Avista (AVA) 10-Q 4 Aug 21 2021 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2021	Jul. 31, 2021
Cover [Abstract]
Entity Registrant Name	AVISTA CORPORATION
Amendment Flag	false
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Information, Former Legal or Registered Name	None
City Area Code	509
Entity Incorporation, State or Country Code	WA
Document Transition Report	false
Document Quarterly Report	true
Document Type	10-Q
Document Period End Date	Jun. 30, 2021
Entity File Number	1-3701
Entity Tax Identification Number	91-0462470
Entity Address, Address Line One	1411 East Mission Avenue
Entity Address, City or Town	Spokane
Entity Address, State or Province	WA
Entity Address, Postal Zip Code	99202-2600
Local Phone Number	489-0500
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Emerging Growth Company	false
Entity Shell Company	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q2
Entity Central Index Key	0000104918
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		69,667,790
Title of 12(b) Security	Common Stock
Trading Symbol	AVA
Security Exchange Name	NYSE

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Utility revenues:
Utility revenues, exclusive of alternative revenue programs	$ 301,176	$ 273,975	$ 713,358	$ 667,795
Alternative revenue programs	(3,069)	4,362	(2,570)	(51)
Total utility revenues	298,107	278,337	710,788	667,744
Non-utility revenues	148	255	337	1,078
Total operating revenues	298,255	278,592	711,125	668,822
Utility operating expenses:
Resource costs	90,678	67,965	225,257	197,512
Other operating expenses	94,053	86,204	181,608	180,700
Depreciation and amortization	56,066	63,908	111,287	115,329
Taxes other than income taxes	24,474	24,742	56,783	55,720
Non-utility operating expenses:
Other operating expenses	1,159	659	2,343	2,019
Depreciation and amortization	73	188	200	423
Total operating expenses	266,503	243,666	577,478	551,703
Income from operations	31,752	34,926	133,647	117,119
Interest expense	26,131	25,625	52,435	51,972
Interest expense to affiliated trusts	106	208	215	478
Capitalized interest	(916)	(972)	(1,931)	(1,970)
Other expense (income)-net	(10,041)	531	(13,725)	149
Income before income taxes	16,472	9,534	96,653	66,490
Income tax expense (benefit)	2,398	(7,919)	14,562	613
Net income	$ 14,074	$ 17,453	$ 82,091	$ 65,877
Weighted-average common shares outstanding (thousands), basic	69,404	67,481	69,348	67,360
Weighted-average common shares outstanding (thousands), diluted	69,534	67,589	69,520	67,485
Earnings per common share:
Basic	$ 0.20	$ 0.26	$ 1.18	$ 0.98
Diluted	$ 0.20	$ 0.26	$ 1.18	$ 0.98

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Statement Of Income And Comprehensive Income [Abstract]
Net income	$ 14,074	$ 17,453	$ 82,091	$ 65,877
Other Comprehensive Income:
Change in unfunded benefit obligation for pension and other postretirement benefit plans - net of taxes of $82, $59, $166 and $113 respectively	308	220	623	425
Total other comprehensive income	308	220	623	425
Comprehensive income	$ 14,382	$ 17,673	$ 82,714	$ 66,302

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Statement Of Income And Comprehensive Income [Abstract]
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ 82	$ 59	$ 166	$ 113

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Current Assets:
Cash and cash equivalents	$ 39,027	$ 14,196
Accounts and notes receivable-less allowances of $12,139 and $11,387, respectively	129,835	163,772
Materials and supplies, fuel stock and stored natural gas	82,778	67,451
Regulatory assets	27,174	13,673
Other current assets	83,140	84,885
Total current assets	361,954	343,977
Net utility property	5,100,762	4,991,612
Goodwill	52,426	52,426
Non-current regulatory assets	870,095	750,443
Other property and investments-net and other non-current assets	261,064	263,639
Total assets	6,646,301	6,402,097
Current Liabilities:
Accounts payable	104,048	106,613
Long-term Debt, Current Maturities	250,000	0
Short-term borrowings	296,000	203,000
Regulatory liabilities	70,176	46,435
Other current liabilities	171,685	149,831
Total current liabilities	891,909	505,879
Long-term debt	1,758,961	2,008,534
Long-term debt to affiliated trusts	51,547	51,547
Pensions and other postretirement benefits	188,912	211,880
Deferred income taxes	620,020	594,712
Non-current regulatory liabilities	882,443	784,820
Other non-current liabilities and deferred credits	182,543	214,999
Total liabilities	4,576,335	4,372,371
Commitments and Contingencies (See Notes to Condensed Consolidated Financial Statements)
Shareholders’ Equity:
Common stock, no par value; 200,000,000 shares authorized; 69,313,337 and 69,238,901 shares issued and outstanding, respectively	1,303,411	1,286,068
Accumulated other comprehensive loss	(13,755)	(14,378)
Retained earnings	780,310	758,036
Total shareholders’ equity	2,069,966	2,029,726
Total liabilities and equity	$ 6,646,301	$ 6,402,097

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Statement Of Financial Position [Abstract]
Accounts and notes receivable, allowances	$ 11,399	$ 11,387
Common stock, par value
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares, issued	69,666,667	69,238,901
Common stock, shares outstanding	69,666,667	69,238,901

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020
Operating Activities:
Net income	$ 82,091	$ 65,877
Non-cash items included in net income:
Depreciation and amortization	111,487	115,752
Deferred income tax provision and investment tax credits	11,085	(8,400)
Power and natural gas cost amortizations (deferrals), net	(21,826)	1,815
Amortization of debt expense	1,571	1,365
Stock-based compensation expense	2,280	2,826
Equity-related AFUDC	(3,346)	(3,271)
Pension and other postretirement benefit expense	14,793	16,481
Other regulatory assets and liabilities and deferred debits and credits	4,008	4,391
Change in decoupling regulatory deferral	2,203	(454)
Gain on sale of investments	(1,764)	(3,231)
Other	(7,653)	9,043
Contributions to defined benefit pension plan	(28,000)	(14,600)
Changes in certain current assets and liabilities:
Accounts and notes receivable	26,284	43,701
Materials and supplies, fuel stock and stored natural gas	(15,328)	(751)
Collateral posted for derivative instruments	(24,102)	(7,209)
Income taxes receivable	23,869	9,106
Other current assets	2,505	(5,704)
Accounts payable	8,111	(29,860)
Other current liabilities	1,795	3,011
Net cash provided by operating activities	190,063	199,888
Investing Activities:
Utility property capital expenditures (excluding equity-related AFUDC)	(213,827)	(189,480)
Issuance of notes receivable	(75)	(4,343)
Equity and property investments	(5,650)	(2,097)
Proceeds from sale of investments	6,806	5,144
Other	1,907	(988)
Net cash used in investing activities	(210,839)	(191,764)
Financing Activities:
Net increase in short-term borrowings	93,000	135,200
Maturity of long-term debt and finance leases	(1,491)	(1,431)
Issuance of common stock, net of issuance costs	15,689	23,890
Cash dividends paid	(58,693)	(54,708)
Other	(2,898)	(4,577)
Net cash provided by financing activities	45,607	98,374
Net increase in cash and cash equivalents	24,831	106,498
Cash and cash equivalents at beginning of period	14,196	9,896
Cash and cash equivalents at end of period	$ 39,027	$ 116,394

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Thousands	Total	Common Stock [Member]	Accumulated Other Comprehensive Loss [Member]	Retained Earnings [Member]
Beginning Balance (in shares) at Dec. 31, 2019		67,176,996
Shares issued		736,269
Ending Balance (in shares) at Jun. 30, 2020		67,913,265
Beginning Balance at Dec. 31, 2019		$ 1,210,741	$ (10,259)	$ 738,802
Equity compensation expense		2,678
Issuance of common stock, net of issuance costs		23,890
Payment of minimum tax withholdings for share-based payment awards		(2,408)
Other comprehensive income	$ 425		425
Net income	65,877			65,877
Cash dividends on common stock				(54,708)
Ending Balance at Jun. 30, 2020	$ 1,975,038	$ 1,234,901	(9,834)	749,971
Dividends declared per common share	$ 0.8100
Beginning Balance (in shares) at Mar. 31, 2020		67,292,233
Shares issued		621,032
Ending Balance (in shares) at Jun. 30, 2020		67,913,265
Beginning Balance at Mar. 31, 2020		$ 1,209,312	(10,054)	759,837
Equity compensation expense		1,874
Issuance of common stock, net of issuance costs		23,715
Other comprehensive income	$ 220		220
Net income	17,453			17,453
Cash dividends on common stock				(27,319)
Ending Balance at Jun. 30, 2020	$ 1,975,038	$ 1,234,901	(9,834)	749,971
Dividends declared per common share	$ 0.4050
Beginning Balance (in shares) at Dec. 31, 2020	69,238,901	69,238,901
Shares issued		427,766
Ending Balance (in shares) at Jun. 30, 2021	69,666,667	69,666,667
Beginning Balance at Dec. 31, 2020		$ 1,286,068	(14,378)	758,036
Equity compensation expense		2,647
Issuance of common stock, net of issuance costs		15,689
Payment of minimum tax withholdings for share-based payment awards		(993)
Other comprehensive income	$ 623		623
Net income	82,091			82,091
Cash dividends on common stock				(59,817)
Ending Balance at Jun. 30, 2021	$ 2,069,966	$ 1,303,411	(13,755)	780,310
Dividends declared per common share	$ 0.8450
Beginning Balance (in shares) at Mar. 31, 2021		69,313,337
Shares issued		353,330
Ending Balance (in shares) at Jun. 30, 2021	69,666,667	69,666,667
Beginning Balance at Mar. 31, 2021		$ 1,285,999	(14,063)	796,654
Equity compensation expense		1,788
Issuance of common stock, net of issuance costs		15,624
Payment of minimum tax withholdings for share-based payment awards		0
Other comprehensive income	$ 308		308
Net income	14,074			14,074
Cash dividends on common stock				(30,418)
Ending Balance at Jun. 30, 2021	$ 2,069,966	$ 1,303,411	$ (13,755)	$ 780,310
Dividends declared per common share	$ 0.4225

Summary of Significant Accounti

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2021
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	NOTE 1. SUMMARY OF SIGNIF ICANT ACCOUNTING POLICIES Nature of Business Avista Corp. is primarily an electric and natural gas utility with certain other business ventures. Avista Utilities is an operating division of Avista Corp., comprising its regulated utility operations in the Pacific Northwest. Avista Utilities provides electric distribution and transmission, and natural gas distribution services in parts of eastern Washington and northern Idaho. Avista Utilities also provides natural gas distribution service in parts of northeastern and southwestern Oregon. Avista Utilities has electric generating facilities in Washington, Idaho, Oregon and Montana. Avista Utilities also supplies electricity to a small number of customers in Montana, most of whom are employees who operate the Company's Noxon Rapids generating facility. AERC is a wholly-owned subsidiary of Avista Corp. The primary subsidiary of AERC is AEL&P, which comprises Avista Corp.'s regulated utility operations in Alaska. Avista Capital, a wholly owned non-regulated subsidiary of Avista Corp., is the parent company of all of the subsidiary companies in the non-utility businesses, with the exception of AJT Mining Properties, Inc., which is a subsidiary of AERC. See Note 16 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 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. Regulation The Company is subject to state regulation in Washington, Idaho, Montana, Oregon and Alaska. The Company is also subject to federal regulation primarily by the FERC, as well as various other federal agencies with regulatory oversight of particular aspects of its operations. Derivative Assets and Liabilities Derivatives are recorded as either assets or liabilities on the Condensed Consolidated Balance Sheets measured at estimated fair value. The WUTC and the IPUC issued accounting orders authorizing Avista Corp. to offset energy 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 delivery. Realized benefits and costs result in adjustments to retail rates through PGAs, the ERM in Washington, the PCA mechanism in Idaho, and periodic general rate cases. The resulting regulatory assets associated with energy commodity derivative instruments have been concluded to be probable of 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. For interest rate swap derivatives, Avista Corp. records all mark-to-market gains and losses in each accounting period as assets and liabilities, as well as offsetting regulatory assets and liabilities, such that there is no income statement impact. The interest rate swap derivatives are risk management tools similar to energy commodity derivatives. Upon settlement of interest rate swap derivatives, the regulatory asset or liability is amortized as a component of interest expense over the term of the associated debt. The Company records an offset of interest rate swap derivative assets and liabilities with regulatory assets and liabilities, based on the prior practice of the commissions to provide recovery through the ratemaking process. The Company has multiple master netting agreements with a variety of entities that allow for cross-commodity netting of derivative agreements with the same counterparty (i.e. power derivatives can be netted with natural gas derivatives). In addition, some master netting agreements allow for the netting of commodity derivatives and interest rate swap derivatives for the same counterparty. The Company does not have any agreements which allow for cross-affiliate netting among multiple affiliated legal entities. The Company nets all derivative instruments when allowed by the agreement for presentation in the Condensed Consolidated Balance Sheets. Fair Value Measurements Fair value represents the price that would be received when selling 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, deferred compensation assets, as well as derivatives related to interest rate swaps and foreign currency exchange contracts, are reported at estimated fair value on the Condensed Consolidated Balance Sheets. See Note 11 for the Company’s fair value disclosures. 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 loss contingencies that do not meet these conditions for accrual if there is a reasonable possibility that a material loss may be incurred. See Note 15 for further discussion of the Company's commitments and contingencies.

New Accounting Standards

New Accounting Standards	6 Months Ended
	Jun. 30, 2021
New Accounting Pronouncements And Changes In Accounting Principles [Abstract]
New Accounting Standards	NOTE 2. NEW ACCO UNTING STANDARDS There are no new accounting standards with a material impact to the Company.

Balance Sheet Components

Balance Sheet Components	6 Months Ended
	Jun. 30, 2021
Balance Sheet Related Disclosures [Abstract]
Balance Sheet Components	NOTE 3. BALANCE SHEET COMPONENTS Materials and Supplies, Fuel Stock and Stored Natural Gas Inventories of materials and supplies, fuel stock and stored natural gas are recorded at average cost for our regulated operations and the lower of cost or net realizable value for our non-regulated operations and consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Materials and supplies $ 57,068 $ 53,258 Fuel stock 5,780 4,658 Stored natural gas 19,930 9,535 Total $ 82,778 $ 67,451 Other Current Assets Other current assets consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Collateral posted for derivative instruments after netting with outstanding $ 25,089 $ 4,336 Prepayments 22,444 24,411 Income taxes receivable 25,945 49,814 Other 9,662 6,324 Total $ 83,140 $ 84,885 Net Utility Property Net utility property, which is recorded at original cost net of accumulated depreciation, consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Utility plant in service $ 6,980,002 $ 6,809,797 Construction work in progress 185,011 175,767 Total 7,165,013 6,985,564 Less: Accumulated depreciation and amortization 2,064,251 1,993,952 Total net utility property $ 5,100,762 $ 4,991,612 Other Property and Investments-Net and Other Non-Current Assets Other property and investments-net and other non-current assets consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Operating lease ROU assets $ 70,941 $ 71,891 Equity investments 69,921 59,318 Finance lease ROU assets 45,518 47,338 Non-utility property 18,925 19,508 Notes receivable 14,803 14,454 Investment in affiliated trust 11,547 11,547 Deferred compensation assets 9,660 9,174 Assets held for sale (1) — 3,462 Other 19,749 26,947 Total $ 261,064 $ 263,639 (1) During the second quarter of 2021, the Company sold certain subsidiary assets associated with the Spokane Steam Plant. Other Current Liabilities Other current liabilities consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, Accrued taxes other than income taxes $ 42,117 $ 45,099 Derivative liabilities 33,276 14,008 Employee paid time off accruals 28,998 26,495 Accrued interest 16,594 17,083 Pensions and other postretirement benefits 12,429 11,987 Other 38,271 35,159 Total other current liabilities $ 171,685 $ 149,831 Other Non-Current Liabilities and Deferred Credits Other non-current liabilities and deferred credits consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, Operating lease liabilities $ 68,820 $ 67,716 Finance lease liabilities 47,273 48,815 Deferred investment tax credits 29,590 29,866 Asset retirement obligations 16,734 17,194 Derivative liabilities 4,426 37,427 Other 15,700 13,981 Total $ 182,543 $ 214,999 Regulatory Assets and Liabilities Regulatory assets and liabilities consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, 2021 December 31, 2020 Current Non-Current Current Non-Current Regulatory Assets Energy commodity derivatives $ 5,652 $ 1,410 $ 2,073 $ 5,722 Decoupling surcharge 9,768 13,911 7,123 17,123 Pension and other postretirement benefit plans — 194,005 — 198,746 Interest rate swaps — 197,302 — 214,851 Deferred income taxes (1) — 238,234 — 108,517 Settlement with Coeur d'Alene Tribe — 39,484 — 40,043 AFUDC above FERC allowed rate — 48,961 — 47,393 Demand side management programs — 1,449 — 3,814 Utility plant to be abandoned — 27,599 — 28,916 COVID-19 deferrals — 14,292 — 8,166 Other regulatory assets 11,754 93,448 4,477 77,152 Total regulatory assets $ 27,174 $ 870,095 $ 13,673 $ 750,443 Regulatory Liabilities Income tax related liabilities (1) $ 45,431 $ 485,165 $ 14,952 $ 399,677 Deferred power costs 14,996 13,118 20,299 17,570 Decoupling rebate 849 3,754 1,447 1,519 Utility plant retirement costs — 336,940 — 325,832 Interest rate swaps — 15,637 — 15,046 COVID-19 deferrals — 12,680 — 10,949 Other regulatory liabilities 8,900 15,149 9,737 14,227 Total regulatory liabilities $ 70,176 $ 882,443 $ 46,435 $ 784,820 (1) In 2021, the Company received regulatory approval in all jurisdictions to change to flow-through tax treatment of certain basis adjustments, which was $ 127.5 million.

