Idaho Power 10-Q 29 Oct 20 2020 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information Document - shares	9 Months Ended
	Sep. 30, 2020	Oct. 23, 2020
Document Information
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2020
Document Transition Report	false
Entity File Number	1-14465
Entity Registrant Name	IDACORP, Inc.
Entity Tax Identification Number	82-0505802
Entity Address, Address Line One	1221 W. Idaho Street
Entity Address, City or Town	Boise,
Entity Address, State or Province	ID
Entity Address, Postal Zip Code	83702-5627
City Area Code	(208)
Local Phone Number	388-2200
Entity Current Reporting Status	Yes
Entity Incorporation, State or Country Code	ID
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Title of 12(b) Security	Common Stock
Trading Symbol	IDA
Security Exchange Name	NYSE
Entity Common Stock, Shares Outstanding		50,461,885
Entity Central Index Key	0001057877
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Information, Former Legal or Registered Name	None
Idaho Power Company
Document Information
Entity File Number	1-3198
Entity Registrant Name	Idaho Power Company
Entity Tax Identification Number	82-0130980
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		39,150,812
Entity Central Index Key	0000049648
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q3
Amendment Flag	false

Condensed Consolidated Statemen

Condensed Consolidated Statements of Income Statement - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Operating Revenues:
Electric utility revenues	$ 424,170	$ 385,028	$ 1,032,324	$ 1,050,574
Other operating revenues	1,091	1,292	2,711	2,961
Total operating revenues	425,261	386,320	1,035,035	1,053,535
Operating Expenses:
Purchased power	104,113	93,618	227,088	214,512
Fuel expense	59,745	46,881	121,174	119,577
Power cost adjustment	(9,533)	(16,412)	(14,460)	25,935
Other operations and maintenance	82,782	87,151	255,734	263,064
Energy efficiency programs	10,530	8,438	31,957	30,008
Depreciation	43,243	42,601	128,683	126,006
Taxes other than income taxes	8,536	8,827	25,947	27,064
Total electric utility expenses	299,416	271,104	776,123	806,166
Other	1,075	1,060	3,133	3,313
Total operating expenses	300,491	272,164	779,256	809,479
Operating Income	124,770	114,156	255,779	244,056
Other Income (Expense):
Allowance for equity funds used during construction	7,369	6,803	21,791	19,857
Earnings of equity-method investments	3,960	4,166	8,963	9,545
Other Income (Expense), Net	716	1,825	2,692	4,999
Interest Expense:
Interest on long-term debt	21,495	20,489	63,213	62,799
Other interest	3,642	3,748	11,012	10,886
Allowance for borrowed funds used during construction	(2,969)	(2,666)	(8,585)	(7,989)
Total interest expense, net	22,168	21,571	65,640	65,696
Income Before Income Taxes	114,647	105,379	223,585	212,761
Income Tax Expense	12,345	15,161	23,166	26,506
Net Income	102,302	90,218	200,419	186,255
Income attributable to noncontrolling interests	(271)	(342)	(509)	(537)
Net Income Attributable to IDACORP, Inc.	$ 102,031	$ 89,876	$ 199,910	$ 185,718
Weighted-average common shares outstanding - basic	50,541	50,499	50,534	50,502
Weighted-average common shares outstanding - diluted	50,576	50,558	50,554	50,528
Earnings Per Share of Common Stock:
Earnings attributable to IDACORP, Inc. - basic (in dollars per share)	$ 2.02	$ 1.78	$ 3.96	$ 3.68
Earnings attributable to IDACORP, Inc. - diluted (in dollars per share)	$ 2.02	$ 1.78	$ 3.95	$ 3.68
Idaho Power Company
Operating Revenues:
Electric utility revenues	$ 424,170	$ 385,028	$ 1,032,324	$ 1,050,574
Operating Expenses:
Purchased power	104,113	93,618	227,088	214,512
Fuel expense	59,745	46,881	121,174	119,577
Power cost adjustment	(9,533)	(16,412)	(14,460)	25,935
Other operations and maintenance	82,782	87,151	255,734	263,064
Energy efficiency programs	10,530	8,438	31,957	30,008
Depreciation	43,243	42,601	128,683	126,006
Taxes other than income taxes	8,536	8,827	25,947	27,064
Total electric utility expenses	299,416	271,104	776,123	806,166
Operating Income	124,754	113,924	256,201	244,408
Other Income (Expense):
Allowance for equity funds used during construction	7,369	6,803	21,791	19,857
Earnings of equity-method investments	2,928	3,100	7,368	7,365
Other Income (Expense), Net	183	770	612	1,858
Total other income	10,480	10,673	29,771	29,080
Interest Expense:
Interest on long-term debt	21,495	20,489	63,213	62,799
Other interest	3,637	3,741	10,995	10,847
Allowance for borrowed funds used during construction	(2,969)	(2,666)	(8,585)	(7,989)
Total interest expense, net	22,163	21,564	65,623	65,657
Income Before Income Taxes	113,071	103,033	220,349	207,831
Income Tax Expense	12,682	15,054	24,260	27,091
Net Income	$ 100,389	$ 87,979	$ 196,089	$ 180,740

