total deferred charges	510,552	526,990
Total assets	4,254,004	4,214,531
Current Liabilities:
Accounts payable	134,261	166,954
Client fund obligations	164,003	118,325
Current portion of long-term debt	7,409	7,474
Current portion of nonrecourse long-term debt of Spokane Energy	13,984	13,668
Short-term borrowings	47,000	96,000
Utility energy commodity derivative liabilities	73,604	70,824
Natural gas deferrals	15,221	12,140
Other current liabilities	149,547	141,789
Total current liabilities	605,029	627,174
Long-term debt	1,170,175	1,169,826
Nonrecourse long-term debt of Spokane Energy	29,181	32,803
Long-term debt to affiliated trusts	51,547	51,547
Long-term borrowings under committed line of credit	50,000
Regulatory liability for utility plant retirement costs	228,438	227,282
Pensions and other postretirement benefits	235,576	246,177
Deferred income taxes	508,753	505,954
Other non-current liabilities and deferred credits	110,001	116,084
Total liabilities	2,988,700	2,976,847
Commitments and Contingencies (See Notes to Condensed Consolidated Financial Statements)
Redeemable Noncontrolling Interests	57,633	51,809
Avista Corporation Stockholders' Equity:
Common stock, no par value; 200,000,000 shares authorized; 58,670,801 and 58,422,781 shares outstanding	857,747	855,188
Accumulated other comprehensive loss	(5,426)	(5,637)
Retained earnings	355,818	336,150
Total Avista Corporation stockholders' equity	1,208,139	1,185,701
Noncontrolling Interests	(468)	174
Total equity	1,207,671	1,185,875
Total liabilities and equity	$ 4,254,004	$ 4,214,531

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2012	Dec. 31, 2011
Condensed Consolidated Balance Sheets [Abstract]
Accounts and notes receivable, allowances	$ 45,198	$ 43,958
Common stock, par value
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares outstanding	58,670,801	58,422,781

Condensed Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Operating Activities:
Net income	$ 38,213	$ 42,403
Non-cash items included in net income:
Depreciation and amortization	30,322	27,719
Provision (benefit) for deferred income taxes	(303)	966
Power and natural gas cost amortizations, net	4,098	3,950
Amortization of debt expense and premium	965	1,236
Equity-related AFUDC	(843)	(842)
Other	14,348	12,650
Contributions to defined benefit pension plan	(14,700)	(8,500)
Changes in working capital components:
Accounts and notes receivable	16,079	12,505
Materials and supplies, fuel stock and natural gas stored	15,652	10,222
Other current assets	21,265	10,509
Accounts payable	(16,112)	(16,674)
Other current liabilities	12,315	7,118
Net cash provided by operating activities	121,299	103,262
Investing Activities:
Utility property capital expenditures (excluding equity-related AFUDC)	(57,771)	(49,654)
Other capital expenditures	(1,144)	(474)
Federal grant payments received	2,855	4,353
Cash paid by subsidiaries for acquisitions, net of cash received	(50,310)	(199)
Decrease (increase) in funds held for clients	(35,857)	47,635
Purchase of securities available for sale	(36,461)
Sale of securities available for sale	27,000
Other	(2,628)	(1,502)
Net cash provided by (used in) investing activities	(154,316)	159
Financing Activities:
Net decrease in short-term borrowings	(24,000)	(45,000)
Borrowings from Ecova line of credit	25,000
Redemption and maturity of long-term debt	(65)	(95)
Maturity of nonrecourse long-term debt of Spokane Energy	(3,307)	(3,016)
Long-term debt and short-term borrowing issuance costs	(33)	(2,303)
Issuance of common stock	1,437	8,458
Cash dividends paid	(17,073)	(15,780)
Purchase of subsidiary noncontrolling interest	(134)	(5,639)
Increase (decrease) in client fund obligations	45,169	(47,635)
Issuance of subsidiary noncontrolling interests	3,714
Other	350	13
Net cash provided by (used in) financing activities	31,058	(110,997)
Net decrease in cash and cash equivalents	(1,959)	(7,576)
Cash and cash equivalents at beginning of period	74,662	69,413
Cash and cash equivalents at end of period	72,703	61,837
Cash paid during the year:
Interest	6,680	6,433
Income taxes	1,322	2,200
Non-cash financing and investing activities:
Accounts payable for capital expenditures	2,677	3,963
Redeemable noncontrolling interests	$ 1,764	$ (2,429)

Condensed Consolidated Statements Of Equity And Redeemable Noncontrolling Interests - USD ($) $ in Thousands	Common Stock [Member]	Accumulated Other Comprehensive Loss [Member]	Retained Earnings [Member]	Total Avista Corporation Stockholders' Equity [Member]	Noncontrolling Interests [Member]	Redeemable Noncontrolling Interests [Member]	Total
Beginning Balance (in shares) at Dec. 31, 2010	57,119,723
Issuance of common stock	502,495
Beginning Balance at Dec. 31, 2010	$ 827,592	$ (4,326)	$ 302,518		$ (600)	$ 46,722
Equity compensation expense	889
Issuance of common stock, net of issuance costs	8,458
Equity transactions of consolidated subsidiaries	(3,322)
Other comprehensive income (loss)		(196)					$ (196)
Net income attributable to Avista Corporation			41,918				41,918
Cash dividends paid (common stock)			(15,780)
Net income (loss) attributable to noncontrolling interests					33	452
Other					(5)
Purchase of subsidiary noncontrolling interests						(5,639)
Valuation adjustments and other noncontrolling interests activity			2,628			1,282
Ending Balance at Mar. 31, 2011	$ 833,617	(4,522)	331,284		(572)	42,817
Ending Balance (in shares) at Mar. 31, 2011	57,622,218
Total equity				$ 1,160,379			1,159,807
Total equity							$ 1,185,875
Beginning Balance (in shares) at Dec. 31, 2011	58,422,781						58,422,781
Issuance of common stock	248,020
Beginning Balance at Dec. 31, 2011	$ 855,188	(5,637)	336,150		174	51,809	$ 1,185,701
Equity compensation expense	1,120
Issuance of common stock, net of issuance costs	1,437
Equity transactions of consolidated subsidiaries	2
Other comprehensive income (loss)		211					211
Net income attributable to Avista Corporation			38,388				38,388
Cash dividends paid (common stock)			(17,073)
Net income (loss) attributable to noncontrolling interests					31	(206)
Deconsolidation of variable interest entity					(673)
Issuance of subsidiary noncontrolling interests						3,714	3,714
Purchase of subsidiary noncontrolling interests						(134)
Valuation adjustments and other noncontrolling interests activity			(1,647)			2,450
Ending Balance at Mar. 31, 2012	$ 857,747	$ (5,426)	$ 355,818		$ (468)	$ 57,633	$ 1,208,139
Ending Balance (in shares) at Mar. 31, 2012	58,670,801						58,670,801
Total equity				$ 1,208,139			$ 1,207,671

Summary Of Significant Accounting Policies

3 Months Ended

Mar. 31, 2012

Summary Of Significant Accounting Policies [Abstract]

Summary Of Significant Accounting Policies

NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Nature of Business

Avista Corp. is an energy company engaged in the generation, transmission and distribution of energy, as well as other energy-related businesses. Avista Utilities is an operating division of Avista Corp., comprising the regulated utility operations. Avista Utilities generates, transmits and distributes electricity in parts of eastern Washington and northern Idaho. In addition, Avista Utilities has electric generating facilities in Montana and northern Oregon. Avista Utilities also provides natural gas distribution service in parts of eastern Washington and northern Idaho, as well as parts of northeast and southwest Oregon. Avista Capital, Inc. (Avista Capital), a wholly owned subsidiary of Avista Corp., is the parent company of all of the subsidiary companies in the non-utility businesses, except Spokane Energy, LLC (Spokane Energy). Avista Capital's subsidiaries include Ecova, Inc. (Ecova), a 79.2 percent owned subsidiary as of March 31, 2012. Ecova is a provider of energy efficiency and other facility information and cost management programs and services for multi-site customers and utilities throughout North America. See Note 12 for business segment information.

Basis of Reporting

The condensed consolidated financial statements include the assets, liabilities, revenues and expenses of the Company and its subsidiaries, including Ecova and other majority owned subsidiaries and variable interest entities for which the Company or its subsidiaries are the primary beneficiaries. Intercompany balances were eliminated in consolidation. The accompanying condensed consolidated financial statements include the Company's proportionate share of utility plant and related operations resulting from its interests in jointly owned plants.

Taxes Other Than Income Taxes

Taxes other than income taxes include state excise taxes, city occupational and franchise taxes, real and personal property taxes and certain other taxes not based on net income. These taxes are generally based on revenues or the value of property. Utility related taxes collected from customers (primarily state excise taxes and city utility taxes) are recorded as operating revenue and expense and totaled the following amounts for the three months ended March 31 (dollars in thousands):


	2012		2011
Utility taxes	$	17,834	$	18,123

Other Expense (Income) - Net

Other expense (income) - net consisted of the following items for the three months ended March 31 (dollars in thousands):


	2012			2011
Interest income	$	(275	)	$	(289	)
Interest on regulatory deferrals		(8	)		(45	)
Equity-related AFUDC		(843	)		(842	)
Net loss (gain) on investments		439			(103	)
Other expense		1,306			1,911

Total	$	619		$	632

Investments and Funds Held for Clients and Client Fund Obligations

In connection with the bill paying services, Ecova collects funds from its clients and remits the funds to the appropriate utility or other service provider. The funds collected are invested and classified as investments and funds held for clients and a related liability for client fund obligations is recorded. Investments and funds held for clients include cash and cash equivalent investments and investment securities classified as available for sale.

Investments and funds held for clients as of March 31, 2012 are as follows (dollars in thousands):


	Amortized Cost		Unrealized Gain (Loss)			Fair Value
Cash and cash equivalents	$	58,385	$	—		$	58,385
Securities available for sale:
U.S. government agency		78,653		82			78,735
Municipal		5,373		(9	)		5,364
Corporate fixed income – financial		11,604		134			11,738
Corporate fixed income – industrial		6,463		54			6,517
Corporate fixed income – utility		2,082		32			2,114
Certificates of deposit		1,500		10			1,510

Total securities available for sale		105,675		303			105,978

Total investments and funds held for clients	$	164,060	$	303		$	164,363

Investments and funds held for clients as of December 31, 2011 are as follows (dollars in thousands):


	Amortized Cost		Unrealized Gain (Loss)			Fair Value
Cash and cash equivalents	$	21,957	$	—		$	21,957
Securities available for sale:
U.S. government agency		74,721		172			74,893
Municipal		425		—			425
Corporate fixed income – financial		11,139		15			11,154
Corporate fixed income – industrial		6,495		23			6,518
Corporate fixed income – utility		2,088		4			2,092
Certificates of deposit		1,500		(3	)		1,497

Total securities available for sale		96,368		211			96,579

Total investments and funds held for clients	$	118,325	$	211		$	118,536

The Company has classified investments and funds held for clients as a current asset since these funds are held solely for the purpose of satisfying the client fund obligations. Approximately 92 percent and 88 percent of the investment portfolio was rated AA or higher as of March 31, 2012 and December 31, 2011, respectively, by Nationally Recognized Statistical Rating Organizations. All fixed income securities were rated as investment grade as of March 31, 2012 and December 31, 2011. Contractual maturities of securities available for sale (at fair value) as of March 31, 2012 and December 31, 2011 are as follows (dollars in thousands):


	Due within 1 year		After 1 but within 5 years		After 5 but within 10 years		Total
March 31, 2012	$	1,459	$	38,703	$	65,816	$	105,978
December 31, 2011		425		55,126		41,028		96,579

Actual maturities may differ due to call or prepayment rights and the effective duration was 1.7 years as of March 31, 2012 and 1.3 years as of December 31, 2011.

Goodwill

Goodwill arising from acquisitions represents the excess of the purchase price over the estimated fair value of net assets acquired. The Company evaluates goodwill for impairment using a discounted cash flow model on at least an annual basis or more frequently if impairment indicators arise. The Company completed its annual evaluation of goodwill for potential impairment as of November 30, 2011 for the other businesses and as of December 31, 2011 for Ecova and determined that goodwill was not impaired at that time. The changes in the carrying amount of goodwill are as follows (dollars in thousands):


	Ecova		Other		Accumulated Impairment Losses			Total
Balance as of December 31, 2011	$	33,799	$	12,979	$	(7,733	)	$	39,045
Goodwill acquired during the period		33,484		—		—			33,484
Adjustments		1,254		—		—			1,254

Balance as of the March 31, 2012	$	68,537	$	12,979	$	(7,733	)	$	73,783

Accumulated impairment losses are attributable to the other businesses. The goodwill acquired in 2012 was related to Ecova's acquisition of LPB Energy Management (LPB) effective January 31, 2012. The adjustment to goodwill recorded represents purchase accounting adjustments for Ecova's acquisition of Prenova based upon the further review of the fair market values of relevant assets and liabilities identified as of the acquisition date.

Other Intangibles

Other Intangibles represent the amounts assigned to client relationships related to the Ecova acquisition of Cadence Network in 2008 (estimated amortization period of 12 years), Ecos in 2009 (estimated amortization period of 3 years), Loyalton in 2010 (estimated amortization period of 6 years), Prenova in 2011 (estimated amortization period of 9 years) and LPB in 2012 (estimated amortization period of 3 to 10 years), software development costs (estimated amortization period of 3 to 7 years) and other. Other Intangibles are included in other intangibles, property and investments - net on the Condensed Consolidated Balance Sheets. Amortization expense related to Other Intangibles was as follows for the three months ended March 31 (dollars in thousands):


	2012		2011
Other intangible amortization	$	2,097	$	900

The following table details the future estimated amortization expense related to Other Intangibles for each of the five years ending December 31 (dollars in thousands):


	2012		2013		2014		2015		2016
Estimated amortization expense	$	9,675	$	10,235	$	9,265	$	6,204	$	4,687

The gross carrying amount and accumulated amortization of Other Intangibles as of March 31, 2012 and December 31, 2011 are as follows (dollars in thousands):


	March 31, 2012			December 31, 2011
Client relationships	$	32,577		$	18,859
Software development costs		29,650			29,327
Other		4,735			3,065

Total other intangibles		66,962			51,251

Client relationships accumulated amortization		(4,255	)		(3,623	)
Software development costs accumulated amortization		(12,939	)		(12,016	)
Other accumulated amortization		(1,047	)		(990	)

Total accumulated amortization		(18,241	)		(16,629	)

Total other intangibles - net	$	48,721		$	34,622

Derivative Assets and Liabilities

Derivatives are recorded as either assets or liabilities on the Condensed Consolidated Balance Sheets measured at estimated fair value. In certain defined conditions, a derivative may be specifically designated as a hedge for a particular exposure. The accounting for derivatives depends on the intended use of the derivatives and the resulting designation.

The Washington Utilities and Transportation Commission (WUTC) and the Idaho Public Utilities Commission (IPUC) issued accounting orders authorizing Avista Utilities to offset commodity derivative assets or liabilities with a regulatory asset or liability. This accounting treatment is intended to defer the recognition of mark-to-market gains and losses on energy commodity transactions until the period of settlement. The orders provide for Avista Utilities to not recognize the unrealized gain or loss on utility derivative commodity instruments in the Condensed Consolidated Statements of Income. Realized gains or losses are recognized in the period of settlement, subject to approval for recovery through retail rates. Realized gains and losses, subject to regulatory approval, result in adjustments to retail rates through purchased gas cost adjustments, the Energy Recovery Mechanism (ERM) in Washington, the Power Cost Adjustment (PCA) mechanism in Idaho, and periodic general rates cases. Regulatory assets are assessed regularly and are probable for recovery through future rates.

Substantially all forward contracts to purchase or sell power and natural gas are recorded as derivative assets or liabilities at estimated fair value with an offsetting regulatory asset or liability. Contracts that are not considered derivatives are accounted for on the accrual basis until they are settled or realized, unless there is a decline in the fair value of the contract that is determined to be other than temporary.

Fair Value Measurements

Fair value represents the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Energy commodity derivative assets and liabilities, investments and funds held for clients, deferred compensation assets, as well as derivatives related to interest rate swap agreements and foreign currency exchange contracts, are reported at estimated fair value on the Condensed Consolidated Balance Sheets. See Note 9 for the Company's fair value disclosures.

Regulatory Deferred Charges and Credits

The Company prepares its condensed consolidated financial statements in accordance with regulatory accounting practices because:

•

rates for regulated services are established by or subject to approval by independent third-party regulators,

•

the regulated rates are designed to recover the cost of providing the regulated services, and

•

in view of demand for the regulated services and the level of competition, it is reasonable to assume that rates can be charged to and collected from customers at levels that will recover costs.

Regulatory accounting practices require that certain costs and/or obligations (such as incurred power and natural gas costs not currently included in rates, but expected to be recovered or refunded in the future) are reflected as deferred charges or credits on the Condensed Consolidated Balance Sheets. These costs and/or obligations are not reflected in the Condensed Consolidated Statements of Income until the period during which matching revenues are recognized. If at some point in the future the Company determines that it no longer meets the criteria for continued application of regulatory accounting practices for all or a portion of its regulated operations, the Company could be:

•

required to write off its regulatory assets, and

•

precluded from the future deferral of costs not recovered through rates at the time such costs are incurred, even if the Company expected to recover such costs in the future.

Contingencies

The Company has unresolved regulatory, legal and tax issues which have inherently uncertain outcomes. The Company accrues a loss contingency if it is probable that a liability has been incurred and the amount of the loss or impairment can be reasonably estimated. The Company also discloses losses that do not meet these conditions for accrual, if there is a reasonable possibility that a loss may be incurred.

New Accounting Standards	3 Months Ended
New Accounting Standards	Mar. 31, 2012
New Accounting Standards [Abstract]
New Accounting Standards	NOTE 2. NEW ACCOUNTING STANDARDS Effective January 1, 2012, the Company adopted Accounting Standards Update (ASU) No. 2011-04, "Fair Value Measurement (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs." This ASU requires enhanced disclosures for fair value measurements, including quantitative sensitivity analysis of unobservable inputs used in Level 3 fair value measurements. The ASU also clarifies the FASB's intent about the application of existing fair value measurement requirements. The Company adopted this ASU effective January 1, 2012. The adoption of this ASU did not have any impact on the Company's financial condition, results of operations and cash flows. See Note 9 for the Company's fair value disclosures. In September 2011, the Financial Accounting Standards Board (FASB) issued ASU No. 2011-08, "Intangibles – Goodwill and Other (Topic 350): Testing Goodwill for Impairment." This ASU amends the guidance on testing goodwill for impairment, providing entities with the option of performing a qualitative assessment before calculating the fair value of the reporting unit. If it is determined, on the basis of the qualitative assessment, that the fair value of the reporting unit is more likely than not less than the carrying amount, the two-step impairment test would be required. This ASU does not change how goodwill is calculated or assigned to reporting units, nor does it revise the requirement to test goodwill annually for impairment. This ASU is effective for goodwill impairment tests performed for fiscal years beginning after December 15, 2011, with early adoption permitted. The Company does not expect that this ASU will have any material impact on its testing of goodwill for impairment.