Revenue

Revenue	6 Months Ended
	Jun. 30, 2021
Revenue From Contract With Customer [Abstract]
Revenue	NOTE 4. REVENUE The revenue recognition model contained in ASC 606 requires an entity to identify the various performance obligations in a contract, allocate the transaction price among the performance obligations and recognize revenue when (or as) the entity satisfies each performance obligation. Utility Revenues Revenue from Contracts with Customers General The majority of Avista Corp.’s revenue is from rate-regulated sales of electricity and natural gas to retail customers, which has two performance obligations, (1) having service available for a specified period (typically a month at a time) and (2) the delivery of energy to customers. The total energy price generally has a fixed component (basic charge) related to having service available and a usage-based component, related to the delivery and consumption of energy. The commodity is sold and/or delivered to and consumed by the customer simultaneously, and the provisions of the relevant utility commission authorization determine the charges the Company may bill the customer. Given that all revenue recognition criteria are met upon the delivery of energy to customers, revenue is recognized immediately at that time. Revenues from contracts with customers are presented in the Condensed Consolidated Statements of Income in the line item "Utility revenues, exclusive of alternative revenue programs." Non-Derivative Wholesale Contracts The Company has certain wholesale contracts which are not accounted for as derivatives and, accordingly, are within the scope of ASC 606 and considered revenue from contracts with customers. Revenue is recognized as energy is delivered to the customer or the service is available for a specified period of time, consistent with the discussion of rate-regulated sales above. Alternative Revenue Programs (Decoupling) ASC 606 retained existing GAAP associated with alternative revenue programs, which specified that alternative revenue programs are contracts between an entity and a regulator of utilities, not a contract between an entity and a customer. GAAP requires that an entity present revenue arising from alternative revenue programs separately from revenues arising from contracts with customers on the face of the Condensed Consolidated Statements of Income. The Company's decoupling mechanisms (also known as a FCA in Idaho) qualify as alternative revenue programs. Decoupling revenue deferrals are recognized in the Condensed Consolidated Statements of Income during the period they occur (i.e. during the period of revenue shortfall or excess due to fluctuations in customer usage), subject to certain limitations, and a regulatory asset or liability is established that will be surcharged or rebated to customers in future periods. GAAP requires that for any alternative revenue program, like decoupling, the revenue must be expected to be collected from customers within 24 months of the deferral to qualify for recognition in the current period Condensed Consolidated Statement of Income. Any amounts included in the Company's decoupling program that are not expected to be collected from customers within 24 months are not recorded in the financial statements until the period in which revenue recognition criteria are met. The amounts expected to be collected from customers within 24 months represents an estimate that must be made by the Company on an ongoing basis due to it being based on the volumes of electric and natural gas sold to customers on a go-forward basis. Derivative Revenue Most wholesale electric and natural gas transactions (including both physical and financial transactions), and the sale of fuel are considered derivatives, which are specifically scoped out of ASC 606. As such, these revenues are disclosed separately from revenue from contracts with customers. Revenue is recognized for these items upon the settlement/expiration of the derivative contract. Derivative revenue includes those transactions that are entered into and settled within the same month. Other Utility Revenue Other utility revenue includes rent, sales of materials, late fees and other charges that do not represent contracts with customers. Other utility revenue also includes the provision for earnings sharing and the deferral and amortization of refunds to customers associated with the TCJA. This revenue is scoped out of ASC 606, as this revenue does not represent items where a customer is a party that has contracted with the Company to obtain goods or services that are an output of the Company’s ordinary activities in exchange for consideration. As such, these revenues are presented separately from revenue from contracts with customers. Other Considerations for Utility Revenues Gross Versus Net Presentation Revenues and resource costs from Avista Utilities’ settled energy contracts that are “booked out” (not physically delivered) are reported on a net basis as part of derivative revenues. Utility-related taxes collected from customers (primarily state excise taxes and city utility taxes) are taxes that are imposed on Avista Utilities as opposed to being imposed on its customers; therefore, Avista Utilities is the taxpayer and records these transactions on a gross basis in revenue from contracts with customers and operating expense (taxes other than income taxes). The utility-related taxes collected from customers at AEL&P are imposed on the customers rather than AEL&P; therefore, the customers are the taxpayers and AEL&P is acting as their agent. As such, these transactions at AEL&P are presented on a net basis within revenue from contracts with customers. Utility-related taxes that were included in revenue from contracts with customers were as follows for the three and six months ended June 30 (dollars in thousands): Three months ended June 30, Six months ended June 30, 2021 2020 2021 2020 Utility-related taxes $ 13,459 $ 12,879 $ 33,155 $ 31,578 Significant Judgments and Unsatisfied Performance Obligations The only significant judgments involving revenue recognition are estimates surrounding unbilled revenue and receivables from contracts with customers and estimates surrounding the amount of decoupling revenues that will be collected from customers within 24 months (discussed above). The Company has certain capacity arrangements, where the Company has a contractual obligation to provide either electric or natural gas capacity to its customers for a fixed fee. Most of these arrangements are paid for in arrears by the customers and do not result in deferred revenue and only result in receivables from the customers. The Company does have one capacity agreement where the customer makes payments throughout the year. As of June 30, 2021, the Company estimates it had unsatisfied capacity performance obligations of $ 19.8 million, which will be recognized as revenue in future periods as the capacity is provided to the customers. These performance obligations are not reflected in the financial statements, as the Company has not received payment for these services. Disaggregation of Total Operating Revenue The following table disaggregates total operating revenue by segment and source for the three and six months ended June 30 (dollars in thousands): Three months ended June 30, Six months ended June 30, 2021 2020 2021 2020 Avista Utilities Revenue from contracts with customers $ 260,676 $ 235,405 $ 619,289 $ 587,034 Derivative revenues 28,083 24,211 63,064 55,285 Alternative revenue programs ( 3,069 ) 4,362 ( 2,570 ) ( 51 ) Deferrals and amortizations for rate refunds to customers ( 369 ) 2,080 2,820 ( 525 ) Other utility revenues 2,239 2,281 4,817 3,801 Total Avista Utilities 287,560 268,339 687,420 645,544 AEL&P Revenue from contracts with customers 10,487 9,978 23,266 22,104 Deferrals and amortizations for rate refunds to customers ( 48 ) ( 47 ) ( 95 ) ( 95 ) Other utility revenues 108 67 197 191 Total AEL&P 10,547 9,998 23,368 22,200 Other revenues 148 255 337 1,078 Total operating revenues $ 298,255 $ 278,592 $ 711,125 $ 668,822 Utility Revenue from Contracts with Customers by Type and Service The following table disaggregates revenue from contracts with customers associated with the Company's electric operations for the three and six months ended June 30 (dollars in thousands): 2021 2020 Avista AEL&P Total Utility Avista AEL&P Total Utility Three months ended June 30: ELECTRIC OPERATIONS Revenue from contracts with customers Residential $ 84,688 $ 4,251 $ 88,939 $ 78,760 $ 4,190 $ 82,950 Commercial 80,858 6,177 87,035 68,785 5,729 74,514 Industrial 27,429 — 27,429 24,816 — 24,816 Public street and highway lighting 1,869 59 1,928 1,846 59 1,905 Total retail revenue 194,844 10,487 205,331 174,207 9,978 184,185 Transmission 4,801 — 4,801 4,409 — 4,409 Other revenue from contracts with 6,532 — 6,532 3,415 — 3,415 Total electric revenue from contracts $ 206,177 $ 10,487 $ 216,664 $ 182,031 $ 9,978 $ 192,009 Six months ended June 30: ELECTRIC OPERATIONS Revenue from contracts with customers Residential $ 197,911 $ 10,299 $ 208,210 $ 186,737 $ 10,045 $ 196,782 Commercial 157,142 12,848 169,990 147,634 11,938 159,572 Industrial 52,140 — 52,140 49,527 — 49,527 Public street and highway lighting 3,721 119 3,840 3,629 121 3,750 Total retail revenue 410,914 23,266 434,180 387,527 22,104 409,631 Transmission 8,296 — 8,296 8,183 — 8,183 Other revenue from contracts with 12,672 — 12,672 8,705 — 8,705 Total electric revenue from contracts $ 431,882 $ 23,266 $ 455,148 $ 404,415 $ 22,104 $ 426,519 The following table disaggregates revenue from contracts with customers associated with the Company's natural gas operations for the three and six months ended June 30 (dollars in thousands): 2021 2020 Avista Utilities Avista Utilities Three months ended June 30: NATURAL GAS OPERATIONS Revenue from contracts with customers Residential $ 33,703 $ 34,826 Commercial 15,598 14,142 Industrial and interruptible 1,819 1,543 Total retail revenue 51,120 50,511 Transportation 1,973 1,738 Other revenue from contracts with 1,406 1,125 Total natural gas revenue from $ 54,499 $ 53,374 Six months ended June 30: NATURAL GAS OPERATIONS Revenue from contracts with customers Residential $ 121,204 $ 118,998 Commercial 55,373 53,544 Industrial and interruptible 4,043 3,737 Total retail revenue 180,620 176,279 Transportation 4,256 4,090 Other revenue from contracts with 2,531 2,250 Total natural gas revenue from $ 187,407 $ 182,619

Derivatives and Risk Management

Derivatives and Risk Management	6 Months Ended
	Jun. 30, 2021
Derivative Instruments And Hedges [Abstract]
Derivatives and Risk Management	NOTE 5. DERIVATIVES AND RISK MANAGEMENT Energy Commodity Derivatives Avista Corp. 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. Avista Corp. utilizes derivative instruments, such as forwards, futures, swap derivatives and options, in order to manage the various risks relating to these commodity price exposures. Avista Corp. has an energy resources risk policy and control procedures to manage these risks. As part of Avista Corp.'s resource procurement and management operations in the electric business, Avista Corp. engages in an ongoing process of resource optimization, which involves the economic selection from available energy resources to serve Avista Corp.'s load obligations and the use of these resources to capture available economic value through wholesale market transactions. These include sales and purchases of electric capacity and energy, fuel for electric generation, and derivative contracts related to capacity, energy and fuel. Such transactions are part of the process of matching resources with load obligations and hedging a portion of the related financial risks. These transactions range from terms of intra-hour up to multiple years. As part of its resource procurement and management of its natural gas business, Avista Corp. 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 Corp.’s distribution system. However, daily variations in natural gas demand can be significantly different than monthly demand projections. On the basis of these projections, Avista Corp. plans and executes a series of transactions to hedge a portion of its projected natural gas requirements through forward market transactions and derivative instruments. These transactions may extend as much as three natural gas operating years (November through October) into the future. Avista Corp. also leaves a significant portion of its natural gas supply requirements unhedged for purchase in short-term and spot markets. Avista Corp. plans for sufficient natural gas delivery capacity to serve its retail customers for a theoretical peak day event. Avista Corp. generally has more pipeline and storage capacity than what is needed during periods other than a peak-day. Avista Corp. optimizes its natural gas resources by using market opportunities to generate economic value that mitigates the fixed costs. Avista Corp. also optimizes its natural gas storage capacity by purchasing and storing natural gas when prices are traditionally lower, typically in the summer, and withdrawing during higher priced months, typically during the winter. However, if market conditions and prices indicate that Avista Corp. should buy or sell natural gas at other times during the year, Avista Corp. engages in optimization transactions to capture value in the marketplace. Natural gas optimization activities include, but are not limited to, wholesale market sales of surplus natural gas supplies, purchases and sales of natural gas to optimize use of pipeline and storage capacity, and participation in the transportation capacity release market. The following table presents the underlying energy commodity derivative volumes as of June 30, 2021 that are expected to be delivered in each respective year (in thousands of MWhs and mmBTUs): Purchases Sales Electric Derivatives Gas Derivatives Electric Derivatives Gas Derivatives Year Physical Financial Physical Financial Physical Financial Physical Financial Remainder 2021 11 62 5,875 37,413 47 378 4,504 22,943 2022 — — 450 37,835 — 268 2,260 20,820 2023 — — — 12,000 — — 1,360 6,160 2024 — — — 910 — — 1,370 — 2025 — — — — — — 1,115 — As of June 30, 2021 , there are no expected deliveries of energy commodity derivatives after 2 0 25. The following table presents the underlying energy commodity derivative volumes as of December 31, 2020 that are expected to be delivered in each respective year (in thousands of MWhs and mmBTUs): Purchases Sales Electric Derivatives Gas Derivatives Electric Derivatives Gas Derivatives Year Physical Financial Physical Financial Physical Financial Physical Financial 2021 1 224 10,353 65,188 17 451 5,448 39,273 2022 — — 450 25,525 — — 1,360 12,030 2023 — — — 4,950 — — 1,360 900 2024 — — — — — — 1,370 — 2025 — — — — — — 1,115 — As of December 31, 2020 , there are no expected deliveries of energy commodity derivatives after 2 0 25. (1) Physical transactions represent commodity transactions in which Avista Corp. will take or make delivery of either electricity or natural gas; financial transactions represent derivative instruments with delivery of cash in the amount of the benefit or cost but with no physical delivery of the commodity, such as futures, swap derivatives, options, or forward contracts. The electric and natural gas derivative contracts above will be included in either power supply costs or natural gas supply costs during the period they are scheduled to be delivered and will be included in the various deferral and recovery mechanisms (ERM, PCA and PGAs), or in the general rate case process, and are expected to be collected through retail rates from customers. Foreign Currency Exchange Derivatives A significant portion of Avista Corp.’s 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 Corp.’s short-term natural gas transactions and long-term Canadian transportation contracts are committed based on Canadian currency prices. The short-term natural gas transactions are settled within 60 days with U.S. dollars. Avista Corp. hedges a portion of the foreign currency risk by purchasing Canadian currency exchange derivatives when such commodity transactions are initiated. The foreign currency exchange derivatives and the unhedged foreign currency risk have not had a material effect on Avista Corp.’s financial condition, results of operations or cash flows and these differences in cost related to currency fluctuations are included with natural gas supply costs for ratemaking. The following table summarizes the foreign currency exchange derivatives that Avista Corp. has outstanding as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, Number of contracts 18 22 Notional amount (in United States dollars) $ 6,140 $ 3,860 Notional amount (in Canadian dollars) 7,490 4,949 Interest Rate Swap Derivatives Avista Corp. is affected by fluctuating interest rates related to a portion of its existing debt, and future borrowing requirements. Avista Corp. hedges a portion of its interest rate risk with financial derivative instruments, which may include interest rate swap derivatives and U.S. Treasury lock agreements. These interest rate swap derivatives and U.S. Treasury lock agreements are considered economic hedges against fluctuations in future cash flows associated with anticipated debt issuances. The following table summarizes the unsettled interest rate swap derivatives that Avista Corp. has outstanding as of June 30, 2021 and December 31, 2020 (dollars in thousands): Balance Sheet Date Number of Notional Mandatory June 30, 2021 4 $ 45,000 2021 12 130,000 2022 1 10,000 2023 December 31, 2020 4 $ 45,000 2021 11 120,000 2022 1 10,000 2023 The fair value of outstanding interest rate swap derivatives can vary significantly from period to period depending on the total notional amount of swap derivatives outstanding and fluctuations in market interest rates compared to the interest rates fixed by the swaps. Avista Corp. is required to make cash payments to settle the interest rate swap derivatives when the fixed rates are higher than prevailing market rates at the date of settlement. Conversely, Avista Corp. receives cash to settle its interest rate swap derivatives when prevailing market rates at the time of settlement exceed the fixed swap rates. Summary of Outstanding Derivative Instruments The amounts recorded on the Condensed Consolidated Balance Sheet as of June 30, 2021 and December 31, 2020 reflect the offsetting of derivative assets and liabilities where a legal right of offset exists. The following table presents the fair values and locations of derivative instruments recorded on the Condensed Consolidated Balance Sheet as of June 30, 2021 (in thousands): Fair Value Derivative and Balance Sheet Location Gross Gross Collateral Net Asset Foreign currency exchange derivatives Other current liabilities $ — $ ( 88 ) $ — $ ( 88 ) Interest rate swap derivatives Other property and investments-net and other non-current assets 1,318 — — 1,318 Other current liabilities 1,966 ( 38,135 ) 5,850 ( 30,319 ) Energy commodity derivatives Other current assets 3,430 ( 46 ) — 3,384 Other property and investments-net and other non-current assets 5,442 ( 2,425 ) — 3,017 Other current liabilities 32,554 ( 41,589 ) 6,166 ( 2,869 ) Other non-current liabilities and deferred credits 78 ( 4,504 ) — ( 4,426 ) Total derivative instruments recorded on the balance sheet $ 44,788 $ ( 86,787 ) $ 12,016 $ ( 29,983 ) The following table presents the fair values and locations of derivative instruments recorded on the Condensed Consolidated Balance Sheet as of December 31, 2020 (in thousands): Fair Value Derivative and Balance Sheet Location Gross Gross Collateral Net Asset Foreign currency exchange derivatives Other current assets $ 30 $ — $ — $ 30 Interest rate swap derivatives Other current liabilities — ( 19,575 ) 8,050 ( 11,525 ) Other non-current liabilities and deferred credits 952 ( 32,190 ) — ( 31,238 ) Energy commodity derivatives Other current assets 9,203 ( 8,306 ) — 897 Other property and investments-net and other non-current assets 1,755 ( 1,159 ) — 596 Other current liabilities 11,037 ( 14,007 ) 487 ( 2,483 ) Other non-current liabilities and deferred credits 1,725 ( 8,043 ) 129 ( 6,189 ) Total derivative instruments recorded on the balance sheet $ 24,702 $ ( 83,280 ) $ 8,666 $ ( 49,912 ) Exposure to Demands for Collateral Avista Corp.'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 Avista Corp.'s credit ratings or changes in market prices, additional collateral may be required. In periods of price volatility, the level of exposure can change significantly. As a result, sudden and significant demands may be made against Avista Corp.'s credit facilities and cash. Avista Corp. actively monitors the exposure to possible collateral calls and takes steps to mitigate capital requirements. The following table presents Avista Corp.'s collateral outstanding related to its derivative instruments as of June 30, 2021 and December 31, 2020 (in thousands): June 30, December 31, 2021 2020 Energy commodity derivatives Cash collateral posted $ 31,255 $ 4,953 Letters of credit outstanding 20,000 23,500 Balance sheet offsetting 6,166 616 Interest rate swap derivatives Cash collateral posted (offset by net derivative positions) 5,850 8,050 Certain of Avista Corp.’s derivative instruments contain provisions that require Avista Corp. to maintain an "investment grade" credit rating from the major credit rating agencies. If Avista Corp.’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 following table presents the aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position and the amount of additional collateral Avista Corp. could be required to post as of June 30, 2021 and December 31, 2020 (in thousands): June 30, December 31, 2021 2020 Interest rate swap derivatives Liabilities with credit-risk-related contingent features 38,135 50,813 Additional collateral to post 32,285 42,763