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Net Income	$ 102,302	$ 90,218	$ 200,419	$ 186,255
Other Comprehensive Income:
Unfunded pension liability adjustment, net of tax	747	488	2,241	1,464
Total Comprehensive Income	103,049	90,706	202,660	187,719
Comprehensive (income) loss attributable to noncontrolling interests	(271)	(342)	(509)	(537)
Comprehensive Income Attributable to IDACORP, Inc.	102,778	90,364	202,151	187,182
Idaho Power Company
Net Income	100,389	87,979	196,089	180,740
Other Comprehensive Income:
Unfunded pension liability adjustment, net of tax	747	488	2,241	1,464
Total Comprehensive Income	$ 101,136	$ 88,467	$ 198,330	$ 182,204

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Comprehensive Income (Parenthetical) (Parentheticals) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Unfunded pension liability adjustment, tax	$ 259	$ 170	$ 777	$ 508
Idaho Power Company
Unfunded pension liability adjustment, tax	$ 259	$ 170	$ 777	$ 508

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets Statement - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Current Assets:
Cash and cash equivalents	$ 312,018	$ 217,254
Short-term Investments	25,000	0
Receivables:
Customer	103,581	72,675
Other	13,568	18,789
Income taxes receivable	0	3,106
Accrued unbilled revenues	64,283	64,545
Materials and supplies (at average cost)	62,493	56,660
Fuel stock (at average cost)	41,193	57,448
Prepayments	17,352	17,638
Current regulatory assets	42,830	56,626
Other	2,453	405
Total current assets	684,771	565,146
Investments	125,612	98,218
Property, Plant and Equipment:
Utility plant in service	6,263,386	6,113,567
Accumulated provision for depreciation	(2,242,049)	(2,155,783)
Utility plant in service - net	4,021,337	3,957,784
Construction work in progress	599,557	552,499
Utility plant held for future use	3,697	3,872
Other property, net of accumulated depreciation	16,930	17,299
Property, plant and equipment - net	4,641,521	4,531,454
Other Assets:
Company-owned life insurance	61,326	58,922
Regulatory assets	1,355,181	1,326,433
Other	61,748	61,028
Total other assets	1,478,255	1,446,383
Total	6,930,159	6,641,201
Current Liabilities:
Current maturities of long-term debt	0	100,000
Accounts payable	99,767	110,745
Taxes accrued	52,910	11,501
Interest accrued	19,502	20,999
Accrued compensation	59,096	52,550
Current regulatory liabilities	24,835	33,987
Advances from customers	30,270	28,452
Other	16,391	16,625
Total current liabilities	302,771	374,859
Other Liabilities:
Deferred Income Tax Liabilities, Net	736,273	746,231
Regulatory liabilities	771,236	748,198
Pension and other postretirement benefits	499,413	519,570
Other	47,687	45,131
Total other liabilities	2,054,609	2,059,130
Long-Term Debt	2,000,358	1,736,659
Commitments and Contingencies
Equity:
Common stock	867,491	868,307
Retained earnings	1,732,539	1,634,525
Accumulated other comprehensive loss	(34,043)	(36,284)