- Definition

The entire disclosure for reporting accounting changes and error corrections. It includes the conveyance of information necessary for a user of the Company's financial information to understand all aspects and required disclosure information concerning all changes and error corrections reported in the Company's financial statements for the period.

+ References + Details

Variable Interest Entities	3 Months Ended
Variable Interest Entities	Mar. 31, 2012
Variable Interest Entities [Abstract]
Variable Interest Entities	NOTE 3. VARIABLE INTEREST ENTITIES The Company has a power purchase agreement (PPA) for the purchase of all the output of the Lancaster Plant, a 270 MW natural gas-fired combined cycle combustion turbine plant located in Idaho, owned by an unrelated third-party (Rathdrum Power LLC), through 2026. Avista Corp. has a variable interest in the PPA. Accordingly, Avista Corp. made an evaluation of which interest holders have the power to direct the activities that most significantly impact the economic performance of the entity and which interest holders have the obligation to absorb losses or receive benefits that could be significant to the entity. Avista Corp. pays a fixed capacity and operations and maintenance payment and certain monthly variable costs under the PPA. Under the terms of the PPA, Avista Corp. makes the dispatch decisions, provides all natural gas fuel and receives all of the electric energy output from the Lancaster Plant. However, Rathdrum Power LLC (the owner) controls the daily operation of the Lancaster Plant and makes operating and maintenance decisions. Rathdrum Power LLC controls all of the rights and obligations of the Lancaster Plant after the expiration of the PPA in 2026. It is estimated that the plant will have 15 to 25 years of useful life after that time. Rathdrum Power LLC bears the maintenance risk of the plant and will receive the residual value of the Lancaster Plant. Avista Corp. has no debt or equity investments in the Lancaster Plant and does not provide financial support through liquidity arrangements or other commitments (other than the PPA). Based on its analysis, Avista Corp. does not consider itself to be the primary beneficiary of the Lancaster Plant. Accordingly, neither the Lancaster Plant nor Rathdrum Power LLC is included in Avista Corp.'s condensed consolidated financial statements. The Company has a future contractual obligation of approximately $336 million under the PPA (representing the fixed capacity and operations and maintenance payments through 2026) and believes this would be its maximum exposure to loss. However, the Company believes that such costs will be recovered through retail rates. Ecova formed a partnership, SEEL, LLC (SEEL) with a third party for the purpose of entering into utility contracts to provide energy efficiency services. SEEL is funded 49 percent by Ecova and 51 percent by the third party. Prior to 2012, Ecova determined that it was the primary beneficiary of SEEL based on its management of the entity and its technical expertise in obtaining and fulfilling the utility contracts, and Ecova was obligated to absorb the losses or receive the benefits that could be significant to SEEL. In 2012, Ecova is no longer the primary beneficiary of SEEL because it is no longer the sole provider of the technical expertise necessary to obtain and fulfill utility contracts. As of January 1, 2012, Ecova uses the equity method to account for its arrangement with SEEL.

- Definition

Tabular disclosure of the significant judgments and assumptions made in determining whether a variable interest (as defined) held by the entity requires the variable interest entity (VIE) (as defined) to be consolidated and (or) disclose information about its involvement with the VIE, individually or in aggregate (as applicable); the nature of restrictions, if any, on the consolidated VIE's assets and on the settlement of its liabilities reported by an entity in its statement of financial position, including the carrying amounts of such assets and liabilities; the nature of, and changes in, the risks associated with involvement in the VIE; how involvement with the VIE affects the entity's financial position, financial performance, and cash flows; the lack of recourse if creditors (or beneficial interest holders) of the consolidated VIE have no recourse to the general credit of the primary beneficiary (if applicable); the terms of arrangements, giving consideration to both explicit arrangements and implicit variable interests, if any, that could require the entity to provide financial support to the VIE, including events or circumstances that could expose the entity to a loss; the methodology used by the entity for determining whether or not it is the primary beneficiary of the variable interest entity; the significant factors considered and judgments made in determining that the power to direct the activities of a VIE that most significantly impact the VIE's economic performance are shared (as defined); the carrying amounts and classification of assets and liabilities of the VIE included in the statement of financial position; the entity's maximum exposure to loss, if any, as a result of its involvement with the VIE, including how the maximum exposure is determined and significant sources of the entity's exposure to the VIE; a comparison of the carrying amounts of the assets and liabilities and the entity's maximum exposure to loss; information about any liquidity arrangements, guarantees, and (or) other commitments by third parties that may affect the fair value or risk of the entity's variable interest in the VIE; whether or not the entity has provided financial support or other support (explicitly or implicitly) to the VIE that it was not previously contractually required to provide or whether the entity intends to provide that support, including the type and amount of the support and the primary reasons for providing the support; and supplemental information the entity determines necessary to provide.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 46R
-Paragraph 4
-Subparagraph g
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 46R
-Paragraph 2, 14, 15, 16, 23, 24, 25, 26
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Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 140
-Paragraph 35
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
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-Section 50
-Paragraph 4
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Reference 5: http://www.xbrl.org/2003/role/presentationRef
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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-URI http://asc.fasb.org/extlink&oid=6528138

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Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
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-Paragraph 22B

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 167
-Appendix D
-Paragraph 22E

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 167
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Reference 12: http://www.xbrl.org/2003/role/presentationRef
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Reference 13: http://www.xbrl.org/2003/role/presentationRef
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Reference 14: http://www.xbrl.org/2003/role/presentationRef
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-URI http://asc.fasb.org/extlink&oid=6970148&loc=SL6228884-111685

+ Details

Redeemable Noncontrolling Interests And Subsidiary Acquisitions

3 Months Ended

Mar. 31, 2012

Redeemable Noncontrolling Interests And Subsidiary Acquisitions [Abstract]

Redeemable Noncontrolling Interests And Subsidiary Acquisitions

NOTE 4. REDEEMABLE NONCONTROLLING INTERESTS AND SUBSIDIARY ACQUISITIONS

The acquisition of Cadence Network in July 2008 was funded with the issuance of Ecova common stock. Under the transaction agreement, the previous owners of Cadence Network can exercise a right to have their shares of Ecova common stock redeemed during July 2011 or July 2012 if Ecova is not liquidated through either an initial public offering or sale of the business to a third party. These rights were not exercised during July 2011. These redemption rights expire July 31, 2012. The redemption price would be determined based on the fair market value of Ecova at the time of the redemption election as determined by certain independent parties. Additionally, certain minority shareholders and option holders of Ecova have the right to put their shares back to Ecova at their discretion during an annual put window. The following details redeemable noncontrolling interests as of March 31, 2012 and December 31, 2011 (dollars in thousands):


	March 31, 2012		December 31, 2011
Previous owners of Cadence Network	$	44,295	$	38,893
Stock options and other outstanding redeemable stock		13,338		12,916

Total redeemable noncontrolling interests	$	57,633	$	51,809

On November 30, 2011, Ecova acquired Prenova, Inc. (Prenova), an Atlanta-based energy management company. The cash paid for the acquisition of Prenova of $35.6 million was funded primarily through borrowings under Ecova's committed credit agreement. The acquired assets and assumed liabilities of Prenova were recorded at their respective estimated fair values as of the date of acquisition. Final purchase accounting is pending the completion of further review of the fair market values of relevant assets and liabilities identified as of the acquisition date. The results of operations of Prenova are included in the condensed consolidated financial statements beginning December 1, 2011.

On January 31, 2012, Ecova acquired LPB Energy Management (LPB), a Dallas, Texas-based energy management company. The cash paid for the acquisition of LPB of $50.6 million was funded by Ecova through $25.0 million of borrowings under its committed credit agreement, a $20.0 million equity infusion from existing shareholders (including Avista Capital and certain other owners of Ecova), and available cash. The acquired assets and assumed liabilities of LPB were recorded at their respective estimated fair values as of the date of acquisition. Assets recorded include the following: accounts receivable of $2.5 million, goodwill of $33.5 million, client backlog of $8.2 million (estimated amortization period of 3 years), client relationships of $4.8 million (estimated amortization period of 10 years) and internal use software of $2.5 million (estimated amortization period of 3 to 4 years). These intangible assets are included in other intangibles, property and investments on the Condensed Consolidated Balance Sheet. Final purchase accounting is pending the completion of further review of the fair market values of relevant assets and liabilities identified as of the acquisition date. The results of operations of LPB are included in the condensed consolidated financial statements beginning February 1, 2012.

Pro forma disclosures reflecting the effects of Ecova's acquisitions are not presented, as the acquisitions are not material to Avista Corp.'s condensed consolidated results of operations.

- Definition

The entire disclosure for a business combination (or series of individually immaterial business combinations) completed during the period, including background, timing, and recognized assets and liabilities. The disclosure may include leverage buyout transactions (as applicable).

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 88-16
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141
-Paragraph 51, 52
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
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-Paragraph 67-73
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+ Details

Derivatives And Risk Management

3 Months Ended

Mar. 31, 2012

Derivatives And Risk Management [Abstract]

Derivatives And Risk Management

NOTE 5. DERIVATIVES AND RISK MANAGEMENT

Energy Commodity Derivatives

Avista Utilities is exposed to market risks relating to changes in electricity and natural gas commodity prices and certain other fuel prices. Market risk is, in general, the risk of fluctuation in the market price of the commodity being traded and is influenced primarily by supply and demand. Market risk includes the fluctuation in the market price of associated derivative commodity instruments. Market risk may also be influenced by market participants' nonperformance of their contractual obligations and commitments, which affects the supply of, or demand for, the commodity. Avista Utilities utilizes derivative instruments, such as forwards, futures, swaps and options in order to manage the various risks relating to these commodity price exposures. The Company has an energy resources risk policy and control procedures to manage these risks. The Company's Risk Management Committee establishes the Company's energy resources risk policy and monitors compliance. The Risk Management Committee is comprised of certain Company officers and other members of management. The Audit Committee of the Company's Board of Directors periodically reviews and discusses enterprise risk management processes, and it focuses on the Company's material financial and accounting risk exposures and the steps management has undertaken to control them.

As part of its resource procurement and management operations in the electric business, Avista Utilities engages in an ongoing process of resource optimization, which involves the economic selection from available energy resources to serve Avista Utilities' load obligations and the use of these resources to capture available economic value. Avista Utilities sells and purchases wholesale electric capacity and energy and fuel as part of the process of acquiring and balancing resources to serve its load obligations. These transactions range from terms of 30 minutes up to multiple years.

Avista Utilities makes continuing projections of:

•

electric loads at various points in time (ranging from 30 minutes to multiple years) based on, among other things, estimates of customer usage and weather, historical data and contract terms, and

•

resource availability at these points in time based on, among other things, fuel choices and fuel markets, estimates of streamflows, availability of generating units, historic and forward market information, contract terms, and experience.

On the basis of these projections, Avista Utilities makes purchases and sales of electric capacity and energy and fuel to match expected resources to expected electric load requirements. Resource optimization involves generating plant dispatch and scheduling available resources and also includes transactions such as:

•

purchasing fuel for generation,

•

when economical, selling fuel and substituting wholesale electric purchases, and

•

other wholesale transactions to capture the value of generation and transmission resources and fuel delivery capacity contracts.

Avista Utilities' optimization process includes entering into hedging transactions to manage risks.

As part of its resource procurement and management operations in the natural gas business, Avista Utilities makes continuing projections of its natural gas loads and assesses available natural gas resources including natural gas storage availability. Natural gas resource planning typically includes peak requirements, low and average monthly requirements and delivery constraints from natural gas supply locations to Avista Utilities' distribution system. However, daily variations in natural gas demand can be significantly different than monthly demand projections. On the basis of these projections, Avista Utilities plans and executes a series of transactions to hedge a significant portion of its projected natural gas requirements through forward market transactions and derivative instruments. These transactions may extend as much as four natural gas operating years (November through October) into the future. Avista Utilities also leaves a significant portion of its natural gas supply requirements unhedged for purchase in short-term and spot markets. Natural gas resource optimization activities include:

•

wholesale market sales of surplus natural gas supplies,

•

optimization of interstate pipeline transportation capacity not needed to serve daily load, and

•

purchases and sales of natural gas to optimize use of storage capacity.

The following table presents the underlying energy commodity derivative volumes as of March 31, 2012 that are expected to settle in each respective year (in thousands of MWhs and mmBTUs):


	Purchases								Sales
	Electric Derivatives				Gas Derivatives				Electric Derivatives				Gas Derivatives
Year	Physical MWH		Financial MWH		Physical mmBTUs		Financial mmBTUs		Physical MWH		Financial MWH		Physical mmBTUs		Financial mmBTUs
2012		976		845		28,466		7,577		638		433		6,819		4,634
2013		537		245		11,895		10,270		310		491		1,533		1,727
2014		366		0		5,939		5,586		286		246		1,050		225
2015		379		—		3,013		980		285		—		—		—
2016		367		—		1,137		455		287		—		—		—
Thereafter		949		—		—		—		730		—		—		—

Foreign Currency Exchange Contracts

A significant portion of Avista Utilities' natural gas supply (including fuel for power generation) is obtained from Canadian sources. Most of those transactions are executed in U.S. dollars, which avoids foreign currency risk. A portion of Avista Utilities' short-term natural gas transactions and long-term Canadian transportation contracts are committed based on Canadian currency prices and settled within sixty days with U.S. dollars. Avista Utilities economically hedges a portion of the foreign currency risk by purchasing Canadian currency contracts when such commodity transactions are initiated. This risk has not had a material effect on the Company's financial condition, results of operations or cash flows and these differences in cost related to currency fluctuations were included with natural gas supply costs for ratemaking. The following table summarizes the foreign currency hedges that the Company has entered into as of March 31, 2012 and December 31, 2011 (dollars in thousands):


	March 31, 2012			December 31, 2011
Number of contracts		31			28
Notional amount (in United States dollars)	$	4,258		$	7,033
Notional amount (in Canadian dollars)		4,235			7,192
Derivatives in other current assets (liabilities)		(25	)		32

Interest Rate Swap Agreements

Avista Corp. hedges a portion of its interest rate risk with financial derivative instruments, which may include interest rate swaps and U.S. Treasury lock agreements. These interest rate swap agreements are considered economic hedges against fluctuations in future cash flows associated with anticipated debt issuances. The following table summarizes the interest rate swaps that the Company has entered into as of March 31, 2012 and December 31, 2011 (dollars in thousands):


	March 31, 2012			December 31, 2011
Number of contracts		3			3
Notional amount	$	75,000		$	75,000
Mandatory cash settlement date		July 2012			July 2012
Current derivative liability		(9,241	)		(16,253	)
Number of contracts		2			2
Notional amount	$	85,000		$	85,000
Mandatory cash settlement date		June 2013			June 2013
Non-current derivative asset (liability)		5,084			(2,642	)

Upon settlement of the interest rate swaps, the regulatory asset or liability (included as part of long-term debt) is amortized as a component of interest expense over the life of the forecasted interest payments.

Derivative Instruments Summary

The following table presents the fair values and locations of derivative instruments recorded on the Condensed Consolidated Balance Sheet as of March 31, 2012 (in thousands):


		Fair Value
Derivative	Balance Sheet Location	Asset		Liability			Net Asset (Liability)
Foreign currency contracts	Other current liabilities	$	—	$	(25	)	$	(25	)
Interest rate contracts	Other current liabilities		—		(9,241	)		(9,241	)
Interest rate contracts	Other intangibles, property and Investments - net		5,084		—			5,084
Commodity contracts	Current utility energy commodity derivative assets		2,647		(365	)		2,282
Commodity contracts	Non-current utility energy commodity derivative assets		8,148		(5,965	)		2,183
Commodity contracts	Current utility energy commodity derivative liabilities		10,461		(84,065	)		(73,604	)
Commodity contracts	Other non-current liabilities and deferred credits		1,147		(35,864	)		(34,717	)

Total derivative instruments recorded on the balance sheet		$	27,487	$	(135,525	)	$	(108,038	)

The following table presents the fair values and locations of derivative instruments recorded on the Condensed Consolidated Balance Sheet as of December 31, 2011 (in thousands):


		Fair Value
Derivative	Balance Sheet Location	Asset		Liability			Net Asset (Liability)
Foreign currency contracts	Other current assets	$	32	$	—		$	32
Interest rate contracts	Other current liabilities		—		(16,253	)		(16,253	)
Interest rate contracts	Other non-current liabilities and deferred credits		—		(2,642	)		(2,642	)
Commodity contracts	Current utility energy commodity derivative assets		1,618		(479	)		1,139
Commodity contracts	Non-current utility energy commodity derivative assets		185		—			185
Commodity contracts	Current utility energy commodity derivative liabilities		40,090		(110,914	)		(70,824	)
Commodity contracts	Other non-current liabilities and deferred credits		44,308		(84,838	)		(40,530	)

Total derivative instruments recorded on the balance sheet		$	86,233	$	(215,126	)	$	(128,893	)

Exposure to Demands for Collateral

The Company's derivative contracts often require collateral (in the form of cash or letters of credit) or other credit enhancements, or reductions or terminations of a portion of the contract through cash settlement, in the event of a downgrade in the Company's credit ratings or changes in market prices. In periods of price volatility, the level of exposure can change significantly. As a result, sudden and significant demands may be made against the Company's credit facilities and cash. The Company actively monitors the exposure to possible collateral calls and takes steps to mitigate capital requirements. As of March 31, 2012, the Company had cash deposited as collateral of $20.5 million and letters of credit of $12.5 million outstanding related to its energy derivative contracts. The Consolidated Balance Sheet at March 31, 2012 reflects the offsetting of $15.9 million of cash collateral against net derivative positions where management believes a legal right of offset exists.

Certain of the Company's derivative instruments contain provisions that require the Company to maintain an investment grade credit rating from the major credit rating agencies. If the Company's credit ratings were to fall below "investment grade," it would be in violation of these provisions, and the counterparties to the derivative instruments could request immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position as of March 31, 2012 was $84.7 million. If the credit-risk-related contingent features underlying these agreements were triggered on March 31, 2012, the Company could be required to post $64.3 million of additional collateral to its counterparties.

Credit Risk

Credit risk relates to the potential losses that the Company would incur as a result of non-performance by counterparties of their contractual obligations to deliver energy or make financial settlements. The Company often extends credit to counterparties and customers and is exposed to the risk that it may not be able to collect amounts owed to the Company. Credit risk includes potential counterparty default due to circumstances:

•

relating directly to it,

•

caused by market price changes, and

•

relating to other market participants that have a direct or indirect relationship with such counterparty.

Changes in market prices may dramatically alter the size of credit risk with counterparties, even when conservative credit limits are established. Should a counterparty fail to perform, the Company may be required to honor the underlying commitment or to replace existing contracts with contracts at then-current market prices. The Company seeks to mitigate credit risk by:

•

entering into bilateral contracts that specify credit terms and protections against default,

•

applying credit limits and duration criteria to existing and prospective counterparties,

•

actively monitoring current credit exposures, and

•

conducting transactions on exchanges with fully collateralized clearing arrangements that significantly reduce counterparty default risk.

These credit policies include an evaluation of the financial condition and credit ratings of counterparties, collateral requirements or other credit enhancements, such as letters of credit or parent company guarantees. The Company also uses standardized agreements that allow for the netting or offsetting of positive and negative exposures associated with a single counterparty or affiliated group.