Pension Plans and Other Postret

Pension Plans and Other Postretirement Benefit Plans	6 Months Ended
	Jun. 30, 2021
General Discussion Of Pension And Other Postretirement Benefits [Abstract]
Pension Plans and Other Postretirement Benefit Plans	NOTE 6. PENSION PLANS AND OTHE R POSTRETIREMENT BENEFIT PLANS Avista Utilities Avista Utilities’ maintained the same pension and other postretirement plans during the six months ended June 30, 2021 as those described as of December 31, 2020. The Company contributed $ 28 million in cash to the pension plan for the six months ended June 30, 2021 and it expects to contribute $ 42 million in 2021. The Company uses a December 31 measurement date for its defined benefit pension and other postretirement benefit plans. The following table sets forth the components of net periodic benefit costs for the three and six months ended June 30 (dollars in thousands): Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 Three months ended June 30: Service cost $ 6,254 $ 5,550 $ 897 $ 980 Interest cost 6,530 6,967 1,309 1,524 Expected return on plan assets ( 9,704 ) ( 8,625 ) ( 783 ) ( 590 ) Amortization of prior service cost 75 75 ( 275 ) ( 275 ) Net loss recognition 1,688 1,679 1,246 1,243 Net periodic benefit cost $ 4,843 $ 5,646 $ 2,394 $ 2,882 Six months ended June 30: Service cost $ 12,500 $ 11,096 $ 1,905 $ 1,959 Interest cost 13,110 13,938 2,685 3,039 Expected return on plan assets ( 19,479 ) ( 17,750 ) ( 1,458 ) ( 1,220 ) Amortization of prior service cost 150 150 ( 550 ) ( 550 ) Net loss recognition 3,511 3,333 2,419 2,486 Net periodic benefit cost $ 9,792 $ 10,767 $ 5,001 $ 5,714 Total service costs in the table above are recorded to the same accounts as labor expense. Labor and benefits expense is recorded to various projects based on whether the work is a capital project or an operating expense. Approximately 40 percent of all labor and benefits is capitalized to utility property and 60 percent is expensed to utility other operating expenses. The non-service portion of costs in the table above are recorded to other expense below income from operations in the Condensed Consolidated Statements of Income or capitalized as a regulatory asset. Approximately 40 percent of the costs are capitalized to regulatory assets and 60 percent is expensed to the income statement.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2021
Income Tax Disclosure [Abstract]
Income Taxes	NOTE 7. IN COME TAXES In accordance with interim reporting requirements, the Company uses an estimated annual effective tax rate for computing its provisions for income taxes. An estimate of annual income tax expense (or benefit) is made each interim period using estimates for annual pre-tax income, income tax adjustments, and tax credits. The estimated annual effective tax rates do not include discrete events such as tax law changes, examination settlements, accounting method changes, or adjustments to tax expense or benefits attributable to prior years. Discrete events are recorded in the interim period in which they occur or become known. The estimated annual tax rate is applied to year-to-date pre-tax income to determine income tax expense (or benefit) for the interim period consistent with the annual estimate. In subsequent interim periods, income tax expense (or benefit) for the period is computed as the difference between the year-to-date amount reported for the previous interim period and the current period’s year-to-date amount. The following table summarizes the significant factors impacting the difference between our effective tax rate and the federal statutory rate for the three and six months ended June 30 (dollars in thousands): Three months ended June 30, Six months ended June 30, 2021 2020 2021 2020 Federal income taxes at statutory rates $ 3,459 21.0 % $ 2,002 21.0 % $ 20,297 21.0 % $ 13,963 21.0 % Increase (decrease) in tax resulting from: Tax effect of regulatory treatment of utility ( 3,204 ) ( 19.5 ) ( 2,415 ) ( 25.3 ) ( 6,444 ) ( 6.7 ) ( 4,817 ) ( 7.2 ) State income tax expense 280 1.7 ( 325 ) ( 3.4 ) 832 0.9 902 1.4 Non-plant excess deferred turnaround (1) — — ( 8,390 ) ( 88.0 ) — — ( 8,476 ) ( 12.7 ) Settlement of equity awards ( 21 ) ( 0.1 ) — — 909 1.0 165 0.1 Other 1,884 11.5 1,209 12.7 ( 1,032 ) ( 1.1 ) ( 1,124 ) ( 1.7 ) Total income tax expense $ 2,398 14.6 % $ ( 7,919 ) ( 83.0 )% $ 14,562 15.1 % $ 613 0.9 % (1) In March 2020, the WUTC approved an all-party settlement agreement related to electric tax benefits that were set aside for Colstrip in the 2020 general rate case order. In the approved settlement agreement, the parties agreed to utilize $ 10.9 million ($ 8.4 million when tax-effected) of the electric tax benefits to offset costs associated with accelerating the depreciation of Colstrip Units 3 & 4, to reflect a remaining useful life of those units through December 31, 2025. In the second quarter 2020, the Company recorded a one-time increase to depreciation expense with an offsetting decrease to income tax expense.

Committed Lines of Credit

Committed Lines of Credit	6 Months Ended
	Jun. 30, 2021
Short Term Borrowings [Abstract]
Committed Lines of Credit	NOTE 8. COMMITTED LINES OF CREDIT Avista Corp. Avista Corp. has a committed line of credit with various financial institutions in the total amount of $ 400.0 million. In June 2021, the Company entered into an amendment to its committed line of credit that extends the expiration date to June 2026 , with the option to extend for an additional one year period (subject to customary conditions). 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. Balances outstanding and interest rates of borrowings (excluding letters of credit) under the Company’s revolving committed line of credit were as follows as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Balance outstanding at end of period $ 296,000 $ 102,000 Letters of credit outstanding at end of period $ 24,118 $ 27,618 Average interest rate at end of period 1.08 % 1.22 % As of June 30, 2021 and December 31, 2020, the borrowings outstanding under Avista Corp.'s committed line of credit were classified as short-term borrowings on the Condensed Consolidated Balance Sheet. AEL&P AEL&P has a committed line of credit in the amount of $ 25.0 million that expires in November 2024 . There were no borrowings as of June 30, 2021 and $ 1.0 million as of December 31, 2020, and there were no letters of credit outstanding under this committed line of credit as of June 30, 2021 and December 31, 2020. The committed line of credit is secured by non-transferable first mortgage bonds of AEL&P issued to the agent bank that would only become due and payable in the event, and then only to the extent, that AEL&P defaults on its obligations under the committed line of credit. NOTE 9. CRED IT AGREEMENT In April 2020, the Company entered into a one-year Credit Agreement with various financial institutions, in the amount of $ 100.0 million. The Company borrowed the entire $ 100.0 million in April 2020 and repaid the outstanding balance in April 2021 .

Credit Agreement

Credit Agreement	6 Months Ended
	Jun. 30, 2021
Credit Agreement [Abstract]
Committed Lines of Credit	NOTE 8. COMMITTED LINES OF CREDIT Avista Corp. Avista Corp. has a committed line of credit with various financial institutions in the total amount of $ 400.0 million. In June 2021, the Company entered into an amendment to its committed line of credit that extends the expiration date to June 2026 , with the option to extend for an additional one year period (subject to customary conditions). 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. Balances outstanding and interest rates of borrowings (excluding letters of credit) under the Company’s revolving committed line of credit were as follows as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Balance outstanding at end of period $ 296,000 $ 102,000 Letters of credit outstanding at end of period $ 24,118 $ 27,618 Average interest rate at end of period 1.08 % 1.22 % As of June 30, 2021 and December 31, 2020, the borrowings outstanding under Avista Corp.'s committed line of credit were classified as short-term borrowings on the Condensed Consolidated Balance Sheet. AEL&P AEL&P has a committed line of credit in the amount of $ 25.0 million that expires in November 2024 . There were no borrowings as of June 30, 2021 and $ 1.0 million as of December 31, 2020, and there were no letters of credit outstanding under this committed line of credit as of June 30, 2021 and December 31, 2020. The committed line of credit is secured by non-transferable first mortgage bonds of AEL&P issued to the agent bank that would only become due and payable in the event, and then only to the extent, that AEL&P defaults on its obligations under the committed line of credit. NOTE 9. CRED IT AGREEMENT In April 2020, the Company entered into a one-year Credit Agreement with various financial institutions, in the amount of $ 100.0 million. The Company borrowed the entire $ 100.0 million in April 2020 and repaid the outstanding balance in April 2021 .

Long- Term Debt to Affiliated T

Long- Term Debt to Affiliated Trust	6 Months Ended
	Jun. 30, 2021
Long Term Debt To Affiliated Trust [Abstract]
Long- Term Debt To Affiliated Trusts	NOTE 10. LONG-TERM DEB T TO AFFILIATED TRUSTS In 1997 , the Company issued Floating Rate Junior Subordinated Deferrable Interest Debentures, Series B, with a principal amount of $ 51.5 million to Avista Capital II, an affiliated business trust formed by the Company. Avista Capital II issued $ 50.0 million of Preferred Trust Securities with a floating distribution rate of LIBOR plus 0.875 percent, calculated and reset quarterly. The distribution rates paid were as follows during the six months ended June 30, 2021 and the year ended December 31, 2020: June 30, December 31, 2021 2020 Low distribution rate 1.01 % 1.10 % High distribution rate 1.10 % 2.79 % Distribution rate at the end of the period 1.01 % 1.10 % Concurrent with the issuance of the Preferred Trust Securities, Avista Capital II issued $ 1.5 million of Common Trust Securities to the Company. The Preferred Trust Securities may be redeemed at the option of Avista Capital II at any time and mature on June 1, 2037. In December 2000, the Company purchased $ 10.0 million of these Preferred Trust Securities. The Company owns 100 percent of Avista Capital II and has solely and unconditionally guaranteed the payment of distributions on, and redemption price and liquidation amount for, the Preferred Trust Securities to the extent that Avista Capital II has funds available for such payments from the respective debt securities. Upon maturity or prior redemption of such debt securities, the Preferred Trust Securities will be mandatorily redeemed. The Company does not include these capital trusts in its consolidated financial statements as Avista Corp. is not the primary beneficiary. As such, the sole assets of the capital trusts are $ 51.5 million of junior subordinated deferrable interest debentures of Avista Corp., which are reflected on the Condensed Consolidated Balance Sheets. Interest expense to affiliated trusts in the Condensed Consolidated Statements of Income represents interest expense on these debentures.

Fair Value

Fair Value	6 Months Ended
	Jun. 30, 2021
Fair Value Disclosures [Abstract]
Fair Value	NOTE 11. 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 and material capital leases) and long-term debt to affiliated trusts are reported at their carrying value on the Condensed Consolidated Balance Sheets, which may be different than the estimated fair value. See below for the estimated fair value of long-term debt and long-term debt to affiliated trusts. 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 fair values derived from 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, but 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 June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, 2021 December 31, 2020 Carrying Estimated Carrying Estimated Long-term debt (Level 2) $ 963,500 $ 1,167,592 $ 963,500 $ 1,189,824 Long-term debt (Level 3) 1,060,000 1,187,539 1,060,000 1,235,248 Snettisham finance lease obligation (Level 3) 50,283 56,200 51,750 58,700 Long-term debt to affiliated trusts (Level 3) 51,547 63,511 51,547 43,815 These estimates of fair value of long-term debt and long-term debt to affiliated trusts were primarily based on available market information, which generally consists of estimated market prices from third party brokers for debt with similar risk and terms. The price ranges obtained from the third party brokers consisted of par values of 98.02 to 138.97 , where a par value of 100.0 represents the carrying value recorded on the Condensed Consolidated Balance Sheets. Level 2 long-term debt represents publicly issued bonds with quoted market prices; however, due to their limited trading activity, they are classified as Level 2 because brokers must generate quotes and make estimates if there is no trading activity near a period end. Level 3 long-term debt consists of private placement bonds and debt to affiliated trusts, which typically have no secondary trading activity. Fair values in Level 3 are estimated based on market prices from third party brokers using secondary market quotes for debt with similar risk and terms to generate quotes for Avista Corp. bonds. Due to the unique nature of the Snettisham finance lease obligation, the estimated fair value of these items was determined based on a discounted cash flow model using available market information. The Snettisham finance lease obligation was discounted to present value using the Morgan Markets A Ex-Fin discount rate as published on June 30, 2021 and December 31, 2020. 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 June 30, 2021 and December 31, 2020 at fair value on a recurring basis (dollars in thousands): Level 1 Level 2 Level 3 Counterparty Total June 30, 2021 Assets: Energy commodity derivatives $ — $ 41,385 $ — $ ( 34,984 ) $ 6,401 Level 3 energy commodity derivatives: Natural gas exchange agreement — — 119 ( 119 ) — Interest rate swap derivatives — 3,284 — ( 1,966 ) 1,318 Deferred compensation assets: Mutual Funds: Fixed income securities (2) 1,963 — — — 1,963 Equity securities (2) 7,585 — — — 7,585 Total $ 9,548 $ 44,669 $ 119 $ ( 37,069 ) $ 17,267 Liabilities: Energy commodity derivatives $ — $ 42,367 $ — $ ( 41,150 ) $ 1,217 Level 3 energy commodity derivatives: Natural gas exchange agreement — — 6,197 ( 119 ) 6,078 Foreign currency exchange derivatives — 88 — — 88 Interest rate swap derivatives — 38,135 — ( 7,816 ) 30,319 Total $ — $ 80,590 $ 6,197 $ ( 49,085 ) $ 37,702 December 31, 2020 Assets: Energy commodity derivatives $ — $ 23,645 $ — $ ( 22,152 ) $ 1,493 Level 3 energy commodity derivatives: Natural gas exchange agreement — — 75 ( 75 ) — Foreign currency exchange derivatives — 30 — — 30 Interest rate swap derivatives — 952 — ( 952 ) — Deferred compensation assets: Mutual Funds: Fixed income securities (2) 2,471 — — — 2,471 Equity securities (2) 6,228 — — — 6,228 Total $ 8,699 $ 24,627 $ 75 $ ( 23,179 ) $ 10,222 Liabilities: Energy commodity derivatives $ — $ 23,030 $ — $ ( 22,768 ) $ 262 Level 3 energy commodity derivatives: Natural gas exchange agreement — — 8,485 ( 75 ) 8,410 Interest rate swap derivatives — 51,765 — ( 9,002 ) 42,763 Total $ — $ 74,795 $ 8,485 $ ( 31,845 ) $ 51,435 (1) The Company is permitted to net derivative assets and derivative liabilities with the same counterparty when a legally enforceable master netting agreement exists. In addition, the Company nets derivative assets and derivative liabilities against any payables and receivables for cash collateral held or placed with these same counterparties. (2) These assets are included in other property and investments-net and other non-current assets on the Condensed Consolidated Balance Sheets. The difference between the amount of derivative assets and liabilities disclosed in respective levels in the table above and the amount of derivative assets and liabilities disclosed on the Condensed Consolidated Balance Sheets is due to netting arrangements with certain counterparties. See Note 5 for additional discussion of derivative netting. To establish fair value for energy commodity derivatives, the Company uses quoted market prices and forward price curves to estimate the fair value of energy commodity derivative instruments included in Level 2. In particular, electric derivative valuations are performed using market quotes, adjusted for periods in between quotable periods. Natural gas derivative valuations are estimated using New York Mercantile Exchange pricing for similar instruments, adjusted for basin differences, using market quotes. Where observable inputs are available for substantially the full term of the contract, the derivative asset or liability is included in Level 2. To establish fair values for interest rate swap derivatives, the Company uses forward market curves for interest rates for the term of the swaps and discounts the cash flows back to present value using an appropriate discount rate. The discount rate is calculated by third party brokers according to the terms of the swap derivatives and evaluated by the Company for reasonableness, with consideration given to the potential non-performance risk by the Company. Future cash flows of the interest rate swap derivatives are equal to the fixed interest rate in the swap compared to the floating market interest rate multiplied by the notional amount for each period. To establish fair value for foreign currency derivatives, the Company uses forward market curves for Canadian dollars against the US dollar and multiplies the difference between the locked-in price and the market price by the notional amount of the derivative. Forward foreign currency market curves are provided by third party brokers. The Company's credit spread is factored into the locked-in price of the foreign exchange contracts. 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 $ 0.1 million and $ 0.5 million as of June 30, 2021 and December 31, 2020, respectively. Level 3 Fair Value The following table presents the quantitative information which was used to estimate the fair values of the Level 3 assets and liabilities above as of June 30, 2021 (dollars in thousands): Fair Value Valuation Unobservable Range and Weighted June 30, 2021 Technique Input Average Price Natural gas exchange agreement $ ( 6,078 ) Internally derived weighted average cost of gas Forward purchase $ 1.97 - $ 4.10 /mmBTU 2.49 Weighted Average Forward sales prices $ 2.09 - $ 5.08 /mmBTU 3.69 Weighted Average Purchase volumes 40,000 - 310,000 mmBTUs Sales volumes 75,000 - 310,000 mmBTUs The following table presents activity for energy commodity derivative assets (liabilities) measured at fair value using significant unobservable inputs (Level 3) for the six months ended June 30 (dollars in thousands): Natural Gas Three months ended June 30, 2021: Balance as of March 31, 2021 $ ( 6,201 ) Total gains or (losses) (realized/unrealized): Included in regulatory assets/liabilities (1) 268 Settlements ( 145 ) Ending balance as of June 30, 2021 (2) $ ( 6,078 ) Three months ended June 30, 2020: Balance as of March 31, 2020 $ ( 2,253 ) Total gains or (losses) (realized/unrealized): Included in regulatory assets/liabilities (1) ( 391 ) Settlements 16 Ending balance as of June 30, 2020 (2) $ ( 2,628 ) Six months ended June 30, 2021: Balance as of December 31, 2020 $ ( 8,410 ) Total gains (realized/unrealized): Included in regulatory assets/liabilities (1) 3,488 Settlements ( 1,156 ) Ending balance as of June 30, 2021 (2) $ ( 6,078 ) Six months ended June 30, 2020: Balance as of December 31, 2019 $ ( 2,976 ) Total gains (realized/unrealized): Included in regulatory assets/liabilities (1) 94 Settlements 254 Ending balance as of June 30, 2020 (2) $ ( 2,628 ) (1) All gains and losses are included in other regulatory assets and liabilities. There were no gains and losses included in either net income or other comprehensive income during any of the periods presented in the table above. (2) There were no purchases, issuances or transfers from other categories of any derivatives instruments during the periods presented in the table above.