Treasury stock	0	(1,920)
Total IDACORP, Inc. shareholders’ equity	2,565,987	2,464,628
Noncontrolling interests	6,434	5,925
Total equity	2,572,421	2,470,553
Total	6,930,159	6,641,201
Idaho Power Company
Current Assets:
Cash and cash equivalents	236,162	98,950
Receivables:
Customer	103,581	72,675
Other	13,433	17,107
Income taxes receivable	0	9,279
Accrued unbilled revenues	64,283	64,545
Materials and supplies (at average cost)	62,493	56,660
Fuel stock (at average cost)	41,193	57,448
Prepayments	17,231	17,520
Current regulatory assets	42,830	56,626
Other	2,453	405
Total current assets	583,659	451,215
Investments	87,629	87,104
Property, Plant and Equipment:
Utility plant in service	6,263,386	6,113,567
Accumulated provision for depreciation	(2,242,049)	(2,155,783)
Utility plant in service - net	4,021,337	3,957,784
Construction work in progress	599,557	552,499
Utility plant held for future use	3,697	3,872
Property, plant and equipment - net	4,624,591	4,514,155
Other Assets:
Company-owned life insurance	61,326	58,922
Regulatory assets	1,355,181	1,326,433
Other	57,181	56,330
Total other assets	1,473,688	1,441,685
Total	6,769,567	6,494,159
Current Liabilities:
Current maturities of long-term debt	0	100,000
Accounts payable	99,644	110,581
Accounts payable to affiliates	24,045	2,053
Taxes accrued	26,361	11,481
Interest accrued	19,502	20,999
Accrued compensation	45,019	52,267
Current regulatory liabilities	24,835	33,987
Advances from customers	30,270	28,452
Other	15,566	15,629
Total current liabilities	285,242	375,449
Other Liabilities:
Deferred Income Tax Liabilities, Net	798,418	794,402
Regulatory liabilities	771,236	748,198
Pension and other postretirement benefits	499,413	519,570
Other	42,909	44,322
Total other liabilities	2,111,976	2,106,492
Long-Term Debt	2,000,358	1,736,659
Commitments and Contingencies
Equity:
Common stock	97,877	97,877
Premium on capital stock	712,258	712,258
Capital stock expense	(2,097)	(2,097)
Retained earnings	1,597,996	1,503,805
Accumulated other comprehensive loss	(34,043)	(36,284)
Total equity	2,371,991	2,275,559
Total capitalization	4,372,349	4,012,218
Total	$ 6,769,567	$ 6,494,159

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) (Parentheticals) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Accounts Receivable, Allowance for Credit Loss, Current	$ 3,924	$ 1,401
Allowance for Doubtful Other Receivables, Current	$ 499	$ 343
Common Stock, No Par Value	$ 0	$ 0
Common Stock, Shares Authorized	120,000,000	120,000,000
Common Stock, Shares, Issued	50,461,427	50,420,000
Treasury Stock, Shares	0	22,000
Idaho Power Company
Accounts Receivable, Allowance for Credit Loss, Current	$ 3,924	$ 1,401
Allowance for Doubtful Other Receivables, Current	$ 499	$ 343
Common Stock, Par or Stated Value Per Share	$ 2.50	$ 2.50
Common Stock, Shares Authorized	50,000,000	50,000,000
Common Stock, Shares, Issued	39,150,812	39,151,000