The Company has concentrations of suppliers and customers in the electric and natural gas industries including:

•

electric and natural gas utilities,

•

electric generators and transmission providers,

•

natural gas producers and pipelines,

•

financial institutions including commodity clearing exchanges and related parties, and

•

energy marketing and trading companies.

In addition, the Company has concentrations of credit risk related to geographic location as it operates in the western United States and western Canada. These concentrations of counterparties and concentrations of geographic location may impact the Company's overall exposure to credit risk because the counterparties may be similarly affected by changes in conditions.

The Company maintains margin agreements with certain counterparties and margin calls are periodically made and/or received. Margin calls are triggered when exposures exceed predetermined contractual limits or when there are changes in a counterparty's creditworthiness. Price movements in electricity and natural gas can generate exposure levels in excess of these contractual limits. Negotiating for collateral in the form of cash, letters of credit, or performance guarantees is common industry practice.

- Definition

The entire disclosure for the entity's entire derivative instruments and hedging activities. Describes an entity's risk management strategies, derivatives in hedging activities and non-hedging derivative instruments, the assets, obligations, liabilities, revenues and expenses arising therefrom, and the amounts of and methodologies and assumptions used in determining the amounts of such items.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 45
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

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+ Details

Pension Plans And Other Postretirement Benefit Plans

3 Months Ended

Mar. 31, 2012

Pension Plans And Other Postretirement Benefit Plans [Abstract]

Pension Plans And Other Postretirement Benefit Plans

NOTE 6. PENSION PLANS AND OTHER POSTRETIREMENT BENEFIT PLANS

The Company has a defined benefit pension plan covering substantially all regular full-time employees at Avista Utilities. Individual benefits under this plan are based upon the employee's years of service, date of hire and average compensation as specified in the plan. The Company's funding policy is to contribute at least the minimum amounts that are required to be funded under the Employee Retirement Income Security Act, but not more than the maximum amounts that are currently deductible for income tax purposes. The Company contributed $26 million in cash to the pension plan in 2011. The Company expects to contribute $44 million in cash to the pension plan in 2012 ($14.7 million was contributed during the three months ended March 31, 2012).

The Company also has a Supplemental Executive Retirement Plan (SERP) that provides additional pension benefits to executive officers of the Company. The SERP is intended to provide benefits to executive officers whose benefits under the pension plan are reduced due to the application of Section 415 of the Internal Revenue Code of 1986 and the deferral of salary under deferred compensation plans. The liability and expense for this plan are included as pension benefits in the tables included in this Note.

The Company provides certain health care and life insurance benefits for substantially all of its retired employees. The Company accrues the estimated cost of postretirement benefit obligations during the years that employees provide services.

The Company has a Health Reimbursement Arrangement to provide employees with tax-advantaged funds to pay for allowable medical expenses upon retirement. The amount earned by the employee is fixed on the retirement date based on the employee's years of service and the ending salary. The liability and expense of this plan are included as other postretirement benefits.

The Company provides death benefits to beneficiaries of executive officers who die during their term of office or after retirement. Under the plan, an executive officer's designated beneficiary will receive a payment equal to twice the executive officer's annual base salary at the time of death (or if death occurs after retirement, a payment equal to twice the executive officer's total annual pension benefit). The liability and expense for this plan are included as other postretirement benefits.

The Company uses a December 31 measurement date for its pension and other postretirement benefit plans. The following table sets forth the components of net periodic benefit costs for the three months ended March 31 (dollars in thousands):


	Pension Benefits						Other Post- retirement Benefits
	2012			2011			2012			2011
Service cost	$	3,791		$	2,942		$	689		$	227
Interest cost		6,109			6,109			1,281			919
Expected return on plan assets		(6,000	)		(5,591	)		(375	)		(443	)
Transition obligation recognition		—			—			126			126
Amortization of prior service cost		75			119			(38	)		(37	)
Net loss recognition		2,757			2,105			1,312			435

Net periodic benefit cost	$	6,732		$	5,684		$	2,995		$	1,227

- Definition

The entire disclosure for pension and other postretirement benefits.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph h
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
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-Paragraph 5
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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 8
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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 106
-Paragraph 518
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 87
-Paragraph 264
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

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-Name Accounting Principles Board Opinion (APB)
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-Paragraph 26
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-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 158
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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

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-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5, 6, 7, 8
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

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-Publisher FASB
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-Number FAS88
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-Name Accounting Standards Codification
-Topic 715
-URI http://asc.fasb.org/topic&trid=2235017

+ Details

Short-Term Borrowings

3 Months Ended

Mar. 31, 2012

Short-Term Borrowings [Abstract]

Short-Term Borrowings

NOTE 7. SHORT-TERM BORROWINGS

Avista Corp.

Avista Corp. has a committed line of credit with various financial institutions in the total amount of $400.0 million with an expiration date of February 2017. The committed line of credit is secured by non-transferable First Mortgage Bonds of the Company issued to the agent bank that would only become due and payable in the event, and then only to the extent, that the Company defaults on its obligations under the committed line of credit.

The committed line of credit agreement contains customary covenants and default provisions. The credit agreement has a covenant which does not permit the ratio of "consolidated total debt" to "consolidated total capitalization" of Avista Corp. to be greater than 65 percent at any time. As of March 31, 2012, the Company was in compliance with this covenant.

Balances outstanding and interest rates of borrowings (excluding letters of credit) under the Company's revolving committed lines of credit were as follows as of March 31, 2012 and December 31, 2011 (dollars in thousands):


	March 31, 2012			December 31, 2011
Balance outstanding at end of period	$	37,000		$	61,000
Letters of credit outstanding at end of period	$	20,090		$	29,030
Average interest rate at end of period		3.25	%		1.12	%

Ecova

Ecova has a $60.0 million committed line of credit agreement with a financial institution that expires in April 2014. The amount of this committed line of credit will decrease to $55.0 million on September 30, 2012 and $50.0 million on December 31, 2012. The credit agreement is secured by substantially all of Ecova's assets. Balances outstanding and interest rates of borrowings under Ecova's credit agreements were as follows as of March 31, 2012 and December 31, 2011 (dollars in thousands):


	March 31, 2012			December 31, 2011
Balance outstanding at end of period	$	60,000		$	35,000
Average interest rate at end of period		2.25	%		2.38	%

As of March 31, 2012, $50.0 million of the borrowings under Ecova's committed line of credit were classified as long-term and $10.0 million were classified as short-term.

Long-Term Debt

3 Months Ended

Mar. 31, 2012

Long-Term Debt [Abstract]

Long-Term Debt

NOTE 8. LONG-TERM DEBT

The following details long-term debt outstanding as of March 31, 2012 and December 31, 2011 (dollars in thousands):


Maturity Year	Description	Interest Rate	March 31, 2012			December 31, 2011
2012	Secured Medium-Term Notes	7.37%	$	7,000		$	7,000
2013	First Mortgage Bonds	1.68%		50,000			50,000
2018	First Mortgage Bonds	5.95%		250,000			250,000
2018	Secured Medium-Term Notes	7.39%-7.45%		22,500			22,500
2019	First Mortgage Bonds	5.45%		90,000			90,000
2020	First Mortgage Bonds	3.89%		52,000			52,000
2022	First Mortgage Bonds	5.13%		250,000			250,000
2023	Secured Medium-Term Notes	7.18%-7.54%		13,500			13,500
2028	Secured Medium-Term Notes	6.37%		25,000			25,000
2032	Secured Pollution Control Bonds (1)	(1)		66,700			66,700
2034	Secured Pollution Control Bonds (2)	(2)		17,000			17,000
2035	First Mortgage Bonds	6.25%		150,000			150,000
2037	First Mortgage Bonds	5.70%		150,000			150,000
2040	First Mortgage Bonds	5.55%		35,000			35,000
2041	First Mortgage Bonds	4.45%		85,000			85,000

	Total secured long-term debt			1,263,700			1,263,700
2023	Unsecured Pollution Control Bonds	6.00%		4,100			4,100
	Other long-term debt and capital leases			5,389			5,455
	Settled interest rate swaps			(10,321	)		(10,629	)
	Unamortized debt discount			(1,584	)		(1,626	)

	Total			1,261,284			1,261,000
	Secured Pollution Control Bonds held by Avista Corporation (1) (2)			(83,700	)		(83,700	)
	Current portion of long-term debt			(7,409	)		(7,474	)

	Total long-term debt		$	1,170,175		$	1,169,826

(1)

In December 2010, $66.7 million of the City of Forsyth, Montana Pollution Control Revenue Refunding Bonds (Avista Corporation Colstrip Project) due 2032, which had been held by Avista Corp. since 2008, were refunded by a new bond issue (Series 2010A). The new bonds were not offered to the public and were purchased by Avista Corp. due to market conditions. The Company expects that at a later date, subject to market conditions, these bonds may be remarketed to unaffiliated investors. So long as Avista Corp. is the holder of these bonds, the bonds will not be reflected as an asset or a liability on Avista Corp.'s Condensed Consolidated Balance Sheet.

(2)

In December 2010, $17.0 million of the City of Forsyth, Montana Pollution Control Revenue Refunding Bonds, (Avista Corporation Colstrip Project) due 2034, which had been held by Avista Corp. since 2009, were refunded by a new bond issue (Series 2010B). The new bonds were not offered to the public and were purchased by Avista Corp. due to market conditions. The Company expects that at a later date, subject to market conditions, the bonds may be remarketed to unaffiliated investors. So long as Avista Corp. is the holder of these bonds, the bonds will not be reflected as an asset or a liability on Avista Corp.'s Condensed Consolidated Balance Sheet.

Nonrecourse Long-Term Debt

Nonrecourse long-term debt (including current portion) represents the long-term debt of Spokane Energy. To provide funding to acquire a long-term fixed rate electric capacity contract from Avista Corp., Spokane Energy borrowed $145.0 million from a funding trust in December 1998. The long-term debt has scheduled monthly installments and interest at a fixed rate of 8.45 percent with the final payment due in January 2015. Spokane Energy bears full recourse risk for the debt, which is secured by the fixed rate electric capacity contract and $1.6 million of funds held in a trust account.

Fair Value

3 Months Ended

Mar. 31, 2012

Fair Value [Abstract]

Fair Value

NOTE 9. FAIR VALUE

The carrying values of cash and cash equivalents, accounts and notes receivable, accounts payable and short-term borrowings are reasonable estimates of their fair values. Long-term debt (including current portion, but excluding capital leases), nonrecourse long-term debt and long-term debt to affiliated trusts are reported at carrying value on the Condensed Consolidated Balance Sheets.

The fair value hierarchy prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement).

The three levels of the fair value hierarchy are defined as follows:

Level 1 – Quoted prices are available in active markets for identical assets or liabilities. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace.

Level 3 – Pricing inputs include significant inputs that are generally unobservable from objective sources. These inputs may be used with internally developed methodologies that result in management's best estimate of fair value.

Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company's assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values incorporates various factors that not only include the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits and letters of credit), but also the impact of Avista Corp.'s nonperformance risk on its liabilities.

The following table sets forth the carrying value and estimated fair value of the Company's financial instruments not reported at estimated fair value on the Condensed Consolidated Balance Sheets as of March 31, 2012 and December 31, 2011 (dollars in thousands):


	March 31, 2012				December 31, 2011
	Carrying Value		Estimated Fair Value		Carrying Value		Estimated Fair Value
Long-term debt (Level 2)	$	962,100	$	1,099,091	$	962,100	$	1,135,536
Long-term debt (Level 3)		222,000		232,748		222,000		234,226
Nonrecourse long-term debt (Level 3)		43,165		48,227		46,471		51,974
Long-term debt to affiliated trusts (Level 3)		51,547		43,810		51,547		43,810

These estimates of fair value of long-term debt and long-term debt to affiliated trusts were primarily based on available market information. The Company's publicly held long-term debt was classified as Level 2 as the fair value was determined utilizing observable inputs in non-active markets. The Company's other long-term debt (including long-term debt to affiliated trusts and nonrecourse long-term debt) was classified as Level 3 as certain inputs used to determine the fair value are unobservable. In particular, due to the unique nature of the long-term fixed rate electric capacity contract securing the long-term debt of Spokane Energy (nonrecourse long-term debt), the estimated fair value of nonrecourse long-term debt was determined based on a discounted cash flow model using available market information.

The following table discloses by level within the fair value hierarchy the Company's assets and liabilities measured and reported on the Condensed Consolidated Balance Sheets as of March 31, 2012 and December 31, 2011 at fair value on a recurring basis (dollars in thousands):


	Level 1		Level 2		Level 3		Counterparty Netting (1)			Total
March 31, 2012
Assets:
Energy commodity derivatives	$	—	$	21,369	$	—	$	(16,904	)	$	4,465
Level 3 energy commodity derivatives:
Power exchange agreements		—		—		1,034		(1,034	)		—
Interest rate swaps		—		5,084		—		—			5,084
Investments and funds held for clients:
Cash and cash equivalents		58,385		—		—		—			58,385
Securities available for sale:
U.S. government agency		—		78,735		—		—			78,735
Municipal		—		5,364		—		—			5,364
Corporate fixed income – financial		—		11,738		—		—			11,738
Corporate fixed income – industrial		—		6,517		—		—			6,517
Corporate fixed income – utility		—		2,114		—		—			2,114
Certificate of deposits		—		1,510		—		—			1,510
Funds held in trust account of
Spokane Energy		1,600		—		—		—			1,600
Deferred compensation assets:
Fixed income securities (2)		2,142		—		—		—			2,142
Equity securities (2)		5,773		—		—		—			5,773

Total	$	67,900	$	132,431	$	1,034	$	(17,938	)	$	183,427

Liabilities:
Energy commodity derivatives	$	—	$	103,312	$	—	$	(16,904	)	$	86,408
Level 3 energy commodity derivatives:
Natural gas exchange agreements		—		—		2,354		—			2,354
Power exchange agreements		—		—		19,606		(1,034	)		18,572
Power option agreements		—		—		987		—			987
Foreign currency derivatives		—		25		—		—			25
Interest rate swaps		—		9,241		—		—			9,241

Total	$	—	$	112,578	$	22,947	$	(17,938	)	$	117,587


December 31, 2011
Assets:
Energy commodity derivatives	$	—	$	80,571	$	—	$	(79,247	)	$	1,324
Level 3 energy commodity derivatives:
Natural gas exchange agreements		—		—		956		(956	)		—
Power exchange agreements		—		—		4,674		(4,674	)		—
Foreign currency derivatives		—		32		—		—			32
Investments and funds held for clients:
Cash and cash equivalents		21,957		—		—		—			21,957
Securities available for sale:
U.S. government agency		—		74,893		—		—			74,893
Municipal		—		425		—		—			425
Corporate fixed income – financial		—		11,154		—		—			11,154
Corporate fixed income – industrial		—		6,518		—		—			6,518
Corporate fixed income – utility		—		2,092		—		—			2,092
Certificate of deposits		—		1,497		—		—			1,497
Funds held in trust account of Spokane Energy		1,600		—		—		—			1,600
Deferred compensation assets:
Fixed income securities (2)		2,116		—		—		—			2,116
Equity securities (2)		5,252		—		—		—			5,252

Total	$	30,925	$	177,182	$	5,630	$	(84,877	)	$	128,860


	Level 1		Level 2		Level 3		Counterparty Netting (1)			Total
Liabilities:
Energy commodity derivatives	$	—	$	177,743	$	—	$	(79,247	)	$	98,496
Level 3 energy commodity derivatives:
Natural gas exchange agreements		—		—		2,644		(956	)		1,688
Power exchange agreements		—		—		14,584		(4,674	)		9,910
Power option agreements		—		—		1,260		—			1,260
Interest rate swaps		—		18,895		—		—			18,895

Total	$	—	$	196,638	$	18,488	$	(84,877	)	$	130,249

(1)	The Company is permitted to net derivative assets and derivative liabilities with the same counterparty when a legally enforceable master netting agreement exists.

(2)	These assets are trading securities and are included in other intangibles, property and investments-net on the Condensed Consolidated Balance Sheets.

Avista Utilities enters into forward contracts to purchase or sell a specified amount of energy at a specified time, or during a specified period, in the future. These contracts are entered into as part of Avista Utilities' management of loads and resources and certain contracts are considered derivative instruments. The difference between the amount of derivative assets and liabilities disclosed in respective levels and the amount of derivative assets and liabilities disclosed on the Condensed Consolidated Balance Sheets is due to netting arrangements with certain counterparties. The Company uses quoted market prices and forward price curves to estimate the fair value of utility derivative commodity instruments included in Level 2. In particular, electric derivative valuations are performed using broker quotes, adjusted for periods in between quotable periods. Natural gas derivative valuations are estimated using New York Mercantile Exchange (NYMEX) pricing for similar instruments, adjusted for basin differences, using broker quotes. Where observable inputs are available for substantially the full term of the contract, the derivative asset or liability is included in Level 2.

For securities available for sale (held at Ecova) the Company uses a nationally recognized third party to obtain fair value and reviews these prices for accuracy using a variety of market tools and analysis. The Company's pricing vendor uses a generic model which uses standard inputs, including (listed in order of priority for use) benchmark yields, reported trades, broker/dealer quotes, issuer spreads, two-sided markets, benchmark securities, market bids/offers and other reference data. The pricing vendor also monitors market indicators, as well as industry and economic events. Further, the model uses Option Adjusted Spread and is a multidimensional relational model. All securities available for sale were deemed Level 2.

Deferred compensation assets and liabilities represent funds held by the Company in a Rabbi Trust for an executive deferral plan. These funds consist of actively traded equity and bond funds with quoted prices in active markets. The balance disclosed in the table above excludes cash and cash equivalents of $1.3 million as of March 31, 2012 and $1.3 million as of December 31, 2011.

Level 3 Fair Value

For power exchange agreements, the Company compares the Level 2 brokered quotes and forward price curves described above to an internally developed forward price which is based on the average operating and maintenance ("O&M") charges from four surrogate nuclear power plants around the country for the current year which ranged from $29.01 to $43.81 per MWh for an average of $36.73 per MWh. Because the nuclear power plant O&M charges are only known for one year, all forward years are estimated assuming an escalation factor of 5 percent per year through 2015 and 3 percent per year for 2016 to 2019. In addition to the forward price being estimated using unobservable inputs, the Company also estimates the volumes of the transactions that will take place in the future based on historical average transaction volumes and these range from 365,619 MWhs to 379,156 MWhs per delivery year (November to April). Significant increases or decreases in any of these inputs in isolation would result in a significantly higher or lower fair value measurement. Generally, a change in the current year O&M charges for the surrogate plants is accompanied by a directionally similar change in O&M charges in future years. There is generally not a correlation between external market prices and the O&M charges used to develop the internal forward price.

For power commodity option agreements, the Company uses the Black-Scholes-Merton valuation model to estimate the fair value and this model includes significant inputs not observable or corroborated in the market. These inputs include 1) the strike price (which is an internally derived price based on a combination of generation plant heat rate factors, natural gas market pricing, delivery and other O&M charges and range from $32.78 per MWh in 2012 to $73.76 per MWh in 2019), 2) estimated delivery volumes for years beyond 2012 which range from 254,328 MWhs in 2013 to 157,517 MWhs in 2019, and 3) volatility rates for periods beyond April 2015 which were estimated at 0.20 compared to a range of known volatilities of 0.44 for 2012 to 0.22 in April 2015. Significant increases or decreases in any of these inputs in isolation would result in a significantly higher or lower fair value measurement. Generally, changes in overall commodity market prices and volatility rates are accompanied by directionally similar changes in the strike price and volatility assumptions used in the calculation.