Common Stock

Common Stock	6 Months Ended
	Jun. 30, 2021
Stockholders Equity Note [Abstract]
Common Stock	NOTE 12. CO MMON STOCK The Company has board and regulatory authority to issue approximately 3.9 million shares of common stock in public offerings. During the three and six months ended June 30, 2021 , the Company issued 0.3 million shares under the sales agency agreements relating to the Company's periodic offering program.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	6 Months Ended
	Jun. 30, 2021
Accumulated Other Comprehensive Loss [Abstract]
Accumulated Other Comprehensive Loss	NOTE 13. ACCUMULATED OT HER COMPREHENSIVE LOSS Accumulated other comprehensive loss, net of tax, consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, Unfunded benefit obligation for pensions and other postretirement benefit plans - 3,656 and $ 3,822 , respectively $ 13,755 $ 14,378 The following table details the reclassifications out of accumulated other comprehensive loss to net income by component for the three and six months ended June 30 (dollars in thousands): Amounts Reclassified from Accumulated Other Three months ended June 30, Six months ended June 30, Details about Accumulated Other Comprehensive Loss Components 2021 2020 2021 2020 Amortization of defined benefit pension and Amortization of net prior service cost (a) $ ( 200 ) $ ( 200 ) $ ( 400 ) $ ( 400 ) Amortization of net loss (a) 2,739 3,121 5,930 6,221 Adjustment due to effects of regulation (a) ( 2,149 ) ( 2,642 ) ( 4,741 ) ( 5,283 ) Total before tax (b) 390 279 789 538 Tax expense (b) ( 82 ) ( 59 ) ( 166 ) ( 113 ) Net of tax (b) $ 308 $ 220 $ 623 $ 425 (a) These accumulated other comprehensive loss components are included in the computation of net periodic pension cost (see Note 6 for additional details). (b) Description is also the affected line item on the Condensed Consolidated Statement of Income.

Earnings Per Common Share

Earnings Per Common Share	6 Months Ended
	Jun. 30, 2021
Earnings Per Share [Abstract]
Earnings Per Common Share	NOTE 14. EARNINGS PER COMMON SHAR E The following table presents the computation of basic and diluted earnings per common share for the three and six months ended June 30 (in thousands, except per share amounts): Three months ended June 30, Six months ended June 30, 2021 2020 2021 2020 Numerator: Net income $ 14,074 $ 17,453 $ 82,091 $ 65,877 Denominator: Weighted-average number of common shares outstanding-basic 69,404 67,481 69,348 67,360 Effect of dilutive securities: Performance and restricted stock awards 130 108 172 125 Weighted-average number of common shares outstanding-diluted 69,534 67,589 69,520 67,485 Earnings per common share: Basic $ 0.20 $ 0.26 $ 1.18 $ 0.98 Diluted $ 0.20 $ 0.26 $ 1.18 $ 0.98 There were no shares excluded from the calculation because they were antidilutive.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2021
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	NOTE 15. COMMITMENT S 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’ or AEL&P's operations, the Company intends to seek, to the extent appropriate, recovery of incurred costs through the ratemaking process. Boyds Fire (State of Washington Department of Natural Resources (DNR) v. Avista) In August 2019, the Company was served with a complaint, captioned “State of Washington Department of Natural Resources v. Avista Corporation,” seeking recovery up to $ 4.4 million for fire suppression and investigation costs and related expenses incurred in connection with a wildfire that occurred in Ferry County, Washington in August 2018. Specifically, the complaint alleges that the fire, which became known as the “Boyds Fire,” was caused by a dead ponderosa pine tree falling into an overhead distribution line, and that Avista Corp. was negligent in failing to identify and remove the tree before it came into contact with the line. Avista Corp. disputes that the tree in question was the cause of the fire and that it was negligent in failing to identify and remove it. Additional lawsuits have subsequently been filed by private landowners seeking property damages, and holders of insurance subrogation claims seeking recovery of insurance proceeds paid. The lawsuits were filed in the Superior Court of Ferry County, Washington and subsequently consolidated into a single action. The Company intends to vigorously defend itself in the litigation. However, the Company cannot predict the outcome of these matters. Labor Day Windstorm General In September 2020, a severe windstorm occurred in eastern Washington and northern Idaho. The extreme weather event resulted in customer outages and the cause of multiple wildfires in the region. The Company has become aware of instances where, during the course of the storm, trees and limbs, located in areas outside its maintenance right-of-way, broke under the extraordinary wind conditions and caused damage to its energy delivery system at or near what is believed to be the potential area of origin of a wildfire. Those instances include what has been referred to as: the Babb Road fire (near Malden and Pine City, Washington); the Christensen Road fire (near Airway Heights, Washington); and the Mile Marker 49 fire (near Orofino, Idaho). These wildfires covered, in total, approximately 22,000 acres. The Company currently estimates approximately 230 residential, commercial and other structures were impacted. Parallel investigations by applicable state agencies are ongoing, and the Company is cooperating with those efforts. With respect to the Christensen Road Fire and the Mile Marker 49 Fire, the Company’s investigation determined that the primary cause of the fires was extreme high winds. To date, the Company has not found any evidence that the fires were caused by any deficiencies in its equipment, maintenance activities or vegetation management practices. See further discussion below regarding the Babb Road Fire. In addition to the instances identified above, the Company is aware of a 5-acre fire that occurred in Colfax, Washington, which damaged several residential structures. The Company’s investigation determined that the Company’s facilities were not involved in the ignition of this fire in any way. The Company contends that there is no evidence of negligence and intends to vigorously defend any claims for damages that may be asserted against it with respect to the wildfires arising out of the extreme wind event. Babb Road Fire On May 14, 2021 the Company learned that the DNR had completed its investigation and issued a report on the Babb Road Fire. The Babb Road fire covered approximately 15,000 acres and destroyed approximately 220 structures. There are no reports of personal injury or death resulting from the fire. The DNR report concluded, among other things, that  the fire was ignited when a branch of a multi-dominant Ponderosa Pine tree was broken off by the wind and fell on an Avista Corp. distribution line;  the tree was located approximately 30 feet from the center of Avista Corp.’s distribution line and approximately 20 feet beyond Avista Corp.’s right-of-way;  the tree showed some evidence of insect damage, damage at the top of the tree from porcupines, a small area of scarring where a lateral branch/leader (LBL) had apparently broken off in the past, and some past signs of Gall Rust disease. The DNR report concluded as follows: “It is my opinion that because of the unusual configuration of the tree, and its proximity to the powerline, a closer inspection was warranted. A nearer inspection of the tree should have revealed the cut LBL ends and its previous failure, and necessitated determination of the failure potential of the adjacent LBL, implicated in starting the Babb Road Fire.” The DNR report acknowledged that, other than the multi-dominant nature of the tree, the conditions mentioned above would not have been easily visible without close-up inspection of, or cutting into, the tree. The report also acknowledged that, while the presence of multiple tops would have been visible from the nearby roadway, the tree did not fail at a v-fork due to the presence of multiple tops. The Company contends that applicable inspection standards did not require a closer inspection of the otherwise healthy tree, nor was the Company in any way negligent with respect to its maintenance, inspection or vegetation management practices. The Company intends to vigorously defend any such assertion, if made. At this time, no material claims have been asserted against Avista Corp. for damages resulting from the Babb Road Fire. Colstrip The Washington CETA imposes deadlines by which coal-fired resources, such as Colstrip, must be excluded from the rate base of Washington utilities and by which electricity from such resources may no longer be delivered to Washington retail customers. Not all of the co-owners of Colstrip Units 3 & 4 are Washington utilities subject to CETA, and the co-owners have differing needs for the generating capacity of these units. Accordingly, business disagreements have arisen among the co-owners, including, but not limited to, disagreements as to the shut-down date or dates of these units. These business disagreements, in turn, have led to disagreements as to the interpretation of the Ownership and Operating Agreement, including, but not limited to, the rights of the co-owners to discontinue operations of, or otherwise terminate their interest in, Unit 3 and/or Unit 4. The Ownership and Operating Agreement does contain an arbitration clause that dictates a dispute resolution process to address and resolve these disagreements. At least one owner, Talen Montana, has challenged the validity of the arbitration clause contained in the Ownership and Operating Agreement on the basis that it is not consistent with recently-enacted amendments to Montana Code Section 27-5-323. Along with a majority of the owners of Colstrip, the Company has initiated legal proceedings in Washington to compel arbitration in accordance with the Ownership and Operating Agreement, as well as legal proceedings in Montana to challenge the constitutionality of the amendments to Montana Code Section 27-5-323. In addition to amending Montana Code Section 27-5-323, during the course of the 2021 legislative session the Montana Legislature passed Senate Bill 266, which amended Montana’s Consumer Protection Act (MC 30-14-103 et seq.) to make (i) the failure or refusal of an owner of Colstrip to fund its share of operating costs, and (ii) conduct by one or more of the owners of Colstrip to bring about permanent closure of a generating unit of Colstrip without seeking and obtaining the unanimous consent of the owners, an unfair or deceptive act or practice in the conduct of trade or commerce under Montana’s Consumer Protection Act. Along with a majority of the owners of Colstrip, the Company has initiated legal proceedings to challenge the constitutionality of Senate Bill 266. The Company intends to vigorously defend and protect its interests (and those of its stakeholders) in this and all other legal proceedings relating to Colstrip. The Company is not able to predict the outcome, nor an amount or range of potential impact in the event of an outcome that is adverse to the Company’s interests. National Park Service (NPS) - Natural and Cultural Damage Claim In March 2017, the Company accessed property managed by the National Park Service (NPS) to prevent the imminent failure of a power pole that was surrounded by flood water in the Spokane River. The Company voluntarily reported its actions to the NPS several days later. Thereafter, in March 2018, the NPS notified the Company that it might seek recovery for unspecified costs and damages allegedly caused during the incident pursuant to the System Unit Resource Protection Act (SURPA), 54 U.S.C. 100721 et seq. Almost three years later, in January 2021, the United States Department of Justice (DOJ) requested that the Company and the DOJ renew discussions relating to the matter. By letter dated July 7, 2021, the DOJ communicated that it may seek damages of approximately $ 2 million in connection with the incident for alleged damage to "natural and cultural resources". In addition, the DOJ indicated that it may seek treble damages under the SURPA and state law, bringing its total potential claim to approximately $ 6 million. The Company disputes the position taken by the DOJ with respect to the incident, as well as the nature and extent of the DOJ’s alleged damages, and will vigorously defend itself in any litigation that may arise with respect to the matter. The Company and the DOJ have agreed to engage in fact finding discussions to understand their respective positions and determine whether a resolution of the dispute may be possible. However, the Company cannot predict the outcome of the matter. 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. See "Note 22 of the Notes to Consolidated Financial Statements" in the 2020 Form 10-K for additional discussion regarding other contingencies.

Information by Business Segment

Information by Business Segments	6 Months Ended
	Jun. 30, 2021
Segment Reporting [Abstract]
Information by Business Segments	NOTE 16. 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. The Company's management evaluates performance based on income (loss) from operations before income taxes as well as net income (loss). The accounting policies of the segments are the same as those described in the summary of significant accounting policies. Avista Utilities' business is managed based on the total regulated utility operation; therefore, it is considered one segment. AEL&P is a separate reportable business segment, as it has separate financial reports that are reviewed in detail by the Chief Operating Decision Maker and its operations and risks are sufficiently different from Avista Utilities and the other businesses at AERC that it cannot be aggregated with any other operating segments. The Other category, which is not a reportable segment, includes 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 Alaska Total Utility Other Intersegment Total For the three months ended June 30, 2021: Operating revenues $ 287,560 $ 10,547 $ 298,107 $ 148 $ — $ 298,255 Resource costs 89,515 1,163 90,678 — — 90,678 Other operating expenses 90,728 3,325 94,053 1,159 — 95,212 Depreciation and amortization 53,569 2,497 56,066 73 — 56,139 Income (loss) from operations 29,561 3,275 32,836 ( 1,084 ) — 31,752 Interest expense (2) 24,608 1,523 26,131 131 ( 25 ) 26,237 Income taxes 585 468 1,053 1,345 — 2,398 Net income 7,717 1,299 9,016 5,058 — 14,074 Capital expenditures (3) 114,441 2,183 116,624 537 — 117,161 For the three months ended June 30, 2020: Operating revenues $ 268,340 $ 9,997 $ 278,337 $ 255 $ — $ 278,592 Resource costs 67,069 896 67,965 — — 67,965 Other operating expenses 83,140 3,064 86,204 659 — 86,863 Depreciation and amortization 61,462 2,446 63,908 188 — 64,096 Income (loss) from operations 32,217 3,302 35,519 ( 593 ) — 34,926 Interest expense (2) 24,188 1,561 25,749 130 ( 47 ) 25,832 Income taxes ( 8,004 ) 480 ( 7,524 ) ( 395 ) — ( 7,919 ) Net income (loss) 17,605 1,328 18,933 ( 1,480 ) — 17,453 Capital expenditures (3) 91,867 2,087 93,954 477 — 94,431 For the six months ended June 30, 2021: Operating revenues $ 687,420 $ 23,368 $ 710,788 $ 337 $ — $ 711,125 Resource costs 223,355 1,902 225,257 — — 225,257 Other operating expenses 175,327 6,281 181,608 2,343 — 183,951 Depreciation and amortization 106,293 4,994 111,287 200 — 111,487 Income (loss) from operations 126,254 9,599 135,853 ( 2,206 ) — 133,647 Interest expense (2) 49,408 3,048 52,456 260 ( 66 ) 52,650 Income taxes 11,303 1,801 13,104 1,458 — 14,562 Net income 71,775 4,775 76,550 5,541 — 82,091 Capital expenditures (3) 210,835 2,992 213,827 565 — 214,392 For the six months ended June 30, 2020: Operating revenues $ 645,545 $ 22,199 $ 667,744 $ 1,078 $ — $ 668,822 Resource costs 196,625 887 197,512 — — 197,512 Other operating expenses 174,420 6,280 180,700 2,019 — 182,719 Depreciation and amortization 110,436 4,893 115,329 423 — 115,752 Income (loss) from operations 108,935 9,548 118,483 ( 1,364 ) — 117,119 Interest expense (2) 49,171 3,149 52,320 262 ( 132 ) 52,450 Income taxes ( 600 ) 1,781 1,181 ( 568 ) — 613 Net income (loss) 63,584 4,723 68,307 ( 2,430 ) — 65,877 Capital expenditures (3) 185,923 3,557 189,480 586 — 190,066 Total Assets: As of June 30, 2021: $ 6,272,062 $ 270,922 $ 6,542,984 $ 116,654 $ ( 13,337 ) $ 6,646,301 As of December 31, 2020: $ 6,035,340 $ 268,971 $ 6,304,311 $ 109,658 $ ( 11,872 ) $ 6,402,097 (1) Intersegment eliminations reported as interest expense represent intercompany interest. (2) Including interest expense to affiliated trusts. (3) The capital expenditures for the other businesses are included in other investing activities on the Condensed Consolidated Statements of Cash Flows.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2021
Accounting Policies [Abstract]
Nature of Business	Nature of Business Avista Corp. is primarily an electric and natural gas utility with certain other business ventures. Avista Utilities is an operating division of Avista Corp., comprising its regulated utility operations in the Pacific Northwest. Avista Utilities provides electric distribution and transmission, and natural gas distribution services in parts of eastern Washington and northern Idaho. Avista Utilities also provides natural gas distribution service in parts of northeastern and southwestern Oregon. Avista Utilities has electric generating facilities in Washington, Idaho, Oregon and Montana. Avista Utilities also supplies electricity to a small number of customers in Montana, most of whom are employees who operate the Company's Noxon Rapids generating facility. AERC is a wholly-owned subsidiary of Avista Corp. The primary subsidiary of AERC is AEL&P, which comprises Avista Corp.'s regulated utility operations in Alaska. Avista Capital, a wholly owned non-regulated subsidiary of Avista Corp., is the parent company of all of the subsidiary companies in the non-utility businesses, with the exception of AJT Mining Properties, Inc., which is a subsidiary of AERC. See Note 16 for business segment information.
Basis of Reporting	Basis of Reporting The condensed consolidated financial statements include the assets, liabilities, revenues and expenses of the Company and its subsidiaries 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.
Regulation	Regulation The Company is subject to state regulation in Washington, Idaho, Montana, Oregon and Alaska. The Company is also subject to federal regulation primarily by the FERC, as well as various other federal agencies with regulatory oversight of particular aspects of its operations.
Derivative Assets and Liabilities	Derivative Assets and Liabilities Derivatives are recorded as either assets or liabilities on the Condensed Consolidated Balance Sheets measured at estimated fair value. The WUTC and the IPUC issued accounting orders authorizing Avista Corp. to offset energy 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 delivery. Realized benefits and costs result in adjustments to retail rates through PGAs, the ERM in Washington, the PCA mechanism in Idaho, and periodic general rate cases. The resulting regulatory assets associated with energy commodity derivative instruments have been concluded to be probable of 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. For interest rate swap derivatives, Avista Corp. records all mark-to-market gains and losses in each accounting period as assets and liabilities, as well as offsetting regulatory assets and liabilities, such that there is no income statement impact. The interest rate swap derivatives are risk management tools similar to energy commodity derivatives. Upon settlement of interest rate swap derivatives, the regulatory asset or liability is amortized as a component of interest expense over the term of the associated debt. The Company records an offset of interest rate swap derivative assets and liabilities with regulatory assets and liabilities, based on the prior practice of the commissions to provide recovery through the ratemaking process. The Company has multiple master netting agreements with a variety of entities that allow for cross-commodity netting of derivative agreements with the same counterparty (i.e. power derivatives can be netted with natural gas derivatives). In addition, some master netting agreements allow for the netting of commodity derivatives and interest rate swap derivatives for the same counterparty. The Company does not have any agreements which allow for cross-affiliate netting among multiple affiliated legal entities. The Company nets all derivative instruments when allowed by the agreement for presentation in the Condensed Consolidated Balance Sheets.
Fair Value Measurements	Fair Value Measurements Fair value represents the price that would be received when selling 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, deferred compensation assets, as well as derivatives related to interest rate swaps and foreign currency exchange contracts, are reported at estimated fair value on the Condensed Consolidated Balance Sheets. See Note 11 for the Company’s fair value disclosures.
Contingencies	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 loss contingencies that do not meet these conditions for accrual if there is a reasonable possibility that a material loss may be incurred. See Note 15 for further discussion of the Company's commitments and contingencies.
Inventory	Materials and Supplies, Fuel Stock and Stored Natural Gas Inventories of materials and supplies, fuel stock and stored natural gas are recorded at average cost for our regulated operations and the lower of cost or net realizable value for our non-regulated operations and consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Materials and supplies $ 57,068 $ 53,258 Fuel stock 5,780 4,658 Stored natural gas 19,930 9,535 Total $ 82,778 $ 67,451