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Operating Activities:
Net Income	$ 200,419	$ 186,255
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	132,026	129,393
Deferred income taxes and investment tax credits	(2,963)	(7,399)
Changes in regulatory assets and liabilities	(11,616)	22,549
Pension and postretirement benefit plan expense	21,731	20,857
Contributions to pension and postretirement benefit plans	(44,138)	(46,001)
Earnings of equity-method investments	(8,963)	(9,545)
Distributions from equity-method investments	7,300	19,000
Allowance for equity funds used during construction	(21,791)	(19,857)
Other non-cash adjustments to net income, net	7,943	5,785
Change in:
Accounts receivable	(31,215)	(24,798)
Accounts payable and other accrued liabilities	(19,947)	(31,645)
Taxes accrued/receivable	44,515	45,600
Other current assets	8,938	3,618
Other current liabilities	5,128	(3,941)
Other assets	(2,768)	(3,477)
Other liabilities	(569)	621
Net cash provided by operating activities	284,030	287,015
Investing Activities:
Additions to property, plant and equipment	(213,400)	(198,871)
Payments received from transmission project joint funding partners	2,451	1,709
Investments in affordable housing	11,619	2,687
Payments to Acquire Available-for-sale Securities, Equity	3,401	682
Payments to Acquire Short-term Investments	25,000	0
Proceeds from the sale of equity securities	4,015	3,827
Other	4,862	4,121
Net cash used in investing activities	(242,092)	(192,583)
Financing Activities:
Issuance of long-term debt	310,000	166,100
Premium on issuance of long-term debt	31,384	0
Repayments of Long-term Debt	175,000	166,100
Dividends on common stock	(101,999)	(95,871)
Payment, Tax Withholding, Share-based Payment Arrangement	4,641	4,120
Payment for Debt Extinguishment or Debt Prepayment Cost	3,305	0
Other	(3,613)	(1,362)
Net cash (used in) provided by financing activities	52,826	(101,353)
Net increase (decrease) in cash and cash equivalents	94,764	(6,921)
Cash and cash equivalents at beginning of the period	217,254	267,492
Cash and cash equivalents at end of the period	312,018	260,571
Supplemental Disclosure of Cash Flow Information:
Income taxes	2,435	5,225
Interest (net of amount capitalized)	64,630	65,835
Non-cash investing activities:
Additions to property, plant and equipment in accounts payable	34,696	23,214
Idaho Power Company
Operating Activities:
Net Income	196,089	180,740
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	131,567	128,945
Deferred income taxes and investment tax credits	7,554	(6,911)
Changes in regulatory assets and liabilities	(11,616)	22,549
Pension and postretirement benefit plan expense	21,716	20,841
Contributions to pension and postretirement benefit plans	(44,123)	(45,984)
Earnings of equity-method investments	(7,368)	(7,365)
Distributions from equity-method investments	6,500	18,150
Allowance for equity funds used during construction	(21,791)	(19,857)
Other non-cash adjustments to net income, net	2,264	(759)
Change in:
Accounts receivable	(33,365)	(24,760)
Accounts payable and other accrued liabilities	2,658	(31,563)
Taxes accrued/receivable	24,159	34,351
Other current assets	8,942	3,611
Other current liabilities	5,207	(3,881)
Other assets	(2,800)	(3,478)
Other liabilities	(481)	658
Net cash provided by operating activities	285,112	265,287
Investing Activities:
Additions to property, plant and equipment	(213,400)	(198,871)
Payments received from transmission project joint funding partners	2,451	1,709
Payments to Acquire Available-for-sale Securities	(3,401)	(682)
Proceeds from the sale of equity securities	4,015	3,827
Other	4,833	3,964
Net cash used in investing activities	(205,502)	(190,053)
Financing Activities:
Issuance of long-term debt	310,000	166,100
Premium on issuance of long-term debt	31,384	0
Repayments of Long-term Debt	175,000	166,100
Dividends on common stock	(101,898)	(95,919)
Payment for Debt Extinguishment or Debt Prepayment Cost	3,305	0
Other	(3,579)	(1,284)
Net cash (used in) provided by financing activities	57,602	(97,203)
Net increase (decrease) in cash and cash equivalents	137,212	(21,969)
Cash and cash equivalents at beginning of the period	98,950	165,460
Cash and cash equivalents at end of the period	236,162	143,491
Supplemental Disclosure of Cash Flow Information:
Income taxes	(9,189)	16,014
Interest (net of amount capitalized)	64,613	65,796
Non-cash investing activities:
Additions to property, plant and equipment in accounts payable	$ 34,696	$ 23,214