For natural gas commodity exchange agreements, the Company uses the same Level 2 brokered quotes described above; however, the Company also estimates the purchase and sales volumes (within contractual limits) as well as the timing of those transactions. Changing the timing of volume estimates changes the timing of purchases and sales impacting which brokered quote is used. Because the brokered quotes can vary significantly from period to period, the unobservable estimates of the timing and volume of transactions can have a significant impact on the calculated fair value. The range of forward prices for purchases was from a low of $2.65 per mmBTU to a high of $3.61 per mmBTU and the range for sales was a low of $2.95 per mmBTU to a high of $4.14 per mmBTU. The Company currently estimates volumes and timing of transactions based on a most likely scenario using historical data and these ranged from 53,546 mmBTUs to 620,000 mmBTUs for purchases and 140,000 mmBTUs to 310,000 mmBTUs for sales. Historically, the timing and volume of transactions have not been highly correlated with market prices and market volatility.

Refer to Note 5 for further discussion of the Company's energy commodity derivative assets and liabilities.

Avista Corp.'s risk management team and accounting team are responsible for developing the valuation methods described above and both groups report to the Chief Financial Officer. The valuation methods, the significant inputs, and the resulting fair values described above are reviewed on at least a quarterly basis by the risk management team and the accounting team to ensure they provide a reasonable estimate of fair value each reporting period.

The following table presents activity for net energy commodity derivative assets (liabilities) measured at fair value using significant unobservable inputs (Level 3) for the three months ended March 31, 2012 (dollars in thousands):


	Natural Gas Exchange Agreements			Power Exchange Agreements			Power Option Agreements			Total
Balance as of January 1, 2012	$	(1,688	)	$	(9,910	)	$	(1,260	)	$	(12,858	)
Total gains or losses (realized/unrealized):
Included in net income		—			—			—			—
Included in other comprehensive income		—			—			—			—
Included in regulatory assets/liabilities (1)		290			(10,914	)		273			(10,351	)
Purchases		—			—			—			—
Issuances		—			—			—			—
Settlements		(956	)		2,252			—			1,296
Transfers to other categories		—			—			—			—

Ending balance as of March 31, 2012	$	(2,354	)	$	(18,572	)	$	(987	)	$	(21,913	)


	Natural Gas Exchange Agreements		Power Exchange Agreements			Power Option Agreements			Total
Balance as of January 1, 2011	$	—	$	15,793		$	(2,334	)	$	13,459
Total gains or losses (realized/unrealized):
Included in net income		—		—			—			—
Included in other comprehensive income		—		—			—			—
Included in regulatory assets/liabilities (1)		—		(887	)		801			(86	)
Purchases		—		—			—			—
Issuances		—		—			—			—
Settlements		—		956			—			956
Transfers to other categories		—		—			—			—

Ending balance as of March 31, 2011	$	—	$	15,862		$	(1,533	)	$	14,329

(1)

The WUTC and the IPUC issued accounting orders authorizing Avista Utilities to offset commodity derivative assets or liabilities with a regulatory asset or liability. This accounting treatment is intended to defer the recognition of mark-to-market gains and losses on energy commodity transactions until the period of settlement. The orders provide for Avista Utilities to not recognize the unrealized gain or loss on utility derivative commodity instruments in the Condensed Consolidated Statements of Income. Realized gains or losses are recognized in the period of settlement, subject to approval for recovery through retail rates. Realized gains and losses, subject to regulatory approval, result in adjustments to retail rates through purchased gas cost adjustments, the ERM in Washington, the PCA mechanism in Idaho, and periodic general rates cases.

- Definition

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44A, 44B
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15C, 15D
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15A
-Subparagraph a-d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15B
-Subparagraph a, b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 3, 10, 14, 15
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 157
-Paragraph 32, 33, 34
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 159
-Paragraph 17-22, 27, 28
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19207-110258

Reference 9: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 21
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13537-108611

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 28
-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14064-108612

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13433-108611

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14172-108612

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 16
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Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
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+ Details

Earnings Per Common Share Attributable To Avista Corporation

3 Months Ended

Mar. 31, 2012

Earnings Per Common Share Attributable To Avista Corporation [Abstract]

Earnings Per Common Share Attributable To Avista Corporation

NOTE 10. EARNINGS PER COMMON SHARE ATTRIBUTABLE TO AVISTA CORPORATION

The following table presents the computation of basic and diluted earnings per common share attributable to Avista Corporation for the three months ended March 31 (in thousands, except per share amounts):


	2012		2011
Numerator:
Net income attributable to Avista Corporation	$	38,388	$	41,918
Subsidiary earnings adjustment for dilutive securities		—		(74	)

Adjusted net income attributable to Avista Corporation for computation of diluted earnings per common share	$	38,388	$	41,844

Denominator:
Weighted-average number of common shares outstanding-basic		58,581		57,342
Effect of dilutive securities:
Performance and restricted stock awards		344		12
Stock options		25		60

Weighted-average number of common shares outstanding-diluted		58,950		57,414

Potential shares excluded in calculation		—		—
Earnings per common share attributable to Avista Corporation:
Basic	$	0.66	$	0.73

Diluted	$	0.65	$	0.73

Commitments And Contingencies	3 Months Ended
Commitments And Contingencies	Mar. 31, 2012
Commitments And Contingencies [Abstract]
Commitments And Contingencies	NOTE 11. COMMITMENTS AND CONTINGENCIES In the course of its business, the Company becomes involved in various claims, controversies, disputes and other contingent matters, including the items described in this Note. Some of these claims, controversies, disputes and other contingent matters involve litigation or other contested proceedings. For all such matters, the Company intends to vigorously protect and defend its interests and pursue its rights. However, no assurance can be given as to the ultimate outcome of any particular matter because litigation and other contested proceedings are inherently subject to numerous uncertainties. For matters that affect Avista Utilities' operations, the Company intends to seek, to the extent appropriate, recovery of incurred costs through the ratemaking process. With respect to matters discussed in this Note relating to Avista Energy, any potential liabilities or refunds by Avista Energy remain the responsibility of Avista Corp. and/or its subsidiaries and were not assumed by the purchaser of Avista Energy's contracts and operations in 2007. *Federal Energy Regulatory Commission Inquiry* In April 2004, the Federal Energy Regulatory Commission (FERC) approved the contested Agreement in Resolution of Section 206 Proceeding (Agreement in Resolution) between Avista Corp. doing business as Avista Utilities, Avista Energy and the FERC's Trial Staff which stated that there was: (1) no evidence that any executives or employees of Avista Utilities or Avista Energy knowingly engaged in or facilitated any improper trading strategy during 2000 and 2001; (2) no evidence that Avista Utilities or Avista Energy engaged in any efforts to manipulate the western energy markets during 2000 and 2001; and (3) no finding that Avista Utilities or Avista Energy withheld relevant information from the FERC's inquiry into the western energy markets for 2000 and 2001 (Trading Investigation). The Attorney General of the State of California (California AG), the California Electricity Oversight Board, and the City of Tacoma, Washington challenged the FERC's decisions approving the Agreement in Resolution, which are now pending before the United States Court of Appeals for the Ninth Circuit (Ninth Circuit). In May 2004, the FERC provided notice that Avista Energy was no longer subject to an investigation reviewing certain bids above $250 per MW in the short-term energy markets operated by the California Independent System Operator (CalISO) and the California Power Exchange (CalPX) from May 1, 2000 to October 2, 2000 (Bidding Investigation). That matter is also pending before the Ninth Circuit, after the California AG, Pacific Gas & Electric (PG&E), Southern California Edison Company (SCE) and the California Public Utilities Commission (CPUC) filed petitions for review in 2005. Based on the FERC's order approving the Agreement in Resolution in the Trading Investigation and order denying rehearing requests, the Company does not expect that this proceeding will have any material effect on its financial condition, results of operations or cash flows. Furthermore, based on information currently known to the Company regarding the Bidding Investigation and the fact that the FERC Staff did not find any evidence of manipulative behavior, the Company does not expect that this matter will have a material effect on its financial condition, results of operations or cash flows. *California Refund Proceeding* In July 2001, the FERC ordered an evidentiary hearing to determine the amount of refunds due to California energy buyers for purchases made in the spot markets operated by the CalISO and the CalPX during the period from October 2, 2000 to June 20, 2001 (Refund Period). Proposed refunds are based on the calculation of mitigated market clearing prices for each hour. The FERC ruled that if the refunds required by the formula would cause a seller to recover less than its actual costs for the Refund Period, sellers may document these costs and limit their refund liability commensurately. In September 2005, Avista Energy submitted its cost filing claim pursuant to the FERC's August 2005 order. The filing was initially accepted by the FERC, but in March 2011, the FERC ordered Avista Energy to remove any return on equity in a compliance filing with the CalISO, which Avista Energy did in April 2011. A challenge to Avista Energy's cost filing by the California AG, the CPUC, PG&E and SCE was denied in July 2011 as a collateral attack on the FERC's prior orders accepting Avista Energy's cost filing. In July 2011, the California AG, the CPUC, PG&E and SCE filed a petition for review of the FERC's orders regarding Avista Energy's cost filing with the Ninth Circuit. The 2001 bankruptcy of PG&E resulted in a default on its payment obligations to the CalPX. As a result, Avista Energy has not been paid for all of its energy sales during the Refund Period. Those funds are now in escrow accounts and will not be released until the FERC issues an order directing such release in the California refund proceeding. The CalISO continues to work on its compliance filing for the Refund Period, which will show "who owes what to whom." In July 2011, the FERC accepted the preparatory rerun compliance filings by the CalPX and CalISO, and responded to the CalPX request for guidance on issues related to completing the final determination of "who owes what to whom." The FERC directed both the CalISO and the CalPX to prepare and submit to the FERC their final refund rerun compliance filings. The FERC's order also directs the CalPX to pay past due principal amounts to governmental entities. In February 2012, the FERC denied the challenges made to the July 2011 order by the California AG, the CPUC, PG&E and SCE. As of March 31, 2012, Avista Energy's accounts receivable outstanding related to defaulting parties in California were fully offset by reserves for uncollected amounts and funds collected from the defaulting parties. Many of the orders that the FERC has issued in the California refund proceedings were appealed to the Ninth Circuit. In October 2004, the Ninth Circuit ordered that briefing proceed in two rounds. The first round was limited to three issues: (1) which parties are subject to the FERC's refund jurisdiction in light of the exemption for government-owned utilities in section 201(f) of the FPA; (2) the temporal scope of refunds under section 206 of the FPA; and (3) which categories of transactions are subject to refunds. The second round of issues and their corresponding briefing schedules have not yet been set by the Ninth Circuit. In September 2005, the Ninth Circuit held that the FERC did not have the authority to order refunds for sales made by municipal utilities in the California refund proceeding. In August 2006, the Ninth Circuit upheld October 2, 2000 as the refund effective date for the FPA section 206 refund proceeding, but remanded to the FERC its decision not to consider an FPA section 309 remedy for tariff violations prior to that date. A FERC hearing on that issue commenced in April 2012. A May 2011 FERC order denied a motion filed by Avista Energy and Avista Utilities asking that the companies be dismissed from any further proceedings involving alleged tariff violations under FPA section 309. Avista Energy and Avista Utilities sought rehearing of that ruling in June 2011. As noted above, in Docket No. EL02-115, Avista Energy and Avista Utilities were absolved of any wrongdoing related to allegations of tariff violations during 2000 and 2001 and have argued that the doctrines of res judicata and collateral estoppel preclude relitigation of the same issues. The California AG, the CPUC, PG&E and SCE also filed for rehearing of the FERC's May 2011 order, arguing that it improperly denies them a market-wide remedy for the pre-refund period. They also filed a petition for review of the May 2011 order with the Ninth Circuit. Because the resolution of the California refund proceeding remains uncertain, legal counsel cannot express an opinion on the extent of the Company's liability, if any. However, based on information currently known, the Company does not expect that the refunds ultimately ordered for the Refund Period would result in a material loss. This is primarily due to the fact that the FERC orders have stated that any refunds will be netted against unpaid amounts owed to the respective parties and the Company does not believe that refunds would exceed unpaid amounts owed to the Company. *Pacific Northwest Refund Proceeding* In July 2001, the FERC initiated a preliminary evidentiary hearing to develop a factual record as to whether prices for spot market sales of wholesale energy in the Pacific Northwest between December 25, 2000 and June 20, 2001 were just and reasonable. In June 2003, the FERC terminated the Pacific Northwest refund proceedings, after finding that the equities do not justify the imposition of refunds. In August 2007, the Ninth Circuit found that the FERC, in denying the request for refunds, had failed to take into account new evidence of market manipulation in the California energy market and its potential ties to the Pacific Northwest energy market and that such failure was arbitrary and capricious and, accordingly, remanded the case to the FERC, stating that the FERC's findings must be reevaluated in light of the evidence. In addition, the Ninth Circuit concluded that the FERC abused its discretion in denying potential relief for transactions involving energy that was purchased by the California Department of Water Resources (CERS) in the Pacific Northwest and ultimately consumed in California. The Ninth Circuit expressly declined to direct the FERC to grant refunds. The Ninth Circuit denied petitions for rehearing by various parties, and remanded the case to the FERC in April 2009. On October 3, 2011, the FERC issued an Order on Remand, finding that, in light of the Ninth Circuit's remand order, additional procedures are needed to address possible unlawful activity that may have influenced prices in the Pacific Northwest spot market during the period from December 25, 2000 through June 20, 2001. The Order establishes an evidentiary, trial-type hearing before an Administrative Law Judge (ALJ), and reopens the record to permit parties to present evidence of unlawful market activity during the relevant period. The Order also allows participants to supplement the record with additional evidence on CERS transactions in the Pacific Northwest spot market from January 18, 2001 to June 20, 2001. The Order states that parties seeking refunds must submit evidence demonstrating that specific unlawful market activity occurred, and must demonstrate that such activity directly affected the specific contract rate about which they complain. Simply alleging a general link between the dysfunctional spot market in California and the Pacific Northwest spot market will not be sufficient to establish a causal connection between a particular seller's alleged unlawful activities and the specific contract negotiations. A procedural schedule in this docket has not yet been set. Both Avista Utilities and Avista Energy were buyers and sellers of energy in the Pacific Northwest energy market during the period between December 25, 2000 and June 20, 2001 and, are subject to potential claims in this proceeding, and if refunds are ordered by the FERC with regard to any particular contract, could be liable to make payments. The Company cannot predict the outcome of this proceeding or the amount of any refunds that Avista Utilities or Avista Energy could be ordered to make. Therefore, the Company cannot predict the potential impact the outcome of this matter could ultimately have on the Company's results of operations, financial condition or cash flows. *California Attorney General Complaint (the "Lockyer Complaint")* In May 2002, the FERC conditionally dismissed a complaint filed in March 2002 by the California AG that alleged violations of the FPA by the FERC and all sellers (including Avista Corp. and its subsidiaries) of electric power and energy into California. The complaint alleged that the FERC's adoption and implementation of market-based rate authority was flawed and, as a result, individual sellers should refund the difference between the rate charged and a just and reasonable rate. In May 2002, the FERC issued an order dismissing the complaint. In September 2004, the Ninth Circuit upheld the FERC's market-based rate authority, but held that the FERC erred in ruling that it lacked authority to order refunds for violations of its reporting requirement. The Court remanded the case for further proceedings. In March 2008, the FERC issued an order establishing a trial-type hearing to address "whether any individual public utility seller's violation of the FERC's market-based rate quarterly reporting requirement led to an unjust and unreasonable rate for that particular seller in California during the 2000-2001 period." Purchasers in the California markets were given the opportunity to present evidence that "any seller that violated the quarterly reporting requirement failed to disclose an increased market share sufficient to give it the ability to exercise market power and thus cause its market-based rates to be unjust and unreasonable." In March 2010, the Presiding ALJ granted the motions for summary disposition and found that a hearing was "unnecessary" because the California AG, CPUC, PG&E and SCE "failed to apply the appropriate test to determine market power during the relevant time period." The judge determined that "[w]ithout a proper showing of market power, the California Parties failed to establish a prima facie case." In May 2011, the FERC affirmed "in all respects" the ALJ's decision. In June 2011, the California AG, CPUC, PG&E and SCE filed for rehearing of that order. Based on information currently known to the Company's management, and the ALJ's granting of Avista Utilities and Avista Energy's summary disposition motion, the Company does not expect that this matter will have a material effect on its financial condition, results of operations or cash flows. *Colstrip Generating Project Complaint* In March 2007, two families that own property near the holding ponds from Units 3 & 4 of the Colstrip Generating Project (Colstrip) filed a complaint against the owners of Colstrip and Hydrometrics, Inc. in Montana District Court. Avista Corp. owns a 15 percent interest in Units 3 & 4 of Colstrip. The plaintiffs allege that the holding ponds and remediation activities have adversely impacted their property. They allege contamination, decrease in water tables, reduced flow of streams on their property and other similar impacts to their property. They also seek punitive damages, attorney's fees, an order by the court to remove certain ponds, and the forfeiture of profits earned from the generation of Colstrip. In September 2010, the owners of Colstrip filed a motion with the court to enforce a settlement agreement that would resolve all issues between the parties. In October 2011, the court issued an order, which enforces the settlement agreement. The plaintiffs have subsequently appealed the court's decision. Under the settlement, Avista Corp.'s portion of payment (which was accrued in 2010) to the plaintiffs was not material to its financial condition, results of operations or cash flows. Although the final resolution of this complaint remains uncertain, based on information currently known to the Company's management, the Company does not expect this complaint will have a material effect on its financial condition, results of operations or cash flows. *Harbor Oil Inc. Site* Avista Corp. used Harbor Oil Inc. (Harbor Oil) for the recycling of waste oil and non-PCB transformer oil in the late 1980s and early 1990s. In June 2005, the Environmental Protection Agency (EPA) Region 10 provided notification to Avista Corp. and several other parties, as customers of Harbor Oil, that the EPA had determined that hazardous substances were released at the Harbor Oil site in Portland, Oregon and that Avista Corp. and several other parties may be liable for investigation and cleanup of the site under the Comprehensive Environmental Response, Compensation, and Liability Act, commonly referred to as the federal "Superfund" law, which provides for joint and several liability. The initial indication from the EPA is that the site may be contaminated with PCBs, petroleum hydrocarbons, chlorinated solvents and heavy metals. Six potentially responsible parties, including Avista Corp., signed an Administrative Order on Consent with the EPA on May 31, 2007 to conduct a remedial investigation and feasibility study (RI/FS). The draft final RI/FS was submitted to the EPA in December 2011 and was accepted as pre-final in March 2012. The EPA indicated in their approval letter that they intend to recommend a finding of No Further Action later in 2012. The actual cleanup, if any, will not occur until the RI/FS is finalized and approved by the EPA. Based on the review of its records related to Harbor Oil, the Company does not believe it is a major contributor to this potential environmental contamination based on the small volume of waste oil it delivered to the Harbor Oil site. As such, the Company does not expect that this matter will have a material effect on its financial condition, results of operations or cash flows. The Company has expensed its share of the RI/FS ($0.5 million) for this matter. *Spokane River Licensing* The Company owns and operates six hydroelectric plants on the Spokane River. Five of these (Long Lake, Nine Mile, Upper Falls, Monroe Street, and Post Falls) are regulated under one 50-year FERC license issued in June 2009 and are referred to as the Spokane River Project. The sixth, Little Falls, is operated under separate Congressional authority and is not licensed by the FERC. The license incorporated the 4(e) conditions that were included in the December 2008 Settlement Agreement with the United States Department of Interior and the Coeur d'Alene Tribe, as well as the mandatory conditions that were agreed to in the Idaho 401 Water Quality Certifications and in the amended Washington 401 Water Quality Certification. As part of the Settlement Agreement with the Washington Department of Ecology (DOE), the Company has participated in the Total Maximum Daily Load (TMDL) process for the Spokane River and Lake Spokane, the reservoir created by Long Lake Dam. On May 20, 2010, the EPA approved the TMDL and on May 27, 2010, the DOE filed an amended 401 Water Quality Certification with the FERC for inclusion into the license. The amended 401 Water Quality Certification includes the Company's level of responsibility, as defined in the TMDL, for low dissolved oxygen levels in Lake Spokane. The Company has until May 27, 2012 to develop mitigation strategies to address the low levels of dissolved oxygen. It is not possible to provide cost estimates at this time because the mitigation measures have not been fully identified or approved by the DOE. On July 16, 2010, the City of Post Falls and the Hayden Area Regional Sewer Board filed an appeal with the United States District Court for the District of Idaho with respect to the EPA's approval of the TMDL. The Company, the City of Coeur d'Alene, Kaiser Aluminum and the Spokane River Keeper subsequently moved to intervene in the appeal. In September 2011, the EPA issued a stay to the litigation that will be in effect until either the permits are issued and all appeals and challenges are complete or the court lifts the stay. The EPA and the Idaho Department of Environmental Quality (Idaho DEQ) are preparing draft National Pollutant Discharge Elimination System permits and the 401 Water Quality Certifications for the Idaho dischargers, respectively, which once issued will be released for a 30-day public comment period. The IPUC and the WUTC approved the recovery of licensing costs through the general rate case settlements in 2009. The Company will continue to seek recovery, through the ratemaking process, of all operating and capitalized costs related to implementing the license for the Spokane River Project. *Cabinet Gorge Total Dissolved Gas Abatement Plan* Dissolved atmospheric gas levels in the Clark Fork River exceed state of Idaho and federal water quality standards downstream of the Cabinet Gorge Hydroelectric Generating Project (Cabinet Gorge) during periods when excess river flows must be diverted over the spillway. In 2002, the Company submitted a Gas Supersaturation Control Program (GSCP) to the Idaho DEQ and U.S. Fish and Wildlife Service (USFWS). This submission was part of the Clark Fork Settlement Agreement for licensing the use of Cabinet Gorge. The GSCP provided for the possible opening and modification of two diversion tunnels around Cabinet Gorge to allow streamflow to be diverted when flows are in excess of powerhouse capacity. In 2007, engineering studies determined that the tunnels would not sufficiently reduce Total Dissolved Gas (TDG). In consultation with the Idaho DEQ and the USFWS, the Company developed an addendum to the GSCP. The GSCP addendum abandons the concept to reopen the two diversion tunnels and requires the Company to evaluate a variety of different options to abate TDG. In March 2010, the FERC approved the GSCP addendum of preliminary design for alternative abatement measures. In the second quarter of 2011, the Company completed preliminary feasibility assessments for several alternative abatement measures and determined that two alternatives will be considered for continued development. Further analysis and review of these alternatives is expected to be completed through at least the middle of 2012. The Company will continue to seek recovery, through the ratemaking process, of all operating and capitalized costs related to this issue. *Fish Passage at Cabinet Gorge and Noxon Rapids* In 1999, the USFWS listed bull trout as threatened under the Endangered Species Act. The Clark Fork Settlement Agreement describes programs intended to help restore bull trout populations in the project area. Using the concept of adaptive management and working closely with the USFWS, the Company is evaluating the feasibility of fish passage at Cabinet Gorge and Noxon Rapids. The results of these studies led, in part, to the decision to move forward with development of permanent facilities, among other bull trout enhancement efforts. In 2009, the Company selected a contractor to design a permanent upstream passage facility at Cabinet Gorge. The Company anticipates that the design and cost estimates will be completed by the end of 2012 with construction taking place in 2013 and 2014. In January 2010, the USFWS revised its 2005 designation of critical habitat for the bull trout to include the lower Clark Fork River as critical habitat. The Company believes its ongoing efforts through the Clark Fork Settlement Agreement continue to effectively address issues related to bull trout. The Company will continue to seek recovery, through the ratemaking process, of all operating and capitalized costs related to fish passage at Cabinet Gorge and Noxon Rapids. *Aluminum Recycling Site* In October 2009, the Company (through its subsidiary Pentzer Venture Holdings II, Inc. (Pentzer)) received notice from the DOE proposing to find Pentzer liable for a release of hazardous substances under the Model Toxics Control Act, under Washington state law. Pentzer owns property that adjoins land owned by the Union Pacific Railroad (UPR). UPR leased their property to operators of a facility designated by the DOE as "Aluminum Recycling – Trentwood." Operators of the UPR property maintained piles of aluminum "black dross," which can be designated as a state-only dangerous waste in Washington State. In the course of its business, the operators placed a portion of the aluminum dross pile on the property owned by Pentzer. Pentzer does not believe it is a contributor to any environmental contamination associated with the dross pile, and submitted a response to the DOE's proposed findings in November 2009. In December 2009, Pentzer received notice from the DOE that it had been designated as a potentially liable party for any hazardous substances located on this site. UPR completed a RI/FS Work Plan in June 2010. At that time, UPR requested a contribution from Pentzer towards the cost of performing the RI/FS and also an access agreement to investigate the material deposited on the Pentzer property. Pentzer concluded an access agreement with UPR in October 2010. UPR completed the RI/FS during the fourth quarter of 2011. Based on information currently known to the Company's management, the Company does not expect this issue will have a material effect on its financial condition, results of operations or cash flows. *Damages from Fire in Stevens County, Washington* In August 2010, a fire in Stevens County, Washington occurred during a wind storm. The apparent cause of the fire may be a tree located outside of Avista Corp.'s right-of-way that came in contact with an electric line owned by Avista Corp. The fire area is a rural farm and timber landscape. The fire destroyed two residences and six outbuildings. The Company is not aware of any personal injuries resulting from the fire. Although no lawsuits have been filed, Avista Corp. has received several claims and it is possible that additional claims may be made and lawsuits may be filed against the Company. The Company has expensed its estimated liability for this matter, which was not material to its financial condition, results of operations or cash flows. Based on information currently known to the Company's management, the Company does not expect this complaint will have a material effect on its financial condition, results of operations or cash flows. *Other Contingencies* In the normal course of business, the Company has various other legal claims and contingent matters outstanding. The Company believes that any ultimate liability arising from these actions will not have a material impact on its financial condition, results of operations or cash flows. It is possible that a change could occur in the Company's estimates of the probability or amount of a liability being incurred. Such a change, should it occur, could be significant.