Balance Sheet Components (Table

Balance Sheet Components (Tables)	6 Months Ended
	Jun. 30, 2021
Balance Sheet Related Disclosures [Abstract]
Materials and Supplies, Fuel Stock and Stored Natural Gas	Inventories of materials and supplies, fuel stock and stored natural gas are recorded at average cost for our regulated operations and the lower of cost or net realizable value for our non-regulated operations and consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Materials and supplies $ 57,068 $ 53,258 Fuel stock 5,780 4,658 Stored natural gas 19,930 9,535 Total $ 82,778 $ 67,451
Schedule of Other Current Assets	Other current assets consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Collateral posted for derivative instruments after netting with outstanding $ 25,089 $ 4,336 Prepayments 22,444 24,411 Income taxes receivable 25,945 49,814 Other 9,662 6,324 Total $ 83,140 $ 84,885
Schedule of Net Utility Property Recorded at Original Cost Net of Accumulated Depreciation	Net utility property, which is recorded at original cost net of accumulated depreciation, consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Utility plant in service $ 6,980,002 $ 6,809,797 Construction work in progress 185,011 175,767 Total 7,165,013 6,985,564 Less: Accumulated depreciation and amortization 2,064,251 1,993,952 Total net utility property $ 5,100,762 $ 4,991,612
Other Property and Investments-Net and Other Non-Current Assets	Other property and investments-net and other non-current assets consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Operating lease ROU assets $ 70,941 $ 71,891 Equity investments 69,921 59,318 Finance lease ROU assets 45,518 47,338 Non-utility property 18,925 19,508 Notes receivable 14,803 14,454 Investment in affiliated trust 11,547 11,547 Deferred compensation assets 9,660 9,174 Assets held for sale (1) — 3,462 Other 19,749 26,947 Total $ 261,064 $ 263,639 (1) During the second quarter of 2021, the Company sold certain subsidiary assets associated with the Spokane Steam Plant.
Other Current Liabilities	Other current liabilities consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, Accrued taxes other than income taxes $ 42,117 $ 45,099 Derivative liabilities 33,276 14,008 Employee paid time off accruals 28,998 26,495 Accrued interest 16,594 17,083 Pensions and other postretirement benefits 12,429 11,987 Other 38,271 35,159 Total other current liabilities $ 171,685 $ 149,831
Schedule of Other Non-Current Liabilities and Deferred Credits	Other non-current liabilities and deferred credits consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, Operating lease liabilities $ 68,820 $ 67,716 Finance lease liabilities 47,273 48,815 Deferred investment tax credits 29,590 29,866 Asset retirement obligations 16,734 17,194 Derivative liabilities 4,426 37,427 Other 15,700 13,981 Total $ 182,543 $ 214,999
Schedule of Regulatory Assets and Liabilities	Regulatory assets and liabilities consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, 2021 December 31, 2020 Current Non-Current Current Non-Current Regulatory Assets Energy commodity derivatives $ 5,652 $ 1,410 $ 2,073 $ 5,722 Decoupling surcharge 9,768 13,911 7,123 17,123 Pension and other postretirement benefit plans — 194,005 — 198,746 Interest rate swaps — 197,302 — 214,851 Deferred income taxes (1) — 238,234 — 108,517 Settlement with Coeur d'Alene Tribe — 39,484 — 40,043 AFUDC above FERC allowed rate — 48,961 — 47,393 Demand side management programs — 1,449 — 3,814 Utility plant to be abandoned — 27,599 — 28,916 COVID-19 deferrals — 14,292 — 8,166 Other regulatory assets 11,754 93,448 4,477 77,152 Total regulatory assets $ 27,174 $ 870,095 $ 13,673 $ 750,443 Regulatory Liabilities Income tax related liabilities (1) $ 45,431 $ 485,165 $ 14,952 $ 399,677 Deferred power costs 14,996 13,118 20,299 17,570 Decoupling rebate 849 3,754 1,447 1,519 Utility plant retirement costs — 336,940 — 325,832 Interest rate swaps — 15,637 — 15,046 COVID-19 deferrals — 12,680 — 10,949 Other regulatory liabilities 8,900 15,149 9,737 14,227 Total regulatory liabilities $ 70,176 $ 882,443 $ 46,435 $ 784,820 (1) In 2021, the Company received regulatory approval in all jurisdictions to change to flow-through tax treatment of certain basis adjustments, which was $ 127.5 million.

Revenue (Tables)

Revenue (Tables)	6 Months Ended
	Jun. 30, 2021
Revenue From Contract With Customer [Abstract]
Schedule of Utilities Operating Revenue Expense Taxes	Utility-related taxes that were included in revenue from contracts with customers were as follows for the three and six months ended June 30 (dollars in thousands): Three months ended June 30, Six months ended June 30, 2021 2020 2021 2020 Utility-related taxes $ 13,459 $ 12,879 $ 33,155 $ 31,578
Disaggregation of Revenue	Disaggregation of Total Operating Revenue The following table disaggregates total operating revenue by segment and source for the three and six months ended June 30 (dollars in thousands): Three months ended June 30, Six months ended June 30, 2021 2020 2021 2020 Avista Utilities Revenue from contracts with customers $ 260,676 $ 235,405 $ 619,289 $ 587,034 Derivative revenues 28,083 24,211 63,064 55,285 Alternative revenue programs ( 3,069 ) 4,362 ( 2,570 ) ( 51 ) Deferrals and amortizations for rate refunds to customers ( 369 ) 2,080 2,820 ( 525 ) Other utility revenues 2,239 2,281 4,817 3,801 Total Avista Utilities 287,560 268,339 687,420 645,544 AEL&P Revenue from contracts with customers 10,487 9,978 23,266 22,104 Deferrals and amortizations for rate refunds to customers ( 48 ) ( 47 ) ( 95 ) ( 95 ) Other utility revenues 108 67 197 191 Total AEL&P 10,547 9,998 23,368 22,200 Other revenues 148 255 337 1,078 Total operating revenues $ 298,255 $ 278,592 $ 711,125 $ 668,822 Utility Revenue from Contracts with Customers by Type and Service The following table disaggregates revenue from contracts with customers associated with the Company's electric operations for the three and six months ended June 30 (dollars in thousands): 2021 2020 Avista AEL&P Total Utility Avista AEL&P Total Utility Three months ended June 30: ELECTRIC OPERATIONS Revenue from contracts with customers Residential $ 84,688 $ 4,251 $ 88,939 $ 78,760 $ 4,190 $ 82,950 Commercial 80,858 6,177 87,035 68,785 5,729 74,514 Industrial 27,429 — 27,429 24,816 — 24,816 Public street and highway lighting 1,869 59 1,928 1,846 59 1,905 Total retail revenue 194,844 10,487 205,331 174,207 9,978 184,185 Transmission 4,801 — 4,801 4,409 — 4,409 Other revenue from contracts with 6,532 — 6,532 3,415 — 3,415 Total electric revenue from contracts $ 206,177 $ 10,487 $ 216,664 $ 182,031 $ 9,978 $ 192,009 Six months ended June 30: ELECTRIC OPERATIONS Revenue from contracts with customers Residential $ 197,911 $ 10,299 $ 208,210 $ 186,737 $ 10,045 $ 196,782 Commercial 157,142 12,848 169,990 147,634 11,938 159,572 Industrial 52,140 — 52,140 49,527 — 49,527 Public street and highway lighting 3,721 119 3,840 3,629 121 3,750 Total retail revenue 410,914 23,266 434,180 387,527 22,104 409,631 Transmission 8,296 — 8,296 8,183 — 8,183 Other revenue from contracts with 12,672 — 12,672 8,705 — 8,705 Total electric revenue from contracts $ 431,882 $ 23,266 $ 455,148 $ 404,415 $ 22,104 $ 426,519 The following table disaggregates revenue from contracts with customers associated with the Company's natural gas operations for the three and six months ended June 30 (dollars in thousands): 2021 2020 Avista Utilities Avista Utilities Three months ended June 30: NATURAL GAS OPERATIONS Revenue from contracts with customers Residential $ 33,703 $ 34,826 Commercial 15,598 14,142 Industrial and interruptible 1,819 1,543 Total retail revenue 51,120 50,511 Transportation 1,973 1,738 Other revenue from contracts with 1,406 1,125 Total natural gas revenue from $ 54,499 $ 53,374 Six months ended June 30: NATURAL GAS OPERATIONS Revenue from contracts with customers Residential $ 121,204 $ 118,998 Commercial 55,373 53,544 Industrial and interruptible 4,043 3,737 Total retail revenue 180,620 176,279 Transportation 4,256 4,090 Other revenue from contracts with 2,531 2,250 Total natural gas revenue from $ 187,407 $ 182,619

Derivatives and Risk Manageme_2

Derivatives and Risk Management (Tables)	6 Months Ended
	Jun. 30, 2021
Derivative Instruments And Hedges [Abstract]
Schedule of Energy Commodity Derivative Volumes	The following table presents the underlying energy commodity derivative volumes as of June 30, 2021 that are expected to be delivered in each respective year (in thousands of MWhs and mmBTUs): Purchases Sales Electric Derivatives Gas Derivatives Electric Derivatives Gas Derivatives Year Physical Financial Physical Financial Physical Financial Physical Financial Remainder 2021 11 62 5,875 37,413 47 378 4,504 22,943 2022 — — 450 37,835 — 268 2,260 20,820 2023 — — — 12,000 — — 1,360 6,160 2024 — — — 910 — — 1,370 — 2025 — — — — — — 1,115 — As of June 30, 2021 , there are no expected deliveries of energy commodity derivatives after 2 0 25. The following table presents the underlying energy commodity derivative volumes as of December 31, 2020 that are expected to be delivered in each respective year (in thousands of MWhs and mmBTUs): Purchases Sales Electric Derivatives Gas Derivatives Electric Derivatives Gas Derivatives Year Physical Financial Physical Financial Physical Financial Physical Financial 2021 1 224 10,353 65,188 17 451 5,448 39,273 2022 — — 450 25,525 — — 1,360 12,030 2023 — — — 4,950 — — 1,360 900 2024 — — — — — — 1,370 — 2025 — — — — — — 1,115 — As of December 31, 2020 , there are no expected deliveries of energy commodity derivatives after 2 0 25. (1) Physical transactions represent commodity transactions in which Avista Corp. will take or make delivery of either electricity or natural gas; financial transactions represent derivative instruments with delivery of cash in the amount of the benefit or cost but with no physical delivery of the commodity, such as futures, swap derivatives, options, or forward contracts.
Summary of Foreign Currency Exchange Derivatives	The following table summarizes the foreign currency exchange derivatives that Avista Corp. has outstanding as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, Number of contracts 18 22 Notional amount (in United States dollars) $ 6,140 $ 3,860 Notional amount (in Canadian dollars) 7,490 4,949
Summary of Unsettled Interest Rate Swap Derivatives	The following table summarizes the unsettled interest rate swap derivatives that Avista Corp. has outstanding as of June 30, 2021 and December 31, 2020 (dollars in thousands): Balance Sheet Date Number of Notional Mandatory June 30, 2021 4 $ 45,000 2021 12 130,000 2022 1 10,000 2023 December 31, 2020 4 $ 45,000 2021 11 120,000 2022 1 10,000 2023
Schedules of Fair Values and Locations of Derivative Instruments	The following table presents the fair values and locations of derivative instruments recorded on the Condensed Consolidated Balance Sheet as of June 30, 2021 (in thousands): Fair Value Derivative and Balance Sheet Location Gross Gross Collateral Net Asset Foreign currency exchange derivatives Other current liabilities $ — $ ( 88 ) $ — $ ( 88 ) Interest rate swap derivatives Other property and investments-net and other non-current assets 1,318 — — 1,318 Other current liabilities 1,966 ( 38,135 ) 5,850 ( 30,319 ) Energy commodity derivatives Other current assets 3,430 ( 46 ) — 3,384 Other property and investments-net and other non-current assets 5,442 ( 2,425 ) — 3,017 Other current liabilities 32,554 ( 41,589 ) 6,166 ( 2,869 ) Other non-current liabilities and deferred credits 78 ( 4,504 ) — ( 4,426 ) Total derivative instruments recorded on the balance sheet $ 44,788 $ ( 86,787 ) $ 12,016 $ ( 29,983 ) The following table presents the fair values and locations of derivative instruments recorded on the Condensed Consolidated Balance Sheet as of December 31, 2020 (in thousands): Fair Value Derivative and Balance Sheet Location Gross Gross Collateral Net Asset Foreign currency exchange derivatives Other current assets $ 30 $ — $ — $ 30 Interest rate swap derivatives Other current liabilities — ( 19,575 ) 8,050 ( 11,525 ) Other non-current liabilities and deferred credits 952 ( 32,190 ) — ( 31,238 ) Energy commodity derivatives Other current assets 9,203 ( 8,306 ) — 897 Other property and investments-net and other non-current assets 1,755 ( 1,159 ) — 596 Other current liabilities 11,037 ( 14,007 ) 487 ( 2,483 ) Other non-current liabilities and deferred credits 1,725 ( 8,043 ) 129 ( 6,189 ) Total derivative instruments recorded on the balance sheet $ 24,702 $ ( 83,280 ) $ 8,666 $ ( 49,912 )
Schedule of Collateral Outstanding Related to Derivative Instruments	The following table presents Avista Corp.'s collateral outstanding related to its derivative instruments as of June 30, 2021 and December 31, 2020 (in thousands): June 30, December 31, 2021 2020 Energy commodity derivatives Cash collateral posted $ 31,255 $ 4,953 Letters of credit outstanding 20,000 23,500 Balance sheet offsetting 6,166 616 Interest rate swap derivatives Cash collateral posted (offset by net derivative positions) 5,850 8,050 Certain of Avista Corp.’s derivative instruments contain provisions that require Avista Corp. to maintain an "investment grade" credit rating from the major credit rating agencies. If Avista Corp.’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 following table presents the aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position and the amount of additional collateral Avista Corp. could be required to post as of June 30, 2021 and December 31, 2020 (in thousands): June 30, December 31, 2021 2020 Interest rate swap derivatives Liabilities with credit-risk-related contingent features 38,135 50,813 Additional collateral to post 32,285 42,763

Pension Plans and Other Postr_2

Pension Plans and Other Postretirement Benefit Plans (Tables)	6 Months Ended
	Jun. 30, 2021
General Discussion Of Pension And Other Postretirement Benefits [Abstract]
Components of Net Periodic Benefit Cost	The following table sets forth the components of net periodic benefit costs for the three and six months ended June 30 (dollars in thousands): Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 Three months ended June 30: Service cost $ 6,254 $ 5,550 $ 897 $ 980 Interest cost 6,530 6,967 1,309 1,524 Expected return on plan assets ( 9,704 ) ( 8,625 ) ( 783 ) ( 590 ) Amortization of prior service cost 75 75 ( 275 ) ( 275 ) Net loss recognition 1,688 1,679 1,246 1,243 Net periodic benefit cost $ 4,843 $ 5,646 $ 2,394 $ 2,882 Six months ended June 30: Service cost $ 12,500 $ 11,096 $ 1,905 $ 1,959 Interest cost 13,110 13,938 2,685 3,039 Expected return on plan assets ( 19,479 ) ( 17,750 ) ( 1,458 ) ( 1,220 ) Amortization of prior service cost 150 150 ( 550 ) ( 550 ) Net loss recognition 3,511 3,333 2,419 2,486 Net periodic benefit cost $ 9,792 $ 10,767 $ 5,001 $ 5,714

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2021
Income Tax Disclosure [Abstract]
Summary of Significant Factors Impact on Difference Between Effective Tax Rate and Federal Statutory Rate	The following table summarizes the significant factors impacting the difference between our effective tax rate and the federal statutory rate for the three and six months ended June 30 (dollars in thousands): Three months ended June 30, Six months ended June 30, 2021 2020 2021 2020 Federal income taxes at statutory rates $ 3,459 21.0 % $ 2,002 21.0 % $ 20,297 21.0 % $ 13,963 21.0 % Increase (decrease) in tax resulting from: Tax effect of regulatory treatment of utility ( 3,204 ) ( 19.5 ) ( 2,415 ) ( 25.3 ) ( 6,444 ) ( 6.7 ) ( 4,817 ) ( 7.2 ) State income tax expense 280 1.7 ( 325 ) ( 3.4 ) 832 0.9 902 1.4 Non-plant excess deferred turnaround (1) — — ( 8,390 ) ( 88.0 ) — — ( 8,476 ) ( 12.7 ) Settlement of equity awards ( 21 ) ( 0.1 ) — — 909 1.0 165 0.1 Other 1,884 11.5 1,209 12.7 ( 1,032 ) ( 1.1 ) ( 1,124 ) ( 1.7 ) Total income tax expense $ 2,398 14.6 % $ ( 7,919 ) ( 83.0 )% $ 14,562 15.1 % $ 613 0.9 % (1) In March 2020, the WUTC approved an all-party settlement agreement related to electric tax benefits that were set aside for Colstrip in the 2020 general rate case order. In the approved settlement agreement, the parties agreed to utilize $ 10.9 million ($ 8.4 million when tax-effected) of the electric tax benefits to offset costs associated with accelerating the depreciation of Colstrip Units 3 & 4, to reflect a remaining useful life of those units through December 31, 2025. In the second quarter 2020, the Company recorded a one-time increase to depreciation expense with an offsetting decrease to income tax expense.