- Definition

The entire disclosure for commitments and contingencies.

+ References

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-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 14
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Reference 2: http://www.xbrl.org/2003/role/presentationRef
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+ Details

Information By Business Segments

3 Months Ended

Mar. 31, 2012

Information By Business Segments [Abstract]

Information By Business Segments

NOTE 12. INFORMATION BY BUSINESS SEGMENTS

The business segment presentation reflects the basis used by the Company's management to analyze performance and determine the allocation of resources. Avista Utilities' business is managed based on the total regulated utility operation. Ecova is a provider of facility information and cost management services for multi-site customers throughout North America. The Other category, which is not a reportable segment, includes Spokane Energy, other investments and operations of various subsidiaries, as well as certain other operations of Avista Capital. The following table presents information for each of the Company's business segments (dollars in thousands):


	Avista Utilities		Ecova			Other			Total Non- Utility			Intersegment Eliminations (1)			Total
For the three months ended March 31, 2012:
Operating revenues	$	405,910	$	37,010		$	9,787		$	46,797		$	(450	)	$	452,257
Resource costs		211,012		—			—			—			—			211,012
Other operating expenses		63,357		35,774			8,378			44,152			(450	)		107,059
Depreciation and amortization		27,318		2,836			168			3,004			—			30,322
Income (loss) from operations		79,081		(1,600	)		1,241			(359	)		—			78,722
Interest expense (2)		18,046		360			965			1,325			(94	)		19,277
Income taxes		21,726		(381	)		(207	)		(588	)		—			21,138
Net income attributable to Avista Corporation		39,477		(826	)		(263	)		(1,089	)		—			38,388
Capital expenditures		57,771		1,142			2			1,144			—			58,915
For the three months ended March 31, 2011:
Operating revenues	$	438,147	$	29,158		$	9,731		$	38,889		$	(450	)	$	476,586
Resource costs		248,121		—			—			—			—			248,121
Other operating expenses		59,682		24,008			7,688			31,696			(450	)		90,928
Depreciation and amortization		25,852		1,664			203			1,867			—			27,719
Income from operations		79,499		3,486			1,840			5,326			—			84,825
Interest expense (2)		17,356		11			1,597			1,608			(373	)		18,591
Income taxes		22,255		1,254			128			1,382			—			23,637
Net income attributable to Avista Corporation		40,117		1,707			94			1,801			—			41,918
Capital expenditures		49,654		315			159			474			—			50,128
Total Assets:
As of March 31, 2012	$	3,758,726	$	389,782		$	105,496		$	495,278		$	—		$	4,254,004
As of December 31, 2011	$	3,809,446	$	292,940		$	112,145		$	405,085		$	—		$	4,214,531

(1)	Intersegment eliminations reported as operating revenues and resource costs represent intercompany purchases and sales of electric capacity and energy. Intersegment eliminations reported as interest expense represent intercompany interest.

(2)	Including interest expense to affiliated trusts.

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 131
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
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+ Details

Summary Of Significant Accounting Policies (Policy)

3 Months Ended

Mar. 31, 2012

Summary Of Significant Accounting Policies [Abstract]

Nature Of Business

Nature of Business

Basis Of Reporting

Basis of Reporting

Taxes Other Than Income Taxes

Taxes Other Than Income Taxes


	2012		2011
Utility taxes	$	17,834	$	18,123

Other Expense (Income)-Net

Other Expense (Income) - Net

Other expense (income) - net consisted of the following items for the three months ended March 31 (dollars in thousands):


	2012			2011
Interest income	$	(275	)	$	(289	)
Interest on regulatory deferrals		(8	)		(45	)
Equity-related AFUDC		(843	)		(842	)
Net loss (gain) on investments		439			(103	)
Other expense		1,306			1,911

Total	$	619		$	632

Investments And Funds Held For Clients And Client Fund Obligations

Investments and Funds Held for Clients and Client Fund Obligations

Investments and funds held for clients as of March 31, 2012 are as follows (dollars in thousands):


	Amortized Cost		Unrealized Gain (Loss)			Fair Value
Cash and cash equivalents	$	58,385	$	—		$	58,385
Securities available for sale:
U.S. government agency		78,653		82			78,735
Municipal		5,373		(9	)		5,364
Corporate fixed income – financial		11,604		134			11,738
Corporate fixed income – industrial		6,463		54			6,517
Corporate fixed income – utility		2,082		32			2,114
Certificates of deposit		1,500		10			1,510

Total securities available for sale		105,675		303			105,978

Total investments and funds held for clients	$	164,060	$	303		$	164,363

Investments and funds held for clients as of December 31, 2011 are as follows (dollars in thousands):


	Amortized Cost		Unrealized Gain (Loss)			Fair Value
Cash and cash equivalents	$	21,957	$	—		$	21,957
Securities available for sale:
U.S. government agency		74,721		172			74,893
Municipal		425		—			425
Corporate fixed income – financial		11,139		15			11,154
Corporate fixed income – industrial		6,495		23			6,518
Corporate fixed income – utility		2,088		4			2,092
Certificates of deposit		1,500		(3	)		1,497

Total securities available for sale		96,368		211			96,579

Total investments and funds held for clients	$	118,325	$	211		$	118,536


	Due within 1 year		After 1 but within 5 years		After 5 but within 10 years		Total
March 31, 2012	$	1,459	$	38,703	$	65,816	$	105,978
December 31, 2011		425		55,126		41,028		96,579

Actual maturities may differ due to call or prepayment rights and the effective duration was 1.7 years as of March 31, 2012 and 1.3 years as of December 31, 2011.

Goodwill

Goodwill


	Ecova		Other		Accumulated Impairment Losses			Total
Balance as of December 31, 2011	$	33,799	$	12,979	$	(7,733	)	$	39,045
Goodwill acquired during the period		33,484		—		—			33,484
Adjustments		1,254		—		—			1,254

Balance as of the March 31, 2012	$	68,537	$	12,979	$	(7,733	)	$	73,783

Other Intangibles

Other Intangibles


	2012		2011
Other intangible amortization	$	2,097	$	900

The following table details the future estimated amortization expense related to Other Intangibles for each of the five years ending December 31 (dollars in thousands):


	2012		2013		2014		2015		2016
Estimated amortization expense	$	9,675	$	10,235	$	9,265	$	6,204	$	4,687

The gross carrying amount and accumulated amortization of Other Intangibles as of March 31, 2012 and December 31, 2011 are as follows (dollars in thousands):


	March 31, 2012			December 31, 2011
Client relationships	$	32,577		$	18,859
Software development costs		29,650			29,327
Other		4,735			3,065

Total other intangibles		66,962			51,251

Client relationships accumulated amortization		(4,255	)		(3,623	)
Software development costs accumulated amortization		(12,939	)		(12,016	)
Other accumulated amortization		(1,047	)		(990	)

Total accumulated amortization		(18,241	)		(16,629	)

Total other intangibles - net	$	48,721		$	34,622

Derivative Assets And Liabilities

Derivative Assets and Liabilities

Fair Value Measurements

Fair Value Measurements

Regulatory Deferred Charges And Credits

Regulatory Deferred Charges and Credits

The Company prepares its condensed consolidated financial statements in accordance with regulatory accounting practices because:

•

rates for regulated services are established by or subject to approval by independent third-party regulators,

•

the regulated rates are designed to recover the cost of providing the regulated services, and

•

in view of demand for the regulated services and the level of competition, it is reasonable to assume that rates can be charged to and collected from customers at levels that will recover costs.

•

required to write off its regulatory assets, and

•

precluded from the future deferral of costs not recovered through rates at the time such costs are incurred, even if the Company expected to recover such costs in the future.

Contingencies

Contingencies

Summary Of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2012

Summary Of Significant Accounting Policies [Abstract]

Utility Taxes


	2012		2011
Utility taxes	$	17,834	$	18,123

Other Expense (Income) - Net


	2012			2011
Interest income	$	(275	)	$	(289	)
Interest on regulatory deferrals		(8	)		(45	)
Equity-related AFUDC		(843	)		(842	)
Net loss (gain) on investments		439			(103	)
Other expense		1,306			1,911

Total	$	619		$	632

Investments And Funds Held For Clients

Investments and funds held for clients as of March 31, 2012 are as follows (dollars in thousands):


	Amortized Cost		Unrealized Gain (Loss)			Fair Value
Cash and cash equivalents	$	58,385	$	—		$	58,385
Securities available for sale:
U.S. government agency		78,653		82			78,735
Municipal		5,373		(9	)		5,364
Corporate fixed income – financial		11,604		134			11,738
Corporate fixed income – industrial		6,463		54			6,517
Corporate fixed income – utility		2,082		32			2,114
Certificates of deposit		1,500		10			1,510

Total securities available for sale		105,675		303			105,978

Total investments and funds held for clients	$	164,060	$	303		$	164,363

Investments and funds held for clients as of December 31, 2011 are as follows (dollars in thousands):


	Amortized Cost		Unrealized Gain (Loss)			Fair Value
Cash and cash equivalents	$	21,957	$	—		$	21,957
Securities available for sale:
U.S. government agency		74,721		172			74,893
Municipal		425		—			425
Corporate fixed income – financial		11,139		15			11,154
Corporate fixed income – industrial		6,495		23			6,518
Corporate fixed income – utility		2,088		4			2,092
Certificates of deposit		1,500		(3	)		1,497

Total securities available for sale		96,368		211			96,579

Total investments and funds held for clients	$	118,325	$	211		$	118,536

Contractual Maturities Of Securities Available For Sale


	Due within 1 year		After 1 but within 5 years		After 5 but within 10 years		Total
March 31, 2012	$	1,459	$	38,703	$	65,816	$	105,978
December 31, 2011		425		55,126		41,028		96,579

Goodwill


	Ecova		Other		Accumulated Impairment Losses			Total
Balance as of December 31, 2011	$	33,799	$	12,979	$	(7,733	)	$	39,045
Goodwill acquired during the period		33,484		—		—			33,484
Adjustments		1,254		—		—			1,254

Balance as of the March 31, 2012	$	68,537	$	12,979	$	(7,733	)	$	73,783

Other Intangible Amortization


	2012		2011
Other intangible amortization	$	2,097	$	900

Future Estimated Amortization Expense


	2012		2013		2014		2015		2016
Estimated amortization expense	$	9,675	$	10,235	$	9,265	$	6,204	$	4,687

Accumulated Amortization Of Other Intangibles


	March 31, 2012			December 31, 2011
Client relationships	$	32,577		$	18,859
Software development costs		29,650			29,327
Other		4,735			3,065

Total other intangibles		66,962			51,251

Client relationships accumulated amortization		(4,255	)		(3,623	)
Software development costs accumulated amortization		(12,939	)		(12,016	)
Other accumulated amortization		(1,047	)		(990	)

Total accumulated amortization		(18,241	)		(16,629	)

Total other intangibles - net	$	48,721		$	34,622

- Definition

Tabular disclosure of goodwill by reportable segment and in total. Disclosure details may include, but are not limited to, the carrying amount of goodwill, goodwill acquired during the year, goodwill impairment losses recognized, goodwill written-off due to the sale of a business unit, goodwill not yet allocated, and any other changes to goodwill.

+ References + Details

Redeemable Noncontrolling Interests And Subsidiary Acquisitions (Tables)

3 Months Ended

Mar. 31, 2012

Redeemable Noncontrolling Interests And Subsidiary Acquisitions [Abstract]

Redeemable Noncontrolling Interests


	March 31, 2012		December 31, 2011
Previous owners of Cadence Network	$	44,295	$	38,893
Stock options and other outstanding redeemable stock		13,338		12,916

Total redeemable noncontrolling interests	$	57,633	$	51,809

- Definition

Tabular disclosure of redeemable noncontrolling interest (as defined) included in the statement of financial position as either a liability or temporary equity. As of the date of the statement of financial position, such redeemable noncontrolling interest is currently redeemable, as defined, for cash or other assets of the entity at (1) at a fixed or determinable price on a fixed or determinable date, (2) at the option of the holder of the noncontrolling interest, or (3) upon occurrence of an event that is not solely within the control of the entity.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number D-98
-Paragraph 40
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number D-98
-Paragraph 41
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number D-98
-Paragraph 42
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number D-98
-Paragraph 43
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number D-98
-Paragraph 44
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 25
-Appendix A

+ Details

Derivatives And Risk Management (Tables)

3 Months Ended

Mar. 31, 2012

Derivatives And Risk Management [Abstract]

Energy Commodity Derivatives


	Purchases								Sales
	Electric Derivatives				Gas Derivatives				Electric Derivatives				Gas Derivatives
Year	Physical MWH		Financial MWH		Physical mmBTUs		Financial mmBTUs		Physical MWH		Financial MWH		Physical mmBTUs		Financial mmBTUs
2012		976		845		28,466		7,577		638		433		6,819		4,634
2013		537		245		11,895		10,270		310		491		1,533		1,727
2014		366		0		5,939		5,586		286		246		1,050		225
2015		379		—		3,013		980		285		—		—		—
2016		367		—		1,137		455		287		—		—		—
Thereafter		949		—		—		—		730		—		—		—

Foreign Currency Exchange Contracts


	March 31, 2012			December 31, 2011
Number of contracts		31			28
Notional amount (in United States dollars)	$	4,258		$	7,033
Notional amount (in Canadian dollars)		4,235			7,192
Derivatives in other current assets (liabilities)		(25	)		32

Interest Rate Swap Agreements


	March 31, 2012			December 31, 2011
Number of contracts		3			3
Notional amount	$	75,000		$	75,000
Mandatory cash settlement date		July 2012			July 2012
Current derivative liability		(9,241	)		(16,253	)
Number of contracts		2			2
Notional amount	$	85,000		$	85,000
Mandatory cash settlement date		June 2013			June 2013
Non-current derivative asset (liability)		5,084			(2,642	)

Derivative Instruments Summary

The following table presents the fair values and locations of derivative instruments recorded on the Condensed Consolidated Balance Sheet as of March 31, 2012 (in thousands):


		Fair Value
Derivative	Balance Sheet Location	Asset		Liability			Net Asset (Liability)
Foreign currency contracts	Other current liabilities	$	—	$	(25	)	$	(25	)
Interest rate contracts	Other current liabilities		—		(9,241	)		(9,241	)
Interest rate contracts	Other intangibles, property and Investments - net		5,084		—			5,084
Commodity contracts	Current utility energy commodity derivative assets		2,647		(365	)		2,282
Commodity contracts	Non-current utility energy commodity derivative assets		8,148		(5,965	)		2,183
Commodity contracts	Current utility energy commodity derivative liabilities		10,461		(84,065	)		(73,604	)
Commodity contracts	Other non-current liabilities and deferred credits		1,147		(35,864	)		(34,717	)

Total derivative instruments recorded on the balance sheet		$	27,487	$	(135,525	)	$	(108,038	)

The following table presents the fair values and locations of derivative instruments recorded on the Condensed Consolidated Balance Sheet as of December 31, 2011 (in thousands):


		Fair Value
Derivative	Balance Sheet Location	Asset		Liability			Net Asset (Liability)
Foreign currency contracts	Other current assets	$	32	$	—		$	32
Interest rate contracts	Other current liabilities		—		(16,253	)		(16,253	)
Interest rate contracts	Other non-current liabilities and deferred credits		—		(2,642	)		(2,642	)
Commodity contracts	Current utility energy commodity derivative assets		1,618		(479	)		1,139
Commodity contracts	Non-current utility energy commodity derivative assets		185		—			185
Commodity contracts	Current utility energy commodity derivative liabilities		40,090		(110,914	)		(70,824	)
Commodity contracts	Other non-current liabilities and deferred credits		44,308		(84,838	)		(40,530	)

Total derivative instruments recorded on the balance sheet		$	86,233	$	(215,126	)	$	(128,893	)

Pension Plans And Other Postretirement Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2012

Pension Plans And Other Postretirement Benefit Plans [Abstract]

Components Of Net Periodic Benefit Cost


	Pension Benefits						Other Post- retirement Benefits
	2012			2011			2012			2011
Service cost	$	3,791		$	2,942		$	689		$	227
Interest cost		6,109			6,109			1,281			919
Expected return on plan assets		(6,000	)		(5,591	)		(375	)		(443	)
Transition obligation recognition		—			—			126			126
Amortization of prior service cost		75			119			(38	)		(37	)
Net loss recognition		2,757			2,105			1,312			435

Net periodic benefit cost	$	6,732		$	5,684		$	2,995		$	1,227

Short-Term Borrowings (Tables)

3 Months Ended

Mar. 31, 2012

Line of Credit Facility [Line Items]

Schedule Of Balances Outstanding And Interest Rates Of Borrowings


	March 31, 2012			December 31, 2011
Balance outstanding at end of period	$	37,000		$	61,000
Letters of credit outstanding at end of period	$	20,090		$	29,030
Average interest rate at end of period		3.25	%		1.12	%

Ecova [Member]

Line of Credit Facility [Line Items]

Schedule Of Balances Outstanding And Interest Rates Of Borrowings


	March 31, 2012			December 31, 2011
Balance outstanding at end of period	$	60,000		$	35,000
Average interest rate at end of period		2.25	%		2.38	%

Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2012

Long-Term Debt [Abstract]

Schedule Of Long-Term Debt Instruments


Maturity Year	Description	Interest Rate	March 31, 2012			December 31, 2011
2012	Secured Medium-Term Notes	7.37%	$	7,000		$	7,000
2013	First Mortgage Bonds	1.68%		50,000			50,000
2018	First Mortgage Bonds	5.95%		250,000			250,000
2018	Secured Medium-Term Notes	7.39%-7.45%		22,500			22,500
2019	First Mortgage Bonds	5.45%		90,000			90,000
2020	First Mortgage Bonds	3.89%		52,000			52,000
2022	First Mortgage Bonds	5.13%		250,000			250,000
2023	Secured Medium-Term Notes	7.18%-7.54%		13,500			13,500
2028	Secured Medium-Term Notes	6.37%		25,000			25,000
2032	Secured Pollution Control Bonds (1)	(1)		66,700			66,700
2034	Secured Pollution Control Bonds (2)	(2)		17,000			17,000
2035	First Mortgage Bonds	6.25%		150,000			150,000
2037	First Mortgage Bonds	5.70%		150,000			150,000
2040	First Mortgage Bonds	5.55%		35,000			35,000
2041	First Mortgage Bonds	4.45%		85,000			85,000

	Total secured long-term debt			1,263,700			1,263,700
2023	Unsecured Pollution Control Bonds	6.00%		4,100			4,100
	Other long-term debt and capital leases			5,389			5,455
	Settled interest rate swaps			(10,321	)		(10,629	)
	Unamortized debt discount			(1,584	)		(1,626	)

	Total			1,261,284			1,261,000
	Secured Pollution Control Bonds held by Avista Corporation (1) (2)			(83,700	)		(83,700	)
	Current portion of long-term debt			(7,409	)		(7,474	)

	Total long-term debt		$	1,170,175		$	1,169,826

(1)

(2)

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 22
-Article 5

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28551-108399

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28541-108399

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21538-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21521-112644

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6584090&loc=d3e28878-108400

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6479336&loc=d3e64711-112823

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(e),(f))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

+ Details

Fair Value (Tables)

3 Months Ended

Mar. 31, 2012

Fair Value [Abstract]

Carrying Value And Estimated Fair Value Of Financial Instruments


	March 31, 2012				December 31, 2011
	Carrying Value		Estimated Fair Value		Carrying Value		Estimated Fair Value
Long-term debt (Level 2)	$	962,100	$	1,099,091	$	962,100	$	1,135,536
Long-term debt (Level 3)		222,000		232,748		222,000		234,226
Nonrecourse long-term debt (Level 3)		43,165		48,227		46,471		51,974
Long-term debt to affiliated trusts (Level 3)		51,547		43,810		51,547		43,810

Fair Value Of Assets And Liabilities Measured On Recurring Basis


	Level 1		Level 2		Level 3		Counterparty Netting (1)			Total
March 31, 2012
Assets:
Energy commodity derivatives	$	—	$	21,369	$	—	$	(16,904	)	$	4,465
Level 3 energy commodity derivatives:
Power exchange agreements		—		—		1,034		(1,034	)		—
Interest rate swaps		—		5,084		—		—			5,084
Investments and funds held for clients:
Cash and cash equivalents		58,385		—		—		—			58,385
Securities available for sale:
U.S. government agency		—		78,735		—		—			78,735
Municipal		—		5,364		—		—			5,364
Corporate fixed income – financial		—		11,738		—		—			11,738
Corporate fixed income – industrial		—		6,517		—		—			6,517
Corporate fixed income – utility		—		2,114		—		—			2,114
Certificate of deposits		—		1,510		—		—			1,510
Funds held in trust account of
Spokane Energy		1,600		—		—		—			1,600
Deferred compensation assets:
Fixed income securities (2)		2,142		—		—		—			2,142
Equity securities (2)		5,773		—		—		—			5,773

Total	$	67,900	$	132,431	$	1,034	$	(17,938	)	$	183,427

Liabilities:
Energy commodity derivatives	$	—	$	103,312	$	—	$	(16,904	)	$	86,408
Level 3 energy commodity derivatives:
Natural gas exchange agreements		—		—		2,354		—			2,354
Power exchange agreements		—		—		19,606		(1,034	)		18,572
Power option agreements		—		—		987		—			987
Foreign currency derivatives		—		25		—		—			25
Interest rate swaps		—		9,241		—		—			9,241

Total	$	—	$	112,578	$	22,947	$	(17,938	)	$	117,587


December 31, 2011
Assets:
Energy commodity derivatives	$	—	$	80,571	$	—	$	(79,247	)	$	1,324
Level 3 energy commodity derivatives:
Natural gas exchange agreements		—		—		956		(956	)		—
Power exchange agreements		—		—		4,674		(4,674	)		—
Foreign currency derivatives		—		32		—		—			32
Investments and funds held for clients:
Cash and cash equivalents		21,957		—		—		—			21,957
Securities available for sale:
U.S. government agency		—		74,893		—		—			74,893
Municipal		—		425		—		—			425
Corporate fixed income – financial		—		11,154		—		—			11,154
Corporate fixed income – industrial		—		6,518		—		—			6,518
Corporate fixed income – utility		—		2,092		—		—			2,092
Certificate of deposits		—		1,497		—		—			1,497
Funds held in trust account of Spokane Energy		1,600		—		—		—			1,600
Deferred compensation assets:
Fixed income securities (2)		2,116		—		—		—			2,116
Equity securities (2)		5,252		—		—		—			5,252

Total	$	30,925	$	177,182	$	5,630	$	(84,877	)	$	128,860


	Level 1		Level 2		Level 3		Counterparty Netting (1)			Total
Liabilities:
Energy commodity derivatives	$	—	$	177,743	$	—	$	(79,247	)	$	98,496
Level 3 energy commodity derivatives:
Natural gas exchange agreements		—		—		2,644		(956	)		1,688
Power exchange agreements		—		—		14,584		(4,674	)		9,910
Power option agreements		—		—		1,260		—			1,260
Interest rate swaps		—		18,895		—		—			18,895

Total	$	—	$	196,638	$	18,488	$	(84,877	)	$	130,249

(1)	The Company is permitted to net derivative assets and derivative liabilities with the same counterparty when a legally enforceable master netting agreement exists.

(2)	These assets are trading securities and are included in other intangibles, property and investments-net on the Condensed Consolidated Balance Sheets.

Reconciliation For Energy Commodity Derivative Assets (Liabilities Measured At Fair Value On A Recurring Basis Using Significant Unobservable Inputs (Level 3)


	Natural Gas Exchange Agreements			Power Exchange Agreements			Power Option Agreements			Total
Balance as of January 1, 2012	$	(1,688	)	$	(9,910	)	$	(1,260	)	$	(12,858	)
Total gains or losses (realized/unrealized):
Included in net income		—			—			—			—
Included in other comprehensive income		—			—			—			—
Included in regulatory assets/liabilities (1)		290			(10,914	)		273			(10,351	)
Purchases		—			—			—			—
Issuances		—			—			—			—
Settlements		(956	)		2,252			—			1,296
Transfers to other categories		—			—			—			—

Ending balance as of March 31, 2012	$	(2,354	)	$	(18,572	)	$	(987	)	$	(21,913	)


	Natural Gas Exchange Agreements		Power Exchange Agreements			Power Option Agreements			Total
Balance as of January 1, 2011	$	—	$	15,793		$	(2,334	)	$	13,459
Total gains or losses (realized/unrealized):
Included in net income		—		—			—			—
Included in other comprehensive income		—		—			—			—
Included in regulatory assets/liabilities (1)		—		(887	)		801			(86	)
Purchases		—		—			—			—
Issuances		—		—			—			—
Settlements		—		956			—			956
Transfers to other categories		—		—			—			—

Ending balance as of March 31, 2011	$	—	$	15,862		$	(1,533	)	$	14,329

(1)

- Definition

Tabular disclosure of the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments, assets, and liabilities. Such certain disclosures about the financial instruments, assets, and liabilities include: (1) the fair value of the required items together with their carrying amounts (as appropriate) and (2) the methodology and assumptions used in developing such estimates of fair value.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 10
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 14
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15
-Subparagraph b-d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 157
-Paragraph 32
-Subparagraph a, c(1), c(2), c(3), d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 159
-Paragraph 18
-Subparagraph c(2), d, e, f
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 159
-Paragraph 19
-Subparagraph a, b, c(1), d(1)
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 10
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13433-108611

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13467-108611

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13476-108611

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 30
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14172-108612

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 2
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19207-110258

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6447952&loc=d3e13220-108610

+ Details

- Definition

Tabular disclosure of the fair value measurement of liabilities using significant unobservable inputs (Level 3), a reconciliation of the beginning and ending balances, separately presenting changes during the period attributable to the following: (1) total gains or losses for the period (realized and unrealized), segregating those gains or losses included in earnings (or changes in net assets), and gains or losses recognized in other comprehensive income and a description of where those gains or losses included in earnings (or changes in net assets) are reported in the statement of income (or activities); (2) purchases, sales, issuances, and settlements (each type disclosed separately); and (3) transfers in and transfers out of Level 3 (for example, transfers due to changes in the observability of significant inputs) by class of liability.

+ References + Details

- Definition

Tabular disclosure of the fair value measurement of assets and liabilities which includes [financial] instruments measured at fair value that are classified in stockholders' equity. Such assets and liabilities may be measured on a recurring or nonrecurring basis. The disclosures which may be required or desired include: (1) for assets and liabilities measured on a recurring basis, disclosure may include: (a) the fair value measurements at the reporting date; (b) the level within the fair value hierarchy in which the fair value measurements in their entirety fall, segregating fair value measurements using quoted prices in active markets for identical assets or liabilities (Level 1), significant other observable inputs (Level 2), and significant unobservable inputs (Level 3); (c) for fair value measurements using significant unobservable inputs (Level 3), a reconciliation of the beginning and ending balances, separately presenting changes during the period attributable to the following: (i) total gains or losses for the period (realized and unrealized), segregating those gains or losses included in earnings (or changes in net assets), and a description of where those gains or losses included in earnings (or changes in net assets) are reported in the statement of income (or activities); (ii) purchases, sales, issuances, and settlements (net); (iii) transfers in and transfers out of Level 3 (for example, transfers due to changes in the observability of significant inputs); (d) the amount of the total gains or losses for the period in subparagraph (c) (i) above included in earnings (or changes in net assets) that are attributable to the change in unrealized gains or losses relating to those assets and liabilities still held at the reporting date and a description of where those unrealized gains or losses are reported in the statement of income (or activities); (e) the valuation technique(s) used to measure fair value and a discussion of changes in valuation techniques, if any, during the period and (2) for assets and liabilities that are measured at fair value on a nonrecurring basis (for example, impaired assets) disclosure may include, in addition to (a) above: (a) the reasons for the fair value measurements recorded; (b) the same as (b) above; (c) for fair value measurements using significant unobservable inputs (Level 3), a description of the inputs and the information used to develop the inputs; and (d) the valuation technique(s) used to measure fair value and a discussion of changes, if any, in the valuation technique(s) used to measure similar assets and/or liabilities in prior periods. Where the quoted price in an active market for the identical liability is not available, the Level 1 input is the quoted price of an identical liability when traded as an asset.

+ References

+ Details

Earnings Per Common Share Attributable To Avista Corporation (Tables)

3 Months Ended

Mar. 31, 2012

Earnings Per Common Share Attributable To Avista Corporation [Abstract]

Computation Of Basic And Diluted Earnings Per Common Share


	2012		2011
Numerator:
Net income attributable to Avista Corporation	$	38,388	$	41,918
Subsidiary earnings adjustment for dilutive securities		—		(74	)

Adjusted net income attributable to Avista Corporation for computation of diluted earnings per common share	$	38,388	$	41,844

Denominator:
Weighted-average number of common shares outstanding-basic		58,581		57,342
Effect of dilutive securities:
Performance and restricted stock awards		344		12
Stock options		25		60

Weighted-average number of common shares outstanding-diluted		58,950		57,414

Potential shares excluded in calculation		—		—
Earnings per common share attributable to Avista Corporation:
Basic	$	0.66	$	0.73

Diluted	$	0.65	$	0.73

Information By Business Segments (Tables)

3 Months Ended

Mar. 31, 2012

Information By Business Segments [Abstract]

Information By Business Segments


	Avista Utilities		Ecova			Other			Total Non- Utility			Intersegment Eliminations (1)			Total
For the three months ended March 31, 2012:
Operating revenues	$	405,910	$	37,010		$	9,787		$	46,797		$	(450	)	$	452,257
Resource costs		211,012		—			—			—			—			211,012
Other operating expenses		63,357		35,774			8,378			44,152			(450	)		107,059
Depreciation and amortization		27,318		2,836			168			3,004			—			30,322
Income (loss) from operations		79,081		(1,600	)		1,241			(359	)		—			78,722
Interest expense (2)		18,046		360			965			1,325			(94	)		19,277
Income taxes		21,726		(381	)		(207	)		(588	)		—			21,138
Net income attributable to Avista Corporation		39,477		(826	)		(263	)		(1,089	)		—			38,388
Capital expenditures		57,771		1,142			2			1,144			—			58,915
For the three months ended March 31, 2011:
Operating revenues	$	438,147	$	29,158		$	9,731		$	38,889		$	(450	)	$	476,586
Resource costs		248,121		—			—			—			—			248,121
Other operating expenses		59,682		24,008			7,688			31,696			(450	)		90,928
Depreciation and amortization		25,852		1,664			203			1,867			—			27,719
Income from operations		79,499		3,486			1,840			5,326			—			84,825
Interest expense (2)		17,356		11			1,597			1,608			(373	)		18,591
Income taxes		22,255		1,254			128			1,382			—			23,637
Net income attributable to Avista Corporation		40,117		1,707			94			1,801			—			41,918
Capital expenditures		49,654		315			159			474			—			50,128
Total Assets:
As of March 31, 2012	$	3,758,726	$	389,782		$	105,496		$	495,278		$	—		$	4,254,004
As of December 31, 2011	$	3,809,446	$	292,940		$	112,145		$	405,085		$	—		$	4,214,531

(1)	Intersegment eliminations reported as operating revenues and resource costs represent intercompany purchases and sales of electric capacity and energy. Intersegment eliminations reported as interest expense represent intercompany interest.