Committed Lines of Credit (Tabl

Committed Lines of Credit (Tables)	6 Months Ended
	Jun. 30, 2021
Short Term Borrowings [Abstract]
Schedule of Balances Outstanding and Interest Rates of Borrowings (Excluding Letters of Credit)	Balances outstanding and interest rates of borrowings (excluding letters of credit) under the Company’s revolving committed line of credit were as follows as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, 2021 2020 Balance outstanding at end of period $ 296,000 $ 102,000 Letters of credit outstanding at end of period $ 24,118 $ 27,618 Average interest rate at end of period 1.08 % 1.22 %

Long- Term Debt to Affiliated_2

Long- Term Debt to Affiliated Trust (Tables)	6 Months Ended
	Jun. 30, 2021
Long Term Debt To Affiliated Trust [Abstract]
Schedule Of Distribution Rates Paid	The distribution rates paid were as follows during the six months ended June 30, 2021 and the year ended December 31, 2020: June 30, December 31, 2021 2020 Low distribution rate 1.01 % 1.10 % High distribution rate 1.10 % 2.79 % Distribution rate at the end of the period 1.01 % 1.10 %

Fair Value (Tables)

Fair Value (Tables)	6 Months Ended
	Jun. 30, 2021
Fair Value Disclosures [Abstract]
Schedule of Carrying Value and Estimated Fair Value of Financial Instruments	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 June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, 2021 December 31, 2020 Carrying Estimated Carrying Estimated Long-term debt (Level 2) $ 963,500 $ 1,167,592 $ 963,500 $ 1,189,824 Long-term debt (Level 3) 1,060,000 1,187,539 1,060,000 1,235,248 Snettisham finance lease obligation (Level 3) 50,283 56,200 51,750 58,700 Long-term debt to affiliated trusts (Level 3) 51,547 63,511 51,547 43,815
Schedule of Fair Value of Assets and Liabilities Measured on Recurring Basis	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 June 30, 2021 and December 31, 2020 at fair value on a recurring basis (dollars in thousands): Level 1 Level 2 Level 3 Counterparty Total June 30, 2021 Assets: Energy commodity derivatives $ — $ 41,385 $ — $ ( 34,984 ) $ 6,401 Level 3 energy commodity derivatives: Natural gas exchange agreement — — 119 ( 119 ) — Interest rate swap derivatives — 3,284 — ( 1,966 ) 1,318 Deferred compensation assets: Mutual Funds: Fixed income securities (2) 1,963 — — — 1,963 Equity securities (2) 7,585 — — — 7,585 Total $ 9,548 $ 44,669 $ 119 $ ( 37,069 ) $ 17,267 Liabilities: Energy commodity derivatives $ — $ 42,367 $ — $ ( 41,150 ) $ 1,217 Level 3 energy commodity derivatives: Natural gas exchange agreement — — 6,197 ( 119 ) 6,078 Foreign currency exchange derivatives — 88 — — 88 Interest rate swap derivatives — 38,135 — ( 7,816 ) 30,319 Total $ — $ 80,590 $ 6,197 $ ( 49,085 ) $ 37,702 December 31, 2020 Assets: Energy commodity derivatives $ — $ 23,645 $ — $ ( 22,152 ) $ 1,493 Level 3 energy commodity derivatives: Natural gas exchange agreement — — 75 ( 75 ) — Foreign currency exchange derivatives — 30 — — 30 Interest rate swap derivatives — 952 — ( 952 ) — Deferred compensation assets: Mutual Funds: Fixed income securities (2) 2,471 — — — 2,471 Equity securities (2) 6,228 — — — 6,228 Total $ 8,699 $ 24,627 $ 75 $ ( 23,179 ) $ 10,222 Liabilities: Energy commodity derivatives $ — $ 23,030 $ — $ ( 22,768 ) $ 262 Level 3 energy commodity derivatives: Natural gas exchange agreement — — 8,485 ( 75 ) 8,410 Interest rate swap derivatives — 51,765 — ( 9,002 ) 42,763 Total $ — $ 74,795 $ 8,485 $ ( 31,845 ) $ 51,435 (1) The Company is permitted to net derivative assets and derivative liabilities with the same counterparty when a legally enforceable master netting agreement exists. In addition, the Company nets derivative assets and derivative liabilities against any payables and receivables for cash collateral held or placed with these same counterparties. (2) These assets are included in other property and investments-net and other non-current assets on the Condensed Consolidated Balance Sheets.
Schedule of Quantitative Information	The following table presents the quantitative information which was used to estimate the fair values of the Level 3 assets and liabilities above as of June 30, 2021 (dollars in thousands): Fair Value Valuation Unobservable Range and Weighted June 30, 2021 Technique Input Average Price Natural gas exchange agreement $ ( 6,078 ) Internally derived weighted average cost of gas Forward purchase $ 1.97 - $ 4.10 /mmBTU 2.49 Weighted Average Forward sales prices $ 2.09 - $ 5.08 /mmBTU 3.69 Weighted Average Purchase volumes 40,000 - 310,000 mmBTUs Sales volumes 75,000 - 310,000 mmBTUs
Schedule of Activity For Energy Commodity Derivative Assets (Liabilities) Measured At Fair Value Using Significant Unobservable Inputs (Level 3)	The following table presents activity for energy commodity derivative assets (liabilities) measured at fair value using significant unobservable inputs (Level 3) for the six months ended June 30 (dollars in thousands): Natural Gas Three months ended June 30, 2021: Balance as of March 31, 2021 $ ( 6,201 ) Total gains or (losses) (realized/unrealized): Included in regulatory assets/liabilities (1) 268 Settlements ( 145 ) Ending balance as of June 30, 2021 (2) $ ( 6,078 ) Three months ended June 30, 2020: Balance as of March 31, 2020 $ ( 2,253 ) Total gains or (losses) (realized/unrealized): Included in regulatory assets/liabilities (1) ( 391 ) Settlements 16 Ending balance as of June 30, 2020 (2) $ ( 2,628 ) Six months ended June 30, 2021: Balance as of December 31, 2020 $ ( 8,410 ) Total gains (realized/unrealized): Included in regulatory assets/liabilities (1) 3,488 Settlements ( 1,156 ) Ending balance as of June 30, 2021 (2) $ ( 6,078 ) Six months ended June 30, 2020: Balance as of December 31, 2019 $ ( 2,976 ) Total gains (realized/unrealized): Included in regulatory assets/liabilities (1) 94 Settlements 254 Ending balance as of June 30, 2020 (2) $ ( 2,628 ) (1) All gains and losses are included in other regulatory assets and liabilities. There were no gains and losses included in either net income or other comprehensive income during any of the periods presented in the table above. (2) There were no purchases, issuances or transfers from other categories of any derivatives instruments during the periods presented in the table above.

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Loss (Tables)	6 Months Ended
	Jun. 30, 2021
Accumulated Other Comprehensive Loss [Abstract]
Schedule of Accumulated Other Comprehensive Loss, Net of Tax	Accumulated other comprehensive loss, net of tax, consisted of the following as of June 30, 2021 and December 31, 2020 (dollars in thousands): June 30, December 31, Unfunded benefit obligation for pensions and other postretirement benefit plans - 3,656 and $ 3,822 , respectively $ 13,755 $ 14,378
Reclassification out of Accumulated Other Comprehensive Income	The following table details the reclassifications out of accumulated other comprehensive loss to net income by component for the three and six months ended June 30 (dollars in thousands): Amounts Reclassified from Accumulated Other Three months ended June 30, Six months ended June 30, Details about Accumulated Other Comprehensive Loss Components 2021 2020 2021 2020 Amortization of defined benefit pension and Amortization of net prior service cost (a) $ ( 200 ) $ ( 200 ) $ ( 400 ) $ ( 400 ) Amortization of net loss (a) 2,739 3,121 5,930 6,221 Adjustment due to effects of regulation (a) ( 2,149 ) ( 2,642 ) ( 4,741 ) ( 5,283 ) Total before tax (b) 390 279 789 538 Tax expense (b) ( 82 ) ( 59 ) ( 166 ) ( 113 ) Net of tax (b) $ 308 $ 220 $ 623 $ 425 (a) These accumulated other comprehensive loss components are included in the computation of net periodic pension cost (see Note 6 for additional details). (b) Description is also the affected line item on the Condensed Consolidated Statement of Income.

Earnings Per Common Share (Tabl

Earnings Per Common Share (Tables)	6 Months Ended
	Jun. 30, 2021
Earnings Per Share [Abstract]
Schedule of Computation of Basic and Diluted Earnings Per Common Share	The following table presents the computation of basic and diluted earnings per common share for the three and six months ended June 30 (in thousands, except per share amounts): Three months ended June 30, Six months ended June 30, 2021 2020 2021 2020 Numerator: Net income $ 14,074 $ 17,453 $ 82,091 $ 65,877 Denominator: Weighted-average number of common shares outstanding-basic 69,404 67,481 69,348 67,360 Effect of dilutive securities: Performance and restricted stock awards 130 108 172 125 Weighted-average number of common shares outstanding-diluted 69,534 67,589 69,520 67,485 Earnings per common share: Basic $ 0.20 $ 0.26 $ 1.18 $ 0.98 Diluted $ 0.20 $ 0.26 $ 1.18 $ 0.98

Information by Business Segme_2

Information by Business Segments (Tables)	6 Months Ended
	Jun. 30, 2021
Segment Reporting [Abstract]
Schedule of Business Segments	The following table presents information for each of the Company’s business segments (dollars in thousands): Avista Alaska Total Utility Other Intersegment Total For the three months ended June 30, 2021: Operating revenues $ 287,560 $ 10,547 $ 298,107 $ 148 $ — $ 298,255 Resource costs 89,515 1,163 90,678 — — 90,678 Other operating expenses 90,728 3,325 94,053 1,159 — 95,212 Depreciation and amortization 53,569 2,497 56,066 73 — 56,139 Income (loss) from operations 29,561 3,275 32,836 ( 1,084 ) — 31,752 Interest expense (2) 24,608 1,523 26,131 131 ( 25 ) 26,237 Income taxes 585 468 1,053 1,345 — 2,398 Net income 7,717 1,299 9,016 5,058 — 14,074 Capital expenditures (3) 114,441 2,183 116,624 537 — 117,161 For the three months ended June 30, 2020: Operating revenues $ 268,340 $ 9,997 $ 278,337 $ 255 $ — $ 278,592 Resource costs 67,069 896 67,965 — — 67,965 Other operating expenses 83,140 3,064 86,204 659 — 86,863 Depreciation and amortization 61,462 2,446 63,908 188 — 64,096 Income (loss) from operations 32,217 3,302 35,519 ( 593 ) — 34,926 Interest expense (2) 24,188 1,561 25,749 130 ( 47 ) 25,832 Income taxes ( 8,004 ) 480 ( 7,524 ) ( 395 ) — ( 7,919 ) Net income (loss) 17,605 1,328 18,933 ( 1,480 ) — 17,453 Capital expenditures (3) 91,867 2,087 93,954 477 — 94,431 For the six months ended June 30, 2021: Operating revenues $ 687,420 $ 23,368 $ 710,788 $ 337 $ — $ 711,125 Resource costs 223,355 1,902 225,257 — — 225,257 Other operating expenses 175,327 6,281 181,608 2,343 — 183,951 Depreciation and amortization 106,293 4,994 111,287 200 — 111,487 Income (loss) from operations 126,254 9,599 135,853 ( 2,206 ) — 133,647 Interest expense (2) 49,408 3,048 52,456 260 ( 66 ) 52,650 Income taxes 11,303 1,801 13,104 1,458 — 14,562 Net income 71,775 4,775 76,550 5,541 — 82,091 Capital expenditures (3) 210,835 2,992 213,827 565 — 214,392 For the six months ended June 30, 2020: Operating revenues $ 645,545 $ 22,199 $ 667,744 $ 1,078 $ — $ 668,822 Resource costs 196,625 887 197,512 — — 197,512 Other operating expenses 174,420 6,280 180,700 2,019 — 182,719 Depreciation and amortization 110,436 4,893 115,329 423 — 115,752 Income (loss) from operations 108,935 9,548 118,483 ( 1,364 ) — 117,119 Interest expense (2) 49,171 3,149 52,320 262 ( 132 ) 52,450 Income taxes ( 600 ) 1,781 1,181 ( 568 ) — 613 Net income (loss) 63,584 4,723 68,307 ( 2,430 ) — 65,877 Capital expenditures (3) 185,923 3,557 189,480 586 — 190,066 Total Assets: As of June 30, 2021: $ 6,272,062 $ 270,922 $ 6,542,984 $ 116,654 $ ( 13,337 ) $ 6,646,301 As of December 31, 2020: $ 6,035,340 $ 268,971 $ 6,304,311 $ 109,658 $ ( 11,872 ) $ 6,402,097 (1) Intersegment eliminations reported as interest expense represent intercompany interest. (2) Including interest expense to affiliated trusts. (3) The capital expenditures for the other businesses are included in other investing activities on the Condensed Consolidated Statements of Cash Flows.

Balance Sheet Components - Mate

Balance Sheet Components - Materials and Supplies, Fuel Stock and Stored Natural Gas (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Balance Sheet Related Disclosures [Abstract]
Materials and supplies	$ 57,068	$ 53,258
Fuel stock	5,780	4,658
Stored natural gas	19,930	9,535
Total	$ 82,778	$ 67,451

Balance Sheet Components - Sche

Balance Sheet Components - Schedule of Other Current Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Balance Sheet Related Disclosures [Abstract]
Collateral posted for derivative instruments after netting with outstanding derivative liabilities	$ 25,089	$ 4,336
Prepayments	22,444	24,411
Income taxes receivable	25,945	49,814
Other	9,662	6,324
Total	$ 83,140	$ 84,885

Balance Sheet Components - Sc_2

Balance Sheet Components - Schedule of Net Utility Property Recorded at Original Cost Net of Accumulated Depreciation (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Balance Sheet Related Disclosures [Abstract]
Utility plant in service	$ 6,980,002	$ 6,809,797
Construction work in progress	185,011	175,767
Total	7,165,013	6,985,564
Less: Accumulated depreciation and amortization	2,064,251	1,993,952
Total net utility property	$ 5,100,762	$ 4,991,612

Balance Sheet Components - Othe

Balance Sheet Components - Other Property and Investments-Net and Other Non-current Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2021		Dec. 31, 2020
Balance Sheet Related Disclosures [Abstract]
Operating lease ROU assets	$ 70,941		$ 71,891
Equity investments	69,921		59,318
Finance lease ROU assets	45,518		47,338
Non-utility property	18,925		19,508
Notes receivable	14,803		14,454
Investment in affiliated trust	11,547		11,547
Deferred compensation assets	9,660		9,174
Assets held for sale	0	[1]	3,462
Other	19,749		26,947
Total	$ 261,064		$ 263,639
[1]	During the second quarter of 2021, the Company sold certain subsidiary assets associated with the Spokane Steam Plant.

Balance Sheet Components - Ot_2

Balance Sheet Components - Other Current Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Balance Sheet Related Disclosures [Abstract]
Accrued taxes other than income taxes	$ 42,117	$ 45,099
Derivative liabilities	33,276	14,008
Employee paid time off accruals	28,998	26,495
Accrued interest	16,594	17,083
Pensions and other postretirement benefits	12,429	11,987
Other	38,271	35,159
Total other current liabilities	$ 171,685	$ 149,831

Balance Sheet Components - Sc_3

Balance Sheet Components - Schedule of Other Non-Current Liabilities and Deferred Credits (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Balance Sheet Related Disclosures [Abstract]
Operating lease liabilities	$ 68,820	$ 67,716
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Total	Total
Finance lease liabilities	$ 47,273	$ 48,815
Deferred investment tax credits	29,590	29,866
Asset retirement obligations	16,734	17,194
Derivative liabilities	4,426	37,427
Other	15,700	13,981
Total	$ 182,543	$ 214,999

Balance Sheet Components - Sc_4

Balance Sheet Components - Schedule of Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands		Jun. 30, 2021	Dec. 31, 2020
Regulated Asset Liability [Line Items]
Regulatory assets		$ 27,174	$ 13,673
Non-current regulatory assets		870,095	750,443
Regulatory liabilities		70,176	46,435
Non-current regulatory liabilities		882,443	784,820
Income Tax Related [Member]
Regulated Asset Liability [Line Items]
Regulatory liabilities	[1]	45,431	14,952
Non-current regulatory liabilities	[1]	485,165	399,677
Power Deferrals Regulatory Liability [Member]
Regulated Asset Liability [Line Items]
Regulatory liabilities		14,996	20,299
Non-current regulatory liabilities		13,118	17,570
Decoupling Surcharge [Member]
Regulated Asset Liability [Line Items]
Regulatory liabilities		849	1,447
Non-current regulatory liabilities		3,754	1,519
Removal Costs [Member]
Regulated Asset Liability [Line Items]
Regulatory liabilities		0	0
Non-current regulatory liabilities		336,940	325,832
Interest Rate Swaps [Member]
Regulated Asset Liability [Line Items]
Regulatory liabilities		0	0
Non-current regulatory liabilities		15,637	15,046
COVID-19 Deferrals [Member]
Regulated Asset Liability [Line Items]
Regulatory liabilities		0	0
Non-current regulatory liabilities		12,680	10,949
Other Regulatory Assets (Liabilities) [Member]
Regulated Asset Liability [Line Items]
Regulatory liabilities		8,900	9,737
Non-current regulatory liabilities		15,149	14,227
Energy Commodity Derivatives [Member]
Regulated Asset Liability [Line Items]
Regulatory assets		5,652	2,073
Non-current regulatory assets		1,410	5,722
Decoupling Surcharge [Member]
Regulated Asset Liability [Line Items]
Regulatory assets		9,768	7,123
Non-current regulatory assets		13,911	17,123
Pension and Other Postretirement Benefit Plans [Member]
Regulated Asset Liability [Line Items]
Regulatory assets		0	0
Non-current regulatory assets		194,005	198,746
Interest Rate Swaps [Member]
Regulated Asset Liability [Line Items]
Regulatory assets		0	0
Non-current regulatory assets		197,302	214,851
Income Tax Related [Member]
Regulated Asset Liability [Line Items]
Regulatory assets	[1]	0	0
Non-current regulatory assets	[1]	238,234	108,517
Settlement with Coeur d'Alene Tribe [Member]
Regulated Asset Liability [Line Items]
Regulatory assets		0	0
Non-current regulatory assets		39,484	40,043
AFUDC Above FERC Allowed Rate [Member]
Regulated Asset Liability [Line Items]
Regulatory assets		0	0
Non-current regulatory assets		48,961	47,393
Demand Side Management Programs [Member]
Regulated Asset Liability [Line Items]
Regulatory assets		0	0
Non-current regulatory assets		1,449	3,814
Utility Plant to be Abandoned [Member]
Regulated Asset Liability [Line Items]
Regulatory assets		0	0
Non-current regulatory assets		27,599	28,916
COVID-19 Deferrals [Member]
Regulated Asset Liability [Line Items]
Regulatory assets		0	0
Non-current regulatory assets		14,292	8,166
Other Regulatory Assets (Liabilities) [Member]
Regulated Asset Liability [Line Items]
Regulatory assets		11,754	4,477
Non-current regulatory assets		$ 93,448	$ 77,152
[1]	In 2021, the Company received regulatory approval in all jurisdictions to change to flow-through tax treatment of certain basis adjustments, which was $ 127.5 million.

Balance Sheet Components - Sc_5

Balance Sheet Components - Schedule of Regulatory Assets and Liabilities (Parenthetical) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Forecast [Member]
Regulated Asset Liability [Line Items]
Change to flow-through tax treatment of certain basis adjustments	$ 127.5

Revenue - Schedule of Utilities

Revenue - Schedule of Utilities Operating Revenue Expense Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Revenue From Contract With Customer [Abstract]
Utility-related taxes	$ 13,459	$ 12,879	$ 33,155	$ 31,578

Revenue - Additional Informatio

Revenue - Additional Information (Details) $ in Millions	Jun. 30, 2021USD ($)
Revenue From Contract With Customer [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 19.8

Revenue - Disaggregation of Rev

Revenue - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Disaggregation of Revenue [Line Items]
Revenues	$ 298,255	$ 278,592	$ 711,125	$ 668,822
Residential Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	88,939	82,950	208,210	196,782
Commercial Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	87,035	74,514	169,990	159,572
Industrial Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	27,429	24,816	52,140	49,527
Public Street and Highway Lighting Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	1,928	1,905	3,840	3,750
Retail Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	205,331	184,185	434,180	409,631
Transmission Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	4,801	4,409	8,296	8,183
Other Electric Revenues from Contracts With Customers [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	6,532	3,415	12,672	8,705
Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	216,664	192,009	455,148	426,519
Avista Utilities [Member]
Disaggregation of Revenue [Line Items]
Revenues	287,560	268,339	687,420	645,544
Avista Utilities [Member] | Revenue from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues	260,676	235,405	619,289	587,034
Avista Utilities [Member] | Derivative revenues
Disaggregation of Revenue [Line Items]
Revenues	28,083	24,211	63,064	55,285
Avista Utilities [Member] | Alternative Revenue Programs [Member]
Disaggregation of Revenue [Line Items]
Revenues	3,069	4,362	2,570	(51)
Avista Utilities [Member] | Deferrals and Amortizations for Rate Refunds to Customers
Disaggregation of Revenue [Line Items]
Revenues	369	2,080	2,820	(525)
Avista Utilities [Member] | Other Utility Revenues
Disaggregation of Revenue [Line Items]
Revenues	2,239	2,281	4,817	3,801
Alaska Electric Light & Power [Member]
Disaggregation of Revenue [Line Items]
Revenues	10,547	9,998	23,368	22,200
Alaska Electric Light & Power [Member] | Revenue from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues	10,487	9,978	23,266	22,104
Alaska Electric Light & Power [Member] | Deferrals and Amortizations for Rate Refunds to Customers
Disaggregation of Revenue [Line Items]
Revenues	48	(47)	95	(95)
Alaska Electric Light & Power [Member] | Other Utility Revenues
Disaggregation of Revenue [Line Items]
Revenues	108	67	197	191
Corporate and Other [Member] | Other Revenues
Disaggregation of Revenue [Line Items]
Revenues	148	255	337	1,078
Avista Utilities [Member] | Residential Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	84,688	78,760	197,911	186,737
Avista Utilities [Member] | Commercial Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	80,858	68,785	157,142	147,634
Avista Utilities [Member] | Industrial Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	27,429	24,816	52,140	49,527
Avista Utilities [Member] | Public Street and Highway Lighting Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	1,869	1,846	3,721	3,629
Avista Utilities [Member] | Retail Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	194,844	174,207	410,914	387,527
Avista Utilities [Member] | Transmission Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	4,801	4,409	8,296	8,183
Avista Utilities [Member] | Other Electric Revenues from Contracts With Customers [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	6,532	3,415	12,672	8,705
Avista Utilities [Member] | Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	206,177	182,031	431,882	404,415
Avista Utilities [Member] | Residential Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	33,703	34,826	121,204	118,998
Avista Utilities [Member] | Commercial Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	15,598	14,142	55,373	53,544
Avista Utilities [Member] | Industrial and Interruptible Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	1,819	1,543	4,043	3,737
Avista Utilities [Member] | Retail Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	51,120	50,511	180,620	176,279
Avista Utilities [Member] | Transportation Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	1,973	1,738	4,256	4,090
Avista Utilities [Member] | Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	54,499	53,374	187,407	182,619
Avista Utilities [Member] | Other Natural Gas Revenues from Contracts With Customers [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	1,406	1,125	2,531	2,250
Alaska Electric Light & Power [Member] | Residential Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	4,251	4,190	10,299	10,045
Alaska Electric Light & Power [Member] | Commercial Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	6,177	5,729	12,848	11,938
Alaska Electric Light & Power [Member] | Industrial Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	0	0	0	0
Alaska Electric Light & Power [Member] | Public Street and Highway Lighting Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	59	59	119	121
Alaska Electric Light & Power [Member] | Retail Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	10,487	9,978	23,266	22,104
Alaska Electric Light & Power [Member] | Transmission Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	0	0	0	0
Alaska Electric Light & Power [Member] | Other Electric Revenues from Contracts With Customers [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	0	0	0	0
Alaska Electric Light & Power [Member] | Electric [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer including assessed tax	$ 10,487	$ 9,978	$ 23,266	$ 22,104

Derivatives and Risk Manageme_3

Derivatives and Risk Management - Schedule of Energy Commodity Derivative Volumes (Details) MWh in Thousands, MMBTU in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2021MMBTUMWh	Dec. 31, 2020MMBTUMWh
Purchase [Member] | Physical [Member] | Electric Derivative [Member]
Energy Commodity Derivative Volumes [Line Items]
2021 | MWh	11	1
2022 | MWh	0	0
2023 | MWh	0	0
2024 | MWh	0	0
2025 | MWh	0	0
Purchase [Member] | Physical [Member] | Gas Derivative [Member]
Energy Commodity Derivative Volumes [Line Items]
2021 | MMBTU	5,875	10,353
2022 | MMBTU	450	450
2023 | MMBTU	0	0
2024 | MMBTU	0	0
2025 | MMBTU	0	0
Purchase [Member] | Financial [Member] | Electric Derivative [Member]
Energy Commodity Derivative Volumes [Line Items]
2021 | MWh	62	224
2022 | MWh	0	0
2023 | MWh	0	0
2024 | MWh	0	0
2025 | MWh	0	0
Purchase [Member] | Financial [Member] | Gas Derivative [Member]
Energy Commodity Derivative Volumes [Line Items]
2021 | MMBTU	37,413	65,188
2022 | MMBTU	37,835	25,525
2023 | MMBTU	12,000	4,950
2024 | MMBTU	910	0
2025 | MMBTU	0	0
Sales [Member] | Physical [Member] | Electric Derivative [Member]
Energy Commodity Derivative Volumes [Line Items]
2021 | MWh	47	17
2022 | MWh	0	0
2023 | MWh	0	0
2024 | MWh	0	0
2025 | MWh	0	0
Sales [Member] | Physical [Member] | Gas Derivative [Member]
Energy Commodity Derivative Volumes [Line Items]
2021 | MMBTU	4,504	5,448
2022 | MMBTU	2,260	1,360
2023 | MMBTU	1,360	1,360
2024 | MMBTU	1,370	1,370
2025 | MMBTU	1,115	1,115
Sales [Member] | Financial [Member] | Electric Derivative [Member]
Energy Commodity Derivative Volumes [Line Items]
2021 | MWh	378	451
2022 | MWh	268	0
2023 | MWh	0	0
2024 | MWh	0	0
2025 | MWh	0	0
Sales [Member] | Financial [Member] | Gas Derivative [Member]
Energy Commodity Derivative Volumes [Line Items]
2021 | MMBTU	22,943	39,273
2022 | MMBTU	20,820	12,030
2023 | MMBTU	6,160	900
2024 | MMBTU	0	0
2025 | MMBTU	0	0

Derivatives and Risk Manageme_4

Derivatives and Risk Management - Additional Information (Details)	6 Months Ended	12 Months Ended
	Jun. 30, 2021MMBTUMWh	Dec. 31, 2020MWhMMBTU
Canadian [Member]
Derivative [Line Items]
Number of days Canadian currency prices are settled with U.S. dollars	60 days
Purchase [Member] | Physical [Member] | Electric Derivative [Member]
Derivative [Line Items]
Expected deliveries of energy commodity derivatives after five years | MWh	0	0
Purchase [Member] | Physical [Member] | Gas Derivative [Member]
Derivative [Line Items]
Expected deliveries of energy commodity derivatives after five years | MMBTU	0	0
Purchase [Member] | Financial [Member] | Electric Derivative [Member]
Derivative [Line Items]
Expected deliveries of energy commodity derivatives after five years | MWh	0	0
Purchase [Member] | Financial [Member] | Gas Derivative [Member]
Derivative [Line Items]
Expected deliveries of energy commodity derivatives after five years | MMBTU	0	0
Sales [Member] | Physical [Member] | Electric Derivative [Member]
Derivative [Line Items]
Expected deliveries of energy commodity derivatives after five years | MWh	0	0
Sales [Member] | Physical [Member] | Gas Derivative [Member]
Derivative [Line Items]
Expected deliveries of energy commodity derivatives after five years | MMBTU	0	0
Sales [Member] | Financial [Member] | Electric Derivative [Member]
Derivative [Line Items]
Expected deliveries of energy commodity derivatives after five years | MWh	0	0
Sales [Member] | Financial [Member] | Gas Derivative [Member]
Derivative [Line Items]
Expected deliveries of energy commodity derivatives after five years | MMBTU	0	0

Derivatives and Risk Manageme_5

Derivatives and Risk Management - Summary of Foreign Currency Exchange Derivatives (Details) $ in Thousands, $ in Thousands	Jun. 30, 2021USD ($)DerivativeContracts	Jun. 30, 2021CAD ($)DerivativeContracts	Dec. 31, 2020USD ($)DerivativeContracts	Dec. 31, 2020CAD ($)DerivativeContracts
Foreign Currency Fair Value Hedge Derivative [Line Items]
Number of contracts | DerivativeContracts	18	18	22	22
United States of America, Dollars [Member] | Foreign Exchange Contract [Member]
Foreign Currency Fair Value Hedge Derivative [Line Items]
Notional amount	$ 6,140		$ 3,860
Canada, Dollars [Member] | Foreign Exchange Contract [Member]
Foreign Currency Fair Value Hedge Derivative [Line Items]
Notional amount		$ 7,490		$ 4,949

Derivatives and Risk Manageme_6

Derivatives and Risk Management - Summary of Unsettled Interest Rate Swap Derivatives (Details) - Interest Rate Swap [Member] $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2021USD ($)Contract	Dec. 31, 2020USD ($)Contract
2021 [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts | Contract	4	4
Notional Amount | $	$ 45,000	$ 45,000
Mandatory Cash Settlement Date	2021	2021
2022 [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts | Contract	12	11
Notional Amount | $	$ 130,000	$ 120,000
Mandatory Cash Settlement Date	2022	2022
2023 [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts | Contract	1	1
Notional Amount | $	$ 10,000	$ 10,000
Mandatory Cash Settlement Date	2023	2023

Derivatives and Risk Manageme_7

Derivatives and Risk Management - Schedules of Fair Values and Locations of Derivative Instruments (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Derivatives, Fair Value [Line Items]
Gross Asset	$ 44,788	$ 24,702
Gross Liability	(86,787)	(83,280)
Collateral Netted	12,016	8,666
Net Asset (Liability) on Balance Sheet	(29,983)	(49,912)
Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Collateral Netted	6,166	616
Other Current Liabilities [Member] | Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Gross Asset	0
Gross Liability	(88)
Collateral Netted	0
Net Asset (Liability) on Balance Sheet	(88)
Other Current Liabilities [Member] | Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Gross Asset	1,966	0
Gross Liability	(38,135)	(19,575)
Collateral Netted	5,850	8,050
Net Asset (Liability) on Balance Sheet	(30,319)	(11,525)
Other Current Liabilities [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Gross Asset	32,554	11,037
Gross Liability	(41,589)	(14,007)
Collateral Netted	6,166	487
Net Asset (Liability) on Balance Sheet	(2,869)	(2,483)
Other Current Assets [Member] | Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Gross Asset		30
Gross Liability		0
Collateral Netted		0
Net Asset (Liability) on Balance Sheet		30
Other Current Assets [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Gross Asset	3,430	9,203
Gross Liability	(46)	(8,306)
Collateral Netted	0	0
Net Asset (Liability) on Balance Sheet	3,384	897
Other Property And Investments Net And Other Non-current Assets [Member] | Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Gross Asset	1,318
Gross Liability	0
Collateral Netted	0
Net Asset (Liability) on Balance Sheet	1,318
Other Property And Investments Net And Other Non-current Assets [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Gross Asset	5,442	1,755
Gross Liability	(2,425)	(1,159)
Collateral Netted	0	0
Net Asset (Liability) on Balance Sheet	3,017	596
Other Noncurrent Liabilities [Member] | Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Gross Asset		952
Gross Liability		(32,190)
Collateral Netted		0
Net Asset (Liability) on Balance Sheet		(31,238)
Other Noncurrent Liabilities [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Gross Asset	78	1,725
Gross Liability	(4,504)	(8,043)
Collateral Netted	0	129
Net Asset (Liability) on Balance Sheet	$ (4,426)	$ (6,189)

Derivatives and Risk Manageme_8

Derivatives and Risk Management - Schedule of Collateral Outstanding Related to Derivative Instruments (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Derivative [Line Items]
Balance sheet offsetting	$ 12,016	$ 8,666
Commodity Contracts [Member]
Derivative [Line Items]
Cash collateral posted	31,255	4,953
Letters of credit outstanding	20,000	23,500
Balance sheet offsetting	6,166	616
Interest Rate Swap [Member]
Derivative [Line Items]
Cash collateral posted	5,850	8,050
Liabilities with credit-risk-related contingent features	38,135	50,813
Additional collateral to post	$ 32,285	$ 42,763

Pension Plans and Other Postr_3

Pension Plans and Other Postretirement Benefit Plans - Additional Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020
Defined Benefit Plan Disclosure [Line Items]
Payment for pension benefits	$ 28,000	$ 14,600
Percentage of service related net periodic benefit costs capitalized to utility property	40.00%
Percentage of service related net periodic benefit costs recorded to operating expenses	60.00%
Percentage of non-service related net periodic benefit costs capitalized to regulatory assets	40.00%
Percentage of non-service related net periodic benefit costs recorded to other expense	60.00%
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected contributions to pension plan	$ 42,000

Pension Plans and Other Postr_4

Pension Plans and Other Postretirement Benefit Plans - Components of Net Periodic Benefit Costs (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 6,254	$ 5,550	$ 12,500	$ 11,096
Interest cost	6,530	6,967	13,110	13,938
Expected return on plan assets	(9,704)	(8,625)	(19,479)	(17,750)
Amortization of prior service cost	75	75	150	150
Net loss recognition	1,688	1,679	3,511	3,333
Net periodic benefit cost	4,843	5,646	9,792	10,767
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	897	980	1,905	1,959
Interest cost	1,309	1,524	2,685	3,039
Expected return on plan assets	(783)	(590)	(1,458)	(1,220)
Amortization of prior service cost	(275)	(275)	(550)	(550)
Net loss recognition	1,246	1,243	2,419	2,486
Net periodic benefit cost	$ 2,394	$ 2,882	$ 5,001	$ 5,714

Income Taxes - Summary of Signi

Income Taxes - Summary of Significant Factors Impact on Difference Between Effective Tax Rate and Federal Statutory Rate (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Income Tax Disclosure [Abstract]
Federal income taxes at statutory rates	$ 3,459	$ 2,002	$ 20,297	$ 13,963
Tax effect of regulatory treatment of utility plant differences	(3,204)	(2,415)	(6,444)	(4,817)
State income tax expense	280	(325)	832	902
Non-plant excess deferred turnaround	0	(8,390)	0	(8,476)
Settlement of equity awards	(21)	0	909	165
Other	1,884	1,209	(1,032)	(1,124)
Total income tax expense	$ 2,398	$ (7,919)	$ 14,562	$ 613
Federal income taxes at statutory rates	21.00%	21.00%	21.00%	21.00%
Tax effect of regulatory treatment of utility plant differences	(19.50%)	(25.30%)	(6.70%)	(7.20%)
State income tax expense	1.70%	(3.40%)	0.90%	1.40%
Non-plant excess deferred turnaround	0.00%	(88.00%)	0.00%	(12.70%)
Settlement of equity awards	(0.10%)	0.00%	1.00%	0.10%
Other	11.50%	12.70%	(1.10%)	(1.70%)
Total income tax expense	14.60%	(83.00%)	15.10%	0.90%

Income Taxes - Summary of Sig_2

Income Taxes - Summary of Significant Factors Impact on Difference Between Effective Tax Rate and Federal Statutory Rate (Parenthetical) (Details) - USD ($) $ in Thousands		1 Months Ended	3 Months Ended		6 Months Ended
		Mar. 31, 2020	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Regulatory Liabilities [Line Items]
Regulatory liabilities			$ 70,176		$ 70,176		$ 46,435
Non-plant excess deferred turnaround, amount			0	$ 8,390	0	$ 8,476
Income Tax Related [Member]
Regulatory Liabilities [Line Items]
Regulatory liabilities	[1]		$ 45,431		$ 45,431		$ 14,952
WUTC [Member]
Regulatory Liabilities [Line Items]
Non-plant excess deferred turnaround, amount		$ 8,400
WUTC [Member] | Income Tax Related [Member]
Regulatory Liabilities [Line Items]
Regulatory liabilities		$ 10,900
[1]	In 2021, the Company received regulatory approval in all jurisdictions to change to flow-through tax treatment of certain basis adjustments, which was $ 127.5 million.