(2)	Including interest expense to affiliated trusts.

- Definition

Tabular disclosure of the profit or loss and total assets for each reportable segment. An entity discloses certain information on each reportable segment if the amounts (a) are included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) are otherwise regularly provided to the chief operating decision maker, even if not included in that measure of segment profit or loss.

+ References + Details

Summary Of Significant Accounting Policies (Narrative) (Details) - yr	3 Months Ended	12 Months Ended
	Mar. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Summary Of Significant Accounting Policies [Line Items]
Average effective maturity, in years	1.7	1.3
Investment portfolio percentage rated AA or higher	92.00%	88.00%
Ecova [Member]
Summary Of Significant Accounting Policies [Line Items]
Owners percentage interest	79.20%
Cadence Network [Member]
Summary Of Significant Accounting Policies [Line Items]
Intangible assets amortization period, years					12
Ecos [Member]
Summary Of Significant Accounting Policies [Line Items]
Intangible assets amortization period, years				3
Prenova [Member]
Summary Of Significant Accounting Policies [Line Items]
Intangible assets amortization period, years		9
The Loyalton Group [Member]
Summary Of Significant Accounting Policies [Line Items]
Intangible assets amortization period, years			6
Minimum [Member] \| Software Development Costs [Member]
Summary Of Significant Accounting Policies [Line Items]
Intangible assets amortization period, years		3
Minimum [Member] \| LPB [Member]
Summary Of Significant Accounting Policies [Line Items]
Intangible assets amortization period, years	3
Maximum [Member] \| Software Development Costs [Member]
Summary Of Significant Accounting Policies [Line Items]
Intangible assets amortization period, years		7
Maximum [Member] \| LPB [Member]
Summary Of Significant Accounting Policies [Line Items]
Intangible assets amortization period, years	10

Summary Of Significant Accounting Policies (Utility Taxes) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Summary Of Significant Accounting Policies [Abstract]
Utility taxes	$ 17,834	$ 18,123

Summary Of Significant Accounting Policies (Other Expense (Income) - Net) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Summary Of Significant Accounting Policies [Abstract]
Interest income	$ (275)	$ (289)
Interest on regulatory deferrals	(8)	(45)
Equity-related AFUDC	(843)	(842)
Net loss (gain) on investments	439	(103)
Other expense	1,306	1,911
Total	$ 619	$ 632

- Definition

This item represents the net total realized and unrealized gain (loss) included in earnings for the period as a result of selling or holding marketable securities categorized as trading, available-for-sale, or held-to-maturity, including the unrealized holding gain (loss) of held-to-maturity securities transferred to the trading security category and the cumulative unrealized gain (loss) which was included in other comprehensive income (a separate component of shareholders' equity) for available-for-sale securities transferred to trading securities during the period. Additionally, this item would include any gains (losses) realized during the period from the sale of investments accounted for under the cost method of accounting and losses recognized for other than temporary impairments (OTTI) of the subject investments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 95
-Paragraph 28
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 115
-Paragraph 13, 22
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Article 5
-Section 03
-Paragraph 7

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 230
-SubTopic 10
-Section 45
-Paragraph 28
-URI http://asc.fasb.org/extlink&oid=6943989&loc=d3e3602-108585

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 225
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03.7(c),9(a))
-URI http://asc.fasb.org/extlink&oid=6880815&loc=d3e20235-122688

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 320
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (c)-(e)
-URI http://asc.fasb.org/extlink&oid=6872113&loc=d3e27357-111563

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 320
-SubTopic 10
-Section 50
-Paragraph 10
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=6872113&loc=d3e27405-111563

+ Details

Summary Of Significant Accounting Policies (Investments And Funds Held For Clients) (Details) - USD ($) $ in Thousands	Mar. 31, 2012	Dec. 31, 2011
Schedule of Available-for-sale Securities [Line Items]
Cash and cash equivalents, Amortized Cost	$ 58,385	$ 21,957
Cash and cash equivalents, Unrealized Gain (Loss)
Cash and cash equivalents, Fair Value	58,385	21,957
Total securities available for sale, Amortized Cost	105,675	96,368
Total securities available for sale, Unrealized Gain (Loss)	303	211
Total securities available for sale, Fair Value	105,978	96,579
Total investments and funds held for clients, Amortized Cost	164,060	118,325
Total investments and funds held for clients, Unrealized Gain (Loss)	303	211
Total investments and funds held for clients, Fair Value	164,363	118,536
U.S. Government Agency [Member]
Schedule of Available-for-sale Securities [Line Items]
Total securities available for sale, Amortized Cost	78,653	74,721
Total securities available for sale, Unrealized Gain (Loss)	82	172
Total securities available for sale, Fair Value	78,735	74,893
Municipal [Member]
Schedule of Available-for-sale Securities [Line Items]
Total securities available for sale, Amortized Cost	5,373	425
Total securities available for sale, Unrealized Gain (Loss)	(9)
Total securities available for sale, Fair Value	5,364	425
Corporate Fixed Income - Financial [Member]
Schedule of Available-for-sale Securities [Line Items]
Total securities available for sale, Amortized Cost	11,604	11,139
Total securities available for sale, Unrealized Gain (Loss)	134	15
Total securities available for sale, Fair Value	11,738	11,154
Corporate Fixed Income - Industrial [Member]
Schedule of Available-for-sale Securities [Line Items]
Total securities available for sale, Amortized Cost	6,463	6,495
Total securities available for sale, Unrealized Gain (Loss)	54	23
Total securities available for sale, Fair Value	6,517	6,518
Corporate Fixed Income - Utility [Member]
Schedule of Available-for-sale Securities [Line Items]
Total securities available for sale, Amortized Cost	2,082	2,088
Total securities available for sale, Unrealized Gain (Loss)	32	4
Total securities available for sale, Fair Value	2,114	2,092
Certificates Of Deposit [Member]
Schedule of Available-for-sale Securities [Line Items]
Total securities available for sale, Amortized Cost	1,500	1,500
Total securities available for sale, Unrealized Gain (Loss)	10	(3)
Total securities available for sale, Fair Value	$ 1,510	$ 1,497

Summary Of Significant Accounting Policies (Contractual Maturities Of Securities Available For Sale) (Details) - USD ($) $ in Thousands	Mar. 31, 2012	Dec. 31, 2011
Summary Of Significant Accounting Policies [Abstract]
Due within 1 year	$ 1,459	$ 425
After 1 but within 5 years	38,703	55,126
After 5 but within 10 years	65,816	41,028
Total	$ 105,978	$ 96,579

Summary Of Significant Accounting Policies (Goodwill) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2012 USD ($)
Goodwill [Line Items]
Balance at beginning	$ 39,045
Goodwill acquired during the period	33,484
Adjustments	1,254
Balance at ending	73,783
Ecova [Member]
Goodwill [Line Items]
Balance at beginning	33,799
Goodwill acquired during the period	33,484
Adjustments	1,254
Balance at ending	68,537
Other [Member]
Goodwill [Line Items]
Balance at beginning	12,979
Balance at ending	12,979
Accumulated Impairment Losses [Member]
Goodwill [Line Items]
Balance at beginning	(7,733)
Balance at ending	$ (7,733)

- Definition

Carrying amount as of the balance sheet date, which is the cumulative amount paid and (if applicable) the fair value of any noncontrolling interest in the acquiree, adjusted for any amortization recognized prior to the adoption of any changes in generally accepted accounting principles (as applicable) and for any impairment charges, in excess of the fair value of net assets acquired in one or more business combination transactions.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 142
-Paragraph 45
-Subparagraph e
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 142
-Paragraph 43
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 68
-Subparagraph l
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 350
-SubTopic 20
-Section 45
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6388280&loc=d3e13770-109266

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 350
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6905597&loc=d3e13816-109267

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 72
-Subparagraph d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 142
-Paragraph 45
-Subparagraph e
-Clause 1
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 34
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Summary Of Significant Accounting Policies (Other Intangible Amortization) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Summary Of Significant Accounting Policies [Abstract]
Other intangible amortization	$ 2,097	$ 900

Summary Of Significant Accounting Policies (Future Estimated Amortization Expense) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2012 USD ($)
Summary Of Significant Accounting Policies [Abstract]
2012	$ 9,675
2013	10,235
2014	9,265
2015	6,204
2016	$ 4,687

Summary Of Significant Accounting Policies (Accumulated Amortization Of Other Intangibles) (Details) - USD ($) $ in Thousands	Mar. 31, 2012	Dec. 31, 2011
Finite-Lived Intangible Assets [Line Items]
Client relationships	$ 32,577	$ 18,859
Software development costs	29,650	29,327
Other	4,735	3,065
Total other intangibles	66,962	51,251
Total accumulated amortization	(18,241)	(16,629)
Total other intangibles - net	48,721	34,622
Client Relationships Accumulated Amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Total accumulated amortization	(4,255)	(3,623)
Software Development Costs Accumulated Amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Total accumulated amortization	(12,939)	(12,016)
Other Accumulated Amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Total accumulated amortization	$ (1,047)	$ (990)

Variable Interest Entities (Details) $ in Millions	3 Months Ended
Variable Interest Entities (Details) $ in Millions	Mar. 31, 2012 USD ($) yr MW	Jan. 31, 2012 USD ($)
Variable Interest Entity [Line Items]
Evaluated power capacity of Lancaster Plant, megawatts \| MW	270
Minimum estimated life of plant, in years \| yr	15
Maximum estimated life of plant, in years \| yr	25
Future contractual obligation \| $	$ 336.0
Ecova [Member]
Variable Interest Entity [Line Items]
Amounts borrowed from a funding trust \| $		$ 25.0
Percentage of partnership funded	49.00%
Third Party [Member]
Variable Interest Entity [Line Items]
Percentage of partnership funded	51.00%

Redeemable Noncontrolling Interests And Subsidiary Acquisitions (Narrative) (Details) $ in Thousands	1 Months Ended	3 Months Ended		12 Months Ended
	Jan. 31, 2012 USD ($) yr	Mar. 31, 2012 USD ($)	Mar. 31, 2011 USD ($)	Dec. 31, 2011 yr	Nov. 30, 2011 USD ($)
Business Acquisition [Line Items]
Redemption rights expiration date		July 31, 2012
Equity infusion from existing shareholders		$ 1,437	$ 8,458
Ecova [Member]
Business Acquisition [Line Items]
Borrowings under committed credit agreement	$ 25,000
Equity infusion from existing shareholders	20,000
Prenova [Member]
Business Acquisition [Line Items]
Cash paid for acquisition					$ 35,600
Estimated amortization period (in years) \| yr				9
LPB Energy Management [Member]
Business Acquisition [Line Items]
Cash paid for acquisition	50,600
Assets acquired, accounts receivable	2,500
Assets acquired, goodwill	33,500
Client Backlog [Member] \| LPB Energy Management [Member]
Business Acquisition [Line Items]
Intangible assets acquired	$ 8,200
Estimated amortization period (in years)	3
Client Relationships [Member] \| LPB Energy Management [Member]
Business Acquisition [Line Items]
Intangible assets acquired	$ 4,800
Estimated amortization period (in years) \| yr	10
Internal Use Software [Member] \| LPB Energy Management [Member]
Business Acquisition [Line Items]
Intangible assets acquired	$ 2,500
Estimated amortization period, minimum (in years)	3
Estimated amortization period, maximum (in years)	4

Redeemable Noncontrolling Interests And Subsidiary Acquisitions (Redeemable Noncontrolling Interests) (Details) - USD ($) $ in Thousands	Mar. 31, 2012	Dec. 31, 2011
Redeemable Noncontrolling Interests And Subsidiary Acquisitions [Abstract]
Previous owners of Cadence Network	$ 44,295	$ 38,893
Stock options and other outstanding redeemable stock	13,338	12,916
Total redeemable noncontrolling interests	$ 57,633	$ 51,809

- Definition

As of the reporting date, the aggregate carrying amount of all noncontrolling interests which are redeemable by the (parent) entity (1) at a fixed or determinable price on a fixed or determinable date, (2) at the option of the holder of the noncontrolling interest, or (3) upon occurrence of an event that is not solely within the control of the (parent) entity. This item includes noncontrolling interest holder's ownership (or holders' ownership) regardless of the type of equity interest (common, preferred, other) including all potential organizational (legal) forms of the investee entity.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number D-98
-Paragraph 43
-Subparagraph b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number D-98
-Paragraph 43
-Subparagraph c
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 27
-Appendix A
-Subparagraph c

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 480
-SubTopic 10
-Subparagraph (12)(c)
-Section S99
-Paragraph 3A
-URI http://asc.fasb.org/extlink&oid=6802392&loc=SL6540498-122764

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 480
-SubTopic 10
-Subparagraph 14
-Paragraph 3A
-Section S99
-URI http://asc.fasb.org/extlink&oid=6802392&loc=SL6540498-122764

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 480
-SubTopic 10
-Subparagraph 15
-Paragraph 3A
-Section S99
-URI http://asc.fasb.org/extlink&oid=6802392&loc=SL6540498-122764

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 480
-SubTopic 10
-Subparagraph (16)(c)
-Paragraph 3A
-Section S99
-URI http://asc.fasb.org/extlink&oid=6802392&loc=SL6540498-122764

+ Details

- Definition

As of the reporting date, the carrying amount of noncontrolling interests which are redeemable by the (parent) entity (1) at a fixed or determinable price on a fixed or determinable date, (2) at the option of the holder of the noncontrolling interest, or (3) upon occurrence of an event that is not solely within the control of the (parent) entity. The noncontrolling interest holder's ownership (or holders' ownership) may be in the form of common shares (regardless of class), limited partnership units (regardless of class), non-preferential membership interests, or any other form of common equity regardless of investee entity legal form.

+ References

+ Details

- Definition

As of the reporting date, the carrying amount of noncontrolling interests which are redeemable by the (parent) entity (1) at a fixed or determinable price on a fixed or determinable date, (2) at the option of the holder of the noncontrolling interest, or (3) upon occurrence of an event that is not solely within the control of the (parent) entity. The noncontrolling interest holder's ownership (or holders' ownership) is represented by an equity interest that does not conform to either common or preferred equity (noncontrolling) interests otherwise provided for in the taxonomy, regardless of investee entity legal form.

+ References

+ Details

Derivatives And Risk Management (Narrative) (Details) - USD ($) $ in Thousands	Mar. 31, 2012	Dec. 31, 2011
Derivative [Line Items]
Aggregate fair value of all derivative instruments that are in a liability position	$ 84,700
Cash deposited as collateral	20,500
Letters of credit outstanding	20,090	$ 29,030
Cash collateral against net derivative positions	15,900
Collateral agreements with counterparties	64,300
Energy Derivative Contracts [Member]
Derivative [Line Items]
Letters of credit outstanding	$ 12,500

Derivatives And Risk Management (Energy Commodity Derivatives) (Details) Unit13 in Thousands	3 Months Ended
	Mar. 31, 2012
Purchases [Member] \| Physical [Member] \| Electric Derivatives [Member]
Energy Commodity Derivative Volumes [Line Items]
2012	976
2013	537
2014	366
2015	379
2016	367
Thereafter	949
Purchases [Member] \| Physical [Member] \| Gas Derivatives [Member]
Energy Commodity Derivative Volumes [Line Items]
2012	28,466
2013	11,895
2014	5,939
2015	3,013
2016	1,137
Purchases [Member] \| Financial [Member] \| Electric Derivatives [Member]
Energy Commodity Derivative Volumes [Line Items]
2012	845
2013	245
2014	0
Purchases [Member] \| Financial [Member] \| Gas Derivatives [Member]
Energy Commodity Derivative Volumes [Line Items]
2012	7,577
2013	10,270
2014	5,586
2015	980
2016	455
Sales [Member] \| Physical [Member] \| Electric Derivatives [Member]
Energy Commodity Derivative Volumes [Line Items]
2012	638
2013	310
2014	286
2015	285
2016	287
Thereafter	730
Sales [Member] \| Physical [Member] \| Gas Derivatives [Member]
Energy Commodity Derivative Volumes [Line Items]
2012	6,819
2013	1,533
2014	1,050
Sales [Member] \| Financial [Member] \| Electric Derivatives [Member]
Energy Commodity Derivative Volumes [Line Items]
2012	433
2013	491
2014	246
Sales [Member] \| Financial [Member] \| Gas Derivatives [Member]
Energy Commodity Derivative Volumes [Line Items]
2012	4,634
2013	1,727
2014	225

Derivatives And Risk Management (Foreign Currency Exchange Contracts) (Details) $ in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2012 CAD ($)	Mar. 31, 2012 USD ($)	Dec. 31, 2011 CAD ($)	Dec. 31, 2011 USD ($)
Derivatives And Risk Management [Abstract]
Number of days Canadian currency prices are settled with U.S. dollars	60
Number of contracts	31	31	28	28
Notional amount	$ 4,235	$ 4,258	$ 7,192	$ 7,033
Derivatives in other current assets (liabilities)		$ (25)		$ 32

Derivatives And Risk Management (Interest Rate Swap Agreements) (Details) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2012 USD ($)	Dec. 31, 2011 USD ($)
Derivatives, Fair Value [Line Items]
Current derivative liability	$ (135,525)	$ (215,126)
Non-current derivative asset (liability)	$ (108,038)	$ (128,893)
July 2012 [Member] \| Interest Rate Swap Agreements [Member]
Derivatives, Fair Value [Line Items]
Number of contracts	3	3
Notional amount	$ 75,000	$ 75,000
Mandatory cash settlement date	July 2012	July 2012
Current derivative liability	$ (9,241)	$ (16,253)
June 2013 [Member] \| Interest Rate Swap Agreements [Member]
Derivatives, Fair Value [Line Items]
Number of contracts	2	2
Notional amount	$ 85,000	$ 85,000
Mandatory cash settlement date	June 2013	June 2013
Non-current derivative asset (liability)	$ 5,084	$ (2,642)

Derivatives And Risk Management (Derivative Instruments Summary) (Details) - USD ($) $ in Thousands	Mar. 31, 2012	Dec. 31, 2011
Derivatives, Fair Value [Line Items]
Asset	$ 27,487	$ 86,233
Liability	(135,525)	(215,126)
Net Asset (Liability)	(108,038)	(128,893)
Other Current Assets [Member] \| Foreign Currency Contracts [Member]
Derivatives, Fair Value [Line Items]
Asset		32
Net Asset (Liability)		32
Other Current Liabilities [Member] \| Foreign Currency Contracts [Member]
Derivatives, Fair Value [Line Items]
Liability	(25)
Net Asset (Liability)	(25)
Other Current Liabilities [Member] \| Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Liability	(9,241)	(16,253)
Net Asset (Liability)	(9,241)	(16,253)
Other Intangibles, Property And Investments - Net [Member] \| Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Asset	5,084
Net Asset (Liability)	5,084
Other Non-Current Liabilities And Deferred Credits [Member] \| Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Liability		(2,642)
Net Asset (Liability)		(2,642)
Other Non-Current Liabilities And Deferred Credits [Member] \| Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Asset	1,147	44,308
Liability	(35,864)	(84,838)
Net Asset (Liability)	(34,717)	(40,530)
Current Utility Energy Commodity Derivative Assets [Member] \| Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Asset	2,647	1,618
Liability	(365)	(479)
Net Asset (Liability)	2,282	1,139
Non-Current Utility Energy Commodity Derivative Assets [Member] \| Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Asset	8,148	185
Liability	(5,965)
Net Asset (Liability)	2,183	185
Current Utility Energy Commodity Derivative Liabilities [Member] \| Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Asset	10,461	40,090
Liability	(84,065)	(110,914)
Net Asset (Liability)	$ (73,604)	$ (70,824)

Pension Plans And Other Postretirement Benefit Plans (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2012	Dec. 31, 2011	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Contributions to pension plan	$ 14.7	$ 26.0
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected contributions to pension plan			$ 44.0

Pension Plans And Other Postretirement Benefit Plans (Components Of Net Periodic Benefit Costs) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 3,791	$ 2,942
Interest cost	6,109	6,109
Expected return on plan assets	(6,000)	(5,591)
Amortization of prior service cost	75	119
Net loss recognition	2,757	2,105
Net periodic benefit cost	6,732	5,684
Other Post-Retirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	689	227
Interest cost	1,281	919
Expected return on plan assets	(375)	(443)
Transition obligation recognition	126	126
Amortization of prior service cost	(38)	(37)
Net loss recognition	1,312	435
Net periodic benefit cost	$ 2,995	$ 1,227

Short-Term Borrowings (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011
Short-term Debt [Line Items]
Total amount of committed line of credit agreement	$ 400,000
Maximum percentage ratio of consolidated total debt to consolidated total capitalization needed to comply with covenants	65.00%
Committed line of credit long-term agreement	$ 50,000
Committed line of credit short-term agreement	47,000	$ 96,000
Ecova [Member]
Short-term Debt [Line Items]
Line of credit facility decrease for next nine months	55,000
Line of credit facility decrease for next one year	50,000
Line Of Credit [Member] \| Ecova [Member]
Short-term Debt [Line Items]
Total amount of committed line of credit agreement	60,000
Committed line of credit long-term agreement	50,000
Committed line of credit short-term agreement	$ 10,000

- Definition

The carrying value as of the balance sheet date of the current portion of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement.