Committed Lines of Credit - Add

Committed Lines of Credit - Additional Information (Details) - USD ($)	1 Months Ended	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2021	Dec. 31, 2020	Apr. 30, 2014
Avista Utilities [Member]
Short-term Debt [Line Items]
Line of credit facility, maximum borrowing capacity				$ 400,000,000
Line of credit facility, expiration date	2026-06
Line of credit facility additional expiration period		1 year
Line of credit, current	$ 296,000,000	$ 296,000,000	$ 102,000,000
Letters of credit outstanding at end of period	24,118,000	24,118,000	27,618,000
Alaska Electric Light & Power [Member]
Short-term Debt [Line Items]
Line of credit facility, maximum borrowing capacity	25,000,000	$ 25,000,000
Line of credit facility, expiration date		2024-11
Line of credit, current	0	$ 0	1,000,000
Letters of credit outstanding at end of period	$ 0	$ 0	$ 0

Committed Lines of Credit - Sch

Committed Lines of Credit - Schedule of Balances Outstanding and Interest Rates of Borrowings (Excluding Letters of Credit) (Details) - Avista Utilities [Member] - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Short-term Debt [Line Items]
Balance outstanding at end of period	$ 296,000	$ 102,000
Letters of credit outstanding at end of period	$ 24,118	$ 27,618
Average interest rate at end of period	1.08%	1.22%

Credit Agreement - Additional I

Credit Agreement - Additional Information (Details) - Avista Utilities [Member] $ in Millions	1 Months Ended
	Apr. 30, 2020USD ($)
Short-term Debt [Line Items]
Credit agreement amount borrowed	$ 100
Credit agreement, expiration month and year	2021-04
Maximum borrowing capacity credit agreement	$ 100

Long- Term Debt to Affiliated_3

Long- Term Debt to Affiliated Trust - Narrative (Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2021	Dec. 31, 2000
Debt Instrument [Line Items]
Payments for repurchase of trust preferred securities		$ 10
1997 Floating Rate Junior Subordinated Deferrable Interest Debentures, Series B [Member] | Avista Capital II [Member]
Debt Instrument [Line Items]
Junior subordinated debenture issuance date	1997
Principal amount	$ 51.5
Avista Corp [Member]
Debt Instrument [Line Items]
Noncontrolling interest, ownership percentage by parent	100.00%
Trust Preferred Securities Subject to Mandatory Redemption [Member] | 1997 Floating Rate Junior Subordinated Deferrable Interest Debentures, Series B [Member] | Avista Capital II [Member]
Debt Instrument [Line Items]
Principal amount	$ 50
Debt instrument, description of variable rate basis	LIBOR
Debt instrument, basis spread on variable rate	0.875%
Common Trust Securities [Member] | 1997 Floating Rate Junior Subordinated Deferrable Interest Debentures, Series B [Member] | Avista Capital II [Member]
Debt Instrument [Line Items]
Principal amount	$ 1.5

Long-Term Debt to Affiliated Tr

Long-Term Debt to Affiliated Trust - Schedule of Distribution Rates Paid (Details) - Trust Preferred Securities Subject to Mandatory Redemption [Member]	Jun. 30, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Interest rate	1.01%	1.10%
Minimum [Member]
Debt Instrument [Line Items]
Interest rate	1.01%	1.10%
Maximum [Member]
Debt Instrument [Line Items]
Interest rate	1.10%	2.79%

Fair Value - Schedule of Carryi

Fair Value - Schedule of Carrying Value and Estimated Fair Value of Financial Instruments (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Level 2 [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 963,500	$ 963,500
Level 2 [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	1,167,592	1,189,824
Level 3 [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	1,060,000	1,060,000
Level 3 [Member] | Reported Value Measurement [Member] | Alaska Electric Light & Power [Member] | Finance Lease [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Finance Lease, Liability	50,283	51,750
Level 3 [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	1,187,539	1,235,248
Level 3 [Member] | Estimate of Fair Value Measurement [Member] | Alaska Electric Light & Power [Member] | Finance Lease [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Finance Lease, Liability	56,200	58,700
Affiliated Entity [Member] | Level 3 [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	51,547	51,547
Affiliated Entity [Member] | Level 3 [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 63,511	$ 43,815

Fair Value - Additional Informa

Fair Value - Additional Information (Details) $ in Thousands	Jun. 30, 2021USD ($)	Dec. 31, 2020USD ($)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	$ 39,027	$ 14,196
Fixed Income Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	$ 100	$ 500
Measurement Input, Quoted Price [Member] | Secured and Unsecured Debt [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, measurement input	100
Measurement Input, Quoted Price [Member] | Minimum [Member] | Secured and Unsecured Debt [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, measurement input	98.02
Measurement Input, Quoted Price [Member] | Maximum [Member] | Secured and Unsecured Debt [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, measurement input	138.97

Fair Value - Schedule of Fair V

Fair Value - Schedule of Fair Value of Assets and Liabilities Measured on Recurring Basis (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset	$ 44,788	$ 24,702
Liability	86,787	83,280
Fair Value, Recurring [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Assets, Fair Value Disclosure	17,267	10,222
Financial Liabilities Fair Value Disclosure	37,702	51,435
Counterparty and Cash Collateral Netting, Assets	(37,069)	(23,179)
Counterparty and Cash Collateral Netting, Liabilities	(49,085)	(31,845)
Fair Value, Recurring [Member] | Fixed Income Funds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred compensation assets:	1,963	2,471
Counterparty and Cash Collateral Netting, Assets	0
Fair Value, Recurring [Member] | Equity Funds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred compensation assets:	7,585	6,228
Counterparty and Cash Collateral Netting, Assets	0
Fair Value, Recurring [Member] | Energy Commodity Derivatives [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Counterparty and Cash Collateral Netting, Assets	(34,984)	(22,152)
Derivative Asset	6,401	1,493
Counterparty and Cash Collateral Netting, Liabilities	(41,150)	(22,768)
Derivative Liability	1,217	262
Fair Value, Recurring [Member] | Interest Rate Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Counterparty and Cash Collateral Netting, Assets	(1,966)	(952)
Derivative Asset	1,318
Counterparty and Cash Collateral Netting, Liabilities	(7,816)	(9,002)
Derivative Liability	30,319	42,763
Fair Value, Recurring [Member] | Natural Gas Exchange Agreements [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Counterparty and Cash Collateral Netting, Assets	(119)	(75)
Derivative Asset	0
Counterparty and Cash Collateral Netting, Liabilities	(119)	(75)
Derivative Liability	6,078	8,410
Fair Value, Recurring [Member] | Foreign Exchange Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset		30
Counterparty and Cash Collateral Netting, Liabilities	0
Derivative Liability	88
Fair Value, Recurring [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Assets, Fair Value Disclosure	9,548	8,699
Financial Liabilities Fair Value Disclosure	0
Fair Value, Recurring [Member] | Level 1 [Member] | Fixed Income Funds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred compensation assets:	1,963	2,471
Fair Value, Recurring [Member] | Level 1 [Member] | Equity Funds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred compensation assets:	7,585	6,228
Fair Value, Recurring [Member] | Level 1 [Member] | Energy Commodity Derivatives [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset	0
Liability	0
Fair Value, Recurring [Member] | Level 1 [Member] | Interest Rate Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset	0
Liability	0
Fair Value, Recurring [Member] | Level 1 [Member] | Natural Gas Exchange Agreements [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset	0
Liability	0
Fair Value, Recurring [Member] | Level 1 [Member] | Foreign Exchange Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Liability	0
Fair Value, Recurring [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Assets, Fair Value Disclosure	44,669	24,627
Financial Liabilities Fair Value Disclosure	80,590	74,795
Fair Value, Recurring [Member] | Level 2 [Member] | Fixed Income Funds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred compensation assets:	0
Fair Value, Recurring [Member] | Level 2 [Member] | Equity Funds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred compensation assets:	0
Fair Value, Recurring [Member] | Level 2 [Member] | Energy Commodity Derivatives [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset	41,385	23,645
Liability	42,367	23,030
Fair Value, Recurring [Member] | Level 2 [Member] | Interest Rate Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset	3,284	952
Liability	38,135	51,765
Fair Value, Recurring [Member] | Level 2 [Member] | Natural Gas Exchange Agreements [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset	0
Liability	0
Fair Value, Recurring [Member] | Level 2 [Member] | Foreign Exchange Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset		30
Liability	88
Fair Value, Recurring [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Assets, Fair Value Disclosure	119	75
Financial Liabilities Fair Value Disclosure	6,197	8,485
Fair Value, Recurring [Member] | Level 3 [Member] | Fixed Income Funds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred compensation assets:	0
Fair Value, Recurring [Member] | Level 3 [Member] | Equity Funds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred compensation assets:	0
Fair Value, Recurring [Member] | Level 3 [Member] | Energy Commodity Derivatives [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset	0
Liability	0
Fair Value, Recurring [Member] | Level 3 [Member] | Interest Rate Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset	0
Liability	0
Fair Value, Recurring [Member] | Level 3 [Member] | Natural Gas Exchange Agreements [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Asset	119	75
Liability	6,197	$ 8,485
Fair Value, Recurring [Member] | Level 3 [Member] | Foreign Exchange Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Liability	$ 0

Fair Value - Schedule of Quanti

Fair Value - Schedule of Quantitative Information (Details) - Natural Gas Exchange Agreements [Member] $ in Thousands	6 Months Ended
	Jun. 30, 2021USD ($)MMBTU$ / MMBTU	Dec. 31, 2020USD ($)
Purchase [Member] | Minimum [Member] | Internally Derived Weighted Average Cost Of Gas [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Derivative, Forward Price	1.97
Transaction/Delivery Volumes | MMBTU	40,000
Purchase [Member] | Maximum [Member] | Internally Derived Weighted Average Cost Of Gas [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Derivative, Forward Price	4.10
Transaction/Delivery Volumes | MMBTU	310,000
Purchase [Member] | Weighted Average [Member] | Internally Derived Weighted Average Cost Of Gas [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Derivative, Forward Price	2.49
Sales [Member] | Minimum [Member] | Internally Derived Weighted Average Cost Of Gas [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Derivative, Forward Price	2.09
Transaction/Delivery Volumes | MMBTU	75,000
Sales [Member] | Maximum [Member] | Internally Derived Weighted Average Cost Of Gas [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Derivative, Forward Price	5.08
Transaction/Delivery Volumes | MMBTU	310,000
Sales [Member] | Weighted Average [Member] | Internally Derived Weighted Average Cost Of Gas [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Derivative, Forward Price	3.69
Fair Value, Recurring [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Derivative Liability | $	$ (6,078)	$ (8,410)

Fair Value - Schedule of Activi

Fair Value - Schedule of Activity For Energy Commodity Derivative Assets (Liabilities) Measured At Fair Value Using Significant Unobservable Inputs (Level 3) (Details) - Natural Gas Exchange Agreements [Member] - Level 3 [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Fair Value Liabilities Measured On Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	$ (6,201)	$ (2,253)	$ (8,410)	$ (2,976)
Included in regulatory assets/liabilities	268	(391)	3,488	94
Settlements	(145)	16	(1,156)	254
Ending Balance	$ (6,078)	$ (2,628)	$ (6,078)	$ (2,628)

Common Stock - Narrative (Detai

Common Stock - Narrative (Details) - shares	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Common Stock [Member]
Class Of Stock [Line Items]
Number of shares authorized to issue by regulatory authority	3,900,000		3,900,000
Shares issued under sales agency agreements	353,330	621,032	427,766	736,269
Sales Agency Agreement [Member]
Class Of Stock [Line Items]
Shares issued under sales agency agreements	300,000		300,000

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Loss - Schedule of Accumulated Other Comprehensive Loss, Net of Tax (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Accumulated Other Comprehensive Loss [Abstract]
Unfunded benefit obligation for pensions and other postretirement benefit plans - net of taxes of $-0- and $3,822, respectively	$ 13,755	$ 14,378

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Loss - Schedule of Accumulated Other Comprehensive Loss, Net of Tax (Parenthetical) (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Accumulated Other Comprehensive Loss [Abstract]
Accumulated other comprehensive income (loss), pension and other postretirement benefit plans net unamortized (gain) loss, tax	$ 3,656	$ 3,822

Accumulated Other Comprehensi_5

Accumulated Other Comprehensive Loss - Reclassification out of Accumulated Other Comprehensive Income (Details) - Accumulated Defined Benefit and Postretirement Benefit Plans Adjustment Attributable to Parent [Member] - Reclassification out of Accumulated Other Comprehensive Income [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Amortization of net prior service cost	$ (200)	$ (200)	$ (400)	$ (400)
Amortization of net loss	2,739	3,121	5,930	6,221
Adjustment due to effects of regulation	(2,149)	(2,642)	(4,741)	(5,283)
Other comprehensive (income) loss, defined benefit plan, reclassification adjustment from AOCI, before tax	390	279	789	538
Other comprehensive (income) loss, defined benefit plan, reclassification adjustment from AOCI, tax	(82)	(59)	(166)	(113)
Other comprehensive (income) loss, defined benefit plan, reclassification adjustment from AOCI, after tax	$ 308	$ 220	$ 623	$ 425

Earnings Per Common Share - Sch

Earnings Per Common Share - Schedule of Computation of Basic and Diluted Earnings Per Common Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Numerator:
Net income	$ 14,074	$ 17,453	$ 82,091	$ 65,877
Denominator:
Weighted-average number of common shares outstanding-basic	69,404	67,481	69,348	67,360
Effect of dilutive securities:
Performance and restricted stock awards	130	108	172	125
Weighted-average number of common shares outstanding-diluted	69,534	67,589	69,520	67,485
Earnings per common share:
Basic	$ 0.20	$ 0.26	$ 1.18	$ 0.98
Diluted	$ 0.20	$ 0.26	$ 1.18	$ 0.98

Earnings Per Common Share - Add

Earnings Per Common Share - Additional Information (Details) - shares	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Earnings Per Share [Abstract]
Antidilutive securities excluded from computation of earnings per share, amount	0	0	0	0

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Details)	Jul. 07, 2021USD ($)	Aug. 31, 2019USD ($)	May 14, 2021aBuilding	Sep. 02, 2020aBuilding
Natural and Cultural Damage Claim [Member] | Subsequent Event [Member]
Loss Contingencies [Line Items]
Litigation settlement damages claim amount	$ 2,000,000
Boyds Fire [Member] | Damage from Fire [Member] | Maximum [Member]
Loss Contingencies [Line Items]
Loss contingency, damages sought, value		$ 4,400,000
Labor Day Windstorm [Member] | Damage from Fire [Member]
Loss Contingencies [Line Items]
Wildfire covered area | a				22,000
Number of residential, commercial and other structures impacted | Building				230
Babb Road Fire [Member] | Damage from Fire [Member]
Loss Contingencies [Line Items]
Number of residential, commercial and other structures impacted | Building			220
Road fire covered area | a			15,000
System Unit Resource Protection Act [Member] | Natural and Cultural Damage Claim [Member] | Subsequent Event [Member]
Loss Contingencies [Line Items]
Increased potential claim	$ 6,000,000

Information by Business Segme_3

Information by Business Segments - Additional Information (Details)	6 Months Ended
	Jun. 30, 2021ReportableSegments
Segment Reporting [Abstract]
Number of reportable segments	2

Information by Business Segme_4

Information by Business Segments - Schedule of Business Segments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Segment Reporting Information [Line Items]
Operating revenues	$ 298,255	$ 278,592	$ 711,125	$ 668,822
Resource costs	90,678	67,965	225,257	197,512
Other operating expenses	95,212	86,863	183,951	182,719
Depreciation and amortization	56,139	64,096	111,487	115,752
Income (loss) from operations	31,752	34,926	133,647	117,119
Interest expense	26,237	25,832	52,650	52,450
Income taxes	2,398	(7,919)	14,562	613
Net income (loss)	14,074	17,453	82,091	65,877
Capital expenditures	117,161	94,431	214,392	190,066
Total Assets	6,646,301		6,646,301		$ 6,402,097
Operating Segments [Member] | Utility Revenue [Member]
Segment Reporting Information [Line Items]
Operating revenues	298,107	278,337	710,788	667,744
Resource costs	90,678	67,965	225,257	197,512
Other operating expenses	94,053	86,204	181,608	180,700
Depreciation and amortization	56,066	63,908	111,287	115,329
Income (loss) from operations	32,836	35,519	135,853	118,483
Interest expense	26,131	25,749	52,456	52,320
Income taxes	1,053	(7,524)	13,104	1,181
Net income (loss)	9,016	18,933	76,550	68,307
Capital expenditures	116,624	93,954	213,827	189,480
Total Assets	6,542,984		6,542,984		6,304,311
Operating Segments [Member] | Avista Utilities [Member] | Utility Revenue [Member]
Segment Reporting Information [Line Items]
Operating revenues	287,560	268,340	687,420	645,545
Resource costs	89,515	67,069	223,355	196,625
Other operating expenses	90,728	83,140	175,327	174,420
Depreciation and amortization	53,569	61,462	106,293	110,436
Income (loss) from operations	29,561	32,217	126,254	108,935
Interest expense	24,608	24,188	49,408	49,171
Income taxes	585	(8,004)	11,303	600
Net income (loss)	7,717	17,605	71,775	63,584
Capital expenditures	114,441	91,867	210,835	185,923
Total Assets	6,272,062		6,272,062		6,035,340
Operating Segments [Member] | Alaska Electric Light & Power [Member] | Utility Revenue [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,547	9,997	23,368	22,199
Resource costs	1,163	896	1,902	(887)
Other operating expenses	3,325	3,064	6,281	6,280
Depreciation and amortization	2,497	2,446	4,994	4,893
Income (loss) from operations	3,275	3,302	9,599	9,548
Interest expense	1,523	1,561	3,048	3,149
Income taxes	468	480	1,801	1,781
Net income (loss)	1,299	1,328	4,775	4,723
Capital expenditures	2,183	2,087	2,992	3,557
Total Assets	270,922		270,922		268,971
Other [Member] | Non-Utility Revenue [Member]
Segment Reporting Information [Line Items]
Operating revenues	148	255	337	1,078
Resource costs	0	0	0	0
Other operating expenses	1,159	659	2,343	2,019
Depreciation and amortization	73	188	200	423
Income (loss) from operations	1,084	(593)	2,206	(1,364)
Interest expense	131	130	260	262
Income taxes	1,345	(395)	1,458	568
Net income (loss)	5,058	(1,480)	5,541	2,430
Capital expenditures	537	477	565	586
Total Assets	116,654		116,654		109,658
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Resource costs	0	0	0	0
Other operating expenses	0	0	0	0
Depreciation and amortization	0	0	0	0
Income (loss) from operations	0	0	0	0
Interest expense	25	(47)	66	(132)
Income taxes	0	0	0	0
Net income (loss)	0	0	0	0
Capital expenditures	0	$ 0	0	$ 0
Total Assets	$ (13,337)		$ (13,337)		$ (11,872)