+ References + Details

- Definition

The carrying value as of the balance sheet date of the noncurrent portion of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement.

+ References + Details

Short-Term Borrowings (Schedule Of Balances Outstanding And Interest Rates Of Borrowings) (Details) - USD ($) $ in Thousands	Mar. 31, 2012	Dec. 31, 2011
Line of Credit Facility [Line Items]
Balance outstanding at end of period	$ 37,000	$ 61,000
Letters of credit outstanding at end of period	$ 20,090	$ 29,030
Average interest rate at end of period	3.25%	1.12%
Ecova [Member]
Line of Credit Facility [Line Items]
Balance outstanding at end of period	$ 60,000	$ 35,000
Average interest rate at end of period	2.25%	2.38%

Long-Term Debt (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended
	Dec. 31, 1998	Mar. 31, 2012	Dec. 31, 2011
Debt Instrument [Line Items]
Total amount of committed line of credit agreement		$ 400,000
Funds held in trust account that are used to secure long-term debt		$ 1,600	$ 1,600
Nonrecourse Long-Term Debt [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		8.45%
Amount borrowed to acquire a long-term fixed rate electric capacity contract	$ 145,000
Funds held in trust account that are used to secure long-term debt		$ 1,600

Long-Term Debt (Schedule Of Long-Term Debt Instruments) (Details) - USD ($)
$ in Thousands

3 Months Ended

Mar. 31, 2012

Dec. 31, 2011

Debt Instrument [Line Items]

Secured long-term debt

$ 1,263,700

Other long-term debt and capital leases

5,389

5,455

Settled interest rate swaps

(10,321)

(10,629)

Unamortized debt discount

(1,584)

(1,626)

Total

1,261,284

1,261,000

Current portion of long-term debt

(7,409)

(7,474)

Total long-term debt

1,170,175

1,169,826

Secured Debt [Member]

Debt Instrument [Line Items]

Pollution Control Bonds

^[1],[2]

$ (83,700)

(83,700)

2012 [Member] | Secured Debt [Member]

Debt Instrument [Line Items]

Maturity Year

2012

Debt instrument, interest rate, stated percentage

7.37%

Medium-Term Notes, Noncurrent

$ 7,000

7,000

2013 [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Maturity Year

2013

Debt instrument, interest rate, stated percentage

1.68%

Secured long-term debt

$ 50,000

50,000

2018, 5.95% [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Maturity Year

2018

Debt instrument, interest rate, stated percentage

5.95%

Secured long-term debt

$ 250,000

250,000

2018, 7.39% - 7.45% [Member] | Secured Debt [Member]

Debt Instrument [Line Items]

Maturity Year

2018

Interest Rate, minimum

7.39%

Interest Rate, maximum

7.45%

Medium-Term Notes, Noncurrent

$ 22,500

22,500

2019 [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Maturity Year

2019

Debt instrument, interest rate, stated percentage

5.45%

Secured long-term debt

$ 90,000

90,000

2020 [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Maturity Year

2020

Debt instrument, interest rate, stated percentage

3.89%

Secured long-term debt

$ 52,000

52,000

2022 [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Maturity Year

2022

Debt instrument, interest rate, stated percentage

5.13%

Secured long-term debt

$ 250,000

250,000

2023, 7.18% - 7.54% [Member] | Secured Debt [Member]

Debt Instrument [Line Items]

Maturity Year

2023

Interest Rate, minimum

7.18%

Interest Rate, maximum

7.54%

Medium-Term Notes, Noncurrent

$ 13,500

13,500

2028 [Member] | Secured Debt [Member]

Debt Instrument [Line Items]

Maturity Year

2028

Debt instrument, interest rate, stated percentage

6.37%

Medium-Term Notes, Noncurrent

$ 25,000

25,000

2032 [Member] | Secured Debt [Member]

Debt Instrument [Line Items]

Maturity Year

^[2]

2032

Pollution Control Bonds

^[2]

$ (66,700)

(66,700)

2034 [Member] | Secured Debt [Member]

Debt Instrument [Line Items]

Maturity Year

^[1]

2034

Pollution Control Bonds

^[1]

$ (17,000)

(17,000)

2035 [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Maturity Year

2035

Debt instrument, interest rate, stated percentage

6.25%

Secured long-term debt

$ 150,000

150,000

2037 [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Maturity Year

2037

Debt instrument, interest rate, stated percentage

5.70%

Secured long-term debt

$ 150,000

150,000

2040 [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Maturity Year

2040

Debt instrument, interest rate, stated percentage

5.55%

Secured long-term debt

$ 35,000

35,000

2041 [Member] | First Mortgage Bonds [Member]

Debt Instrument [Line Items]

Maturity Year

2041

Debt instrument, interest rate, stated percentage

4.45%

Secured long-term debt

$ 85,000

85,000

2023, 6.00% [Member] | Unsecured Debt [Member]

Debt Instrument [Line Items]

Maturity Year

2023

Debt instrument, interest rate, stated percentage

6.00%

Pollution Control Bonds

$ (4,100)

[1]

[2]

Fair Value (Narrative) (Details) $ in Thousands	3 Months Ended	12 Months Ended
Fair Value (Narrative) (Details) $ in Thousands	Mar. 31, 2012 USD ($)	Dec. 31, 2019	Dec. 31, 2012	Dec. 31, 2011 USD ($)	Mar. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	$ 72,703			$ 74,662	$ 61,837	$ 69,413
Cash Equivalents [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	$ 1,300			$ 1,300
2016 To 2019 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Escalation factor	3.00%
Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Esitmated vloatility rate	0.20%
Level 3 [Member] \| 2015 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Escalation factor	5.00%
Level 3 [Member] \| Internally Developed [member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Average forward price	36.73
Level 3 [Member] \| Minimum [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Forward price	2.65
Volumes of the transactions per delivery	365,619
Sales	2.95
Level 3 [Member] \| Minimum [Member] \| Internally Developed [member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Forward price	29.01
Level 3 [Member] \| Minimum [Member] \| Estimates For Sales [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Volumes of the transactions per delivery	53,546
Level 3 [Member] \| Minimum [Member] \| Estimates For Purchases [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Volumes of the transactions per delivery	140,000
Level 3 [Member] \| Maximum [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Forward price	3.61
Volumes of the transactions per delivery	379,156
Sales	4.14
Level 3 [Member] \| Maximum [Member] \| Internally Developed [member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Forward price	43.81
Level 3 [Member] \| Maximum [Member] \| Estimates For Sales [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Volumes of the transactions per delivery	620,000
Level 3 [Member] \| Maximum [Member] \| Estimates For Purchases [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Volumes of the transactions per delivery	310,000
Scenario, Forecast [Member] \| Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Volumes of the transactions per delivery		157,517	254,328
Known volatility rate		0.22%	0.44%
Scenario, Forecast [Member] \| Level 3 [Member] \| Internally Developed [member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Strike price		73.76	32.78

Fair Value (Carrying Value And Estimated Fair Value Of Financial Instruments) (Details) - USD ($) $ in Thousands	Mar. 31, 2012	Dec. 31, 2011
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt to affiliated trusts	$ 51,547	$ 51,547
Level 2 [Member] \| Carrying Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	962,100	962,100
Level 2 [Member] \| Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	1,099,091	1,135,536
Level 3 [Member] \| Carrying Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	222,000	222,000
Nonrecourse long-term debt	43,165	46,471
Long-term debt to affiliated trusts	51,547	51,547
Level 3 [Member] \| Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	232,748	234,226
Nonrecourse long-term debt	48,227	51,974
Long-term debt to affiliated trusts	$ 43,810	$ 43,810

Fair Value (Fair Value Of Assets And Liabilities Measured On Recurring Basis) (Details) - USD ($)
$ in Thousands

Mar. 31, 2012

Dec. 31, 2011

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Assets

$ 4,465

$ 1,324

Foreign currency derivatives, Assets

Interest rate swaps, Assets

5,084

Cash and cash equivalents

58,385

21,957

Securities available for sale

105,978

96,579

Funds held in trust account of Spokane Energy

1,600

Assets, Total

183,427

128,860

Energy commodity derivatives, Liabilities

86,408

98,496

Foreign currency derivatives, Liabilities

Interest rate swaps, Liabilities

9,241

18,895

Liabilities, Total

117,587

130,249

Level 1 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Cash and cash equivalents

58,385

21,957

Funds held in trust account of Spokane Energy

1,600

Assets, Total

67,900

30,925

Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Assets

21,369

80,571

Foreign currency derivatives, Assets

Interest rate swaps, Assets

5,084

Assets, Total

132,431

177,182

Energy commodity derivatives, Liabilities

103,312

177,743

Foreign currency derivatives, Liabilities

Interest rate swaps, Liabilities

9,241

18,895

Liabilities, Total

112,578

196,638

Level 3 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Assets, Total

1,034

5,630

Liabilities, Total

22,947

18,488

Counterparty Netting [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Assets

^[1]

(16,904)

(79,247)

Assets, Total

^[1]

(17,938)

(84,877)

Energy commodity derivatives, Liabilities

^[1]

(16,904)

(79,247)

Liabilities, Total

^[1]

(17,938)

(84,877)

Natural Gas Exchange Agreements [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Liabilities

2,354

1,688

Natural Gas Exchange Agreements [Member] | Level 3 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Assets

956

Energy commodity derivatives, Liabilities

2,354

2,644

Natural Gas Exchange Agreements [Member] | Counterparty Netting [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Assets

^[1]

(956)

Energy commodity derivatives, Liabilities

^[1]

(956)

Power Exchange Agreements [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Liabilities

18,572

9,910

Power Exchange Agreements [Member] | Level 3 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Assets

1,034

4,674

Energy commodity derivatives, Liabilities

19,606

14,584

Power Exchange Agreements [Member] | Counterparty Netting [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Assets

^[1]

(1,034)

(4,674)

Energy commodity derivatives, Liabilities

^[1]

(1,034)

(4,674)

Power Option Agreements [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Liabilities

987

1,260

Power Option Agreements [Member] | Level 3 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Energy commodity derivatives, Liabilities

987

1,260

U.S. Government Agency [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

78,735

74,893

U.S. Government Agency [Member] | Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

78,735

74,893

Municipal [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

5,364

425

Municipal [Member] | Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

5,364

425

Corporate Fixed Income - Financial [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

11,738

11,154

Corporate Fixed Income - Financial [Member] | Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

11,738

11,154

Corporate Fixed Income - Industrial [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

6,517

6,518

Corporate Fixed Income - Industrial [Member] | Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

6,517

6,518

Fixed Income Securities [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Deferred compensation assets

^[2]

2,142

2,116

Fixed Income Securities [Member] | Level 1 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Deferred compensation assets

^[2]

2,142

2,116

Equity Securities [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Deferred compensation assets

^[2]

5,773

5,252

Equity Securities [Member] | Level 1 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Deferred compensation assets

^[2]

5,773

5,252

Corporate Fixed Income - Utility [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

2,114

2,092

Corporate Fixed Income - Utility [Member] | Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

2,114

2,092

Certificates Of Deposit [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

1,510

1,497

Certificates Of Deposit [Member] | Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Securities available for sale

$ 1,510

$ 1,497

[1]	The Company is permitted to net derivative assets and derivative liabilities with the same counterparty when a legally enforceable master netting agreement exists.
[2]	These assets are trading securities and are included in other intangibles, property and investments-net on the Condensed Consolidated Balance Sheets.

Fair Value (Reconciliation For Energy Commodity Derivative Assets (Liabilities Measured At Fair Value On A Recurring Basis Using Significant Unobservable Inputs (Level 3)) (Details) - USD ($)
$ in Thousands

3 Months Ended

Mar. 31, 2012

Mar. 31, 2011

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Balance as of January 1

$ (12,858)

$ 13,459

Included in regulatory assets/liabilities

^[1]

(10,351)

(86)

Settlements

1,296

956

Ending balance as of March 31

(21,913)

14,329

Natural Gas Exchange Agreements [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Balance as of January 1

(1,688)

Included in net income

Included in other comprehensive income

Included in regulatory assets/liabilities

^[1]

290

Purchases

Issuances

Settlements

(956)

Transfers to other categories

Ending balance as of March 31

(2,354)

Power Exchange Agreements [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Balance as of January 1

(9,910)

15,793

Included in regulatory assets/liabilities

^[1]

(10,914)

(887)

Settlements

2,252

956

Ending balance as of March 31

(18,572)

15,862

Power Option Agreements [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Balance as of January 1

(1,260)

(2,334)

Included in regulatory assets/liabilities

^[1]

273

801

Ending balance as of March 31

$ (987)

$ (1,533)

[1]

Earnings Per Common Share Attributable To Avista Corporation (Computation Of Basic And Diluted Earnings Per Common Share) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Numerator:
Net income attributable to Avista Corporation	$ 38,388	$ 41,918
Subsidiary earnings adjustment for dilutive securities		(74)
Adjusted net income attributable to Avista Corporation for computation of diluted earnings per common share	$ 38,388	$ 41,844
Denominator:
Weighted-average number of common shares outstanding-basic	58,581	57,342
Effect of dilutive securities:
Performance and restricted stock awards	344	12
Stock options	25	60
Weighted-average number of common shares outstanding-diluted	58,950	57,414
Potential shares excluded in calculation
Earnings per common share attributable to Avista Corporation:
Basic	$ 0.66	$ 0.73
Diluted	$ 0.65	$ 0.73

Commitments And Contingencies (Details)	1 Months Ended			3 Months Ended
Commitments And Contingencies (Details)	Aug. 31, 2010	Mar. 31, 2007	May 31, 2004 USD ($)	Mar. 31, 2012 yr	Mar. 30, 2007	Jun. 30, 2005 USD ($)
Commitments And Contingencies [Abstract]
Investigation review bids maximum (per MW)			$ 250
Owners percentage interest					15.00%
Number of families that own property near the holding ponds who filed a complaint		2
Number of years, license issued \| yr				50
Accrual for environmental loss contingencies						$ 500,000
Number of hydroelectric plants				6
Number of diversion tunnels				2
Number of residences destroyed	2
Number of outbuildings destroyed	6

Information By Business Segments (Information By Business Segments) (Details) - USD ($)
$ in Thousands

3 Months Ended

Mar. 31, 2012

Mar. 31, 2011

Dec. 31, 2011

Segment Reporting Information [Line Items]

Operating revenues

$ 452,257

$ 476,586

Resource costs

211,012

248,121

Other operating expenses

107,059

90,928

Depreciation and amortization

30,322

27,719

Income (loss) from operations

78,722

84,825

Interest expense

^[1]

19,277

18,591

Income taxes

21,138

23,637

Net income attributable to Avista Corporation

38,388

41,918

Capital expenditures

58,915

50,128

Total Assets

4,254,004

$ 4,214,531

Avista Utilities [Member]

Segment Reporting Information [Line Items]

Operating revenues

405,910

438,147

Resource costs

211,012

248,121

Other operating expenses

63,357

59,682

Depreciation and amortization

27,318

25,852

Income (loss) from operations

79,081

79,499

Interest expense

^[1]

18,046

17,356

Income taxes

21,726

22,255

Net income attributable to Avista Corporation

39,477

40,117

Capital expenditures

57,771

49,654

Total Assets

3,758,726

3,809,446

Ecova [Member]

Segment Reporting Information [Line Items]

Operating revenues

37,010

29,158

Other operating expenses

35,774

24,008

Depreciation and amortization

2,836

1,664

Income (loss) from operations

(1,600)

3,486

Interest expense

^[1]

360

Income taxes

(381)

1,254

Net income attributable to Avista Corporation

(826)

1,707

Capital expenditures

1,142

315

Total Assets

389,782

292,940

Other Business Segment [Member]

Segment Reporting Information [Line Items]

Operating revenues

9,787

9,731

Other operating expenses

8,378

7,688

Depreciation and amortization

168

203

Income (loss) from operations

1,241

1,840

Interest expense

^[1]

965

1,597

Income taxes

(207)

128

Net income attributable to Avista Corporation

(263)

Capital expenditures

159

Total Assets

105,496

112,145

Total Non-Utility [Member]

Segment Reporting Information [Line Items]

Operating revenues

46,797

38,889

Other operating expenses

44,152

31,696

Depreciation and amortization

3,004

1,867

Income (loss) from operations

(359)

5,326

Interest expense

^[1]

1,325

1,608

Income taxes

(588)

1,382

Net income attributable to Avista Corporation

(1,089)

1,801

Capital expenditures

1,144

474

Total Assets

495,278

$ 405,085

Intersegment Eliminations [Member]

Segment Reporting Information [Line Items]

Operating revenues

^[2]

(450)

Other operating expenses

^[2]

(450)

Interest expense

^[1],[2]

$ (94)

$ (373)

[1]	Including interest expense to affiliated trusts.
[2]	Intersegment eliminations reported as operating revenues and resource costs represent intercompany purchases and sales of electric capacity and energy. Intersegment eliminations reported as interest expense represent intercompany interest.