Condensed Consolidated Statem_5

Condensed Consolidated Statements of Equity $ in Thousands	USD ($)
Balance at beginning of period at Dec. 31, 2018	$ 863,593
Common Stock
Share-based Payment Arrangement, Expense	6,543
Share-based Payment Arrangement, Decrease for Tax Withholding Obligation	0
Treasury Stock Issued	(4,080)
Other common stock changes	75
Balance at end of period at Sep. 30, 2019	866,131
Balance at beginning of period at Dec. 31, 2018	1,531,543
Retained Earnings
Net Income Attributable to IDACORP, Inc.	185,718
Common stock dividends	(95,919)
Balance at end of period at Sep. 30, 2019	1,621,342
AOCI - Beginning Balance at Dec. 31, 2018	(22,844)
Accumulated Other Comprehensive (Loss) Income
Unfunded pension liability adjustment, net of tax	1,464
AOCI - Ending Balance at Sep. 30, 2019	(21,380)
Balance at beginning of period at Dec. 31, 2018	(1,932)
Treasury Stock
Issued	4,080
Acquired	(4,120)
Balance at end of period at Sep. 30, 2019	(1,972)
Balance at beginning of period at Dec. 31, 2018	5,451
Noncontrolling Interests
Income attributable to noncontrolling interests	537
Balance at end of period at Sep. 30, 2019	5,988
Balance at beginning of period at Jun. 30, 2019	864,266
Common Stock
Share-based Payment Arrangement, Expense	1,877
Share-based Payment Arrangement, Decrease for Tax Withholding Obligation	0
Treasury Stock Issued	(33)
Other common stock changes	21
Balance at end of period at Sep. 30, 2019	866,131
Balance at beginning of period at Jun. 30, 2019	1,563,399
Retained Earnings
Net Income Attributable to IDACORP, Inc.	89,876
Common stock dividends	(31,933)
Balance at end of period at Sep. 30, 2019	1,621,342
AOCI - Beginning Balance at Jun. 30, 2019	(21,868)
Accumulated Other Comprehensive (Loss) Income
Unfunded pension liability adjustment, net of tax	488
AOCI - Ending Balance at Sep. 30, 2019	(21,380)
Balance at beginning of period at Jun. 30, 2019	(1,992)
Treasury Stock
Issued	33
Acquired	(13)
Balance at end of period at Sep. 30, 2019	(1,972)
Balance at beginning of period at Jun. 30, 2019	5,646
Noncontrolling Interests
Income attributable to noncontrolling interests	342
Balance at end of period at Sep. 30, 2019	5,988
Treasury Stock
Total IDACORP, Inc. shareholders’ equity at end of period	2,464,121
Noncontrolling Interests
Total equity at end of period	2,470,109
Total IDACORP, Inc. shareholders’ equity at end of period	2,464,628
Total equity at end of period	2,470,553
Balance at beginning of period at Dec. 31, 2019	868,307
Common Stock
Share-based Payment Arrangement, Expense	5,678
Share-based Payment Arrangement, Decrease for Tax Withholding Obligation	(4,641)
Treasury Stock Issued	(1,920)
Other common stock changes	67
Balance at end of period at Sep. 30, 2020	867,491
Balance at beginning of period at Dec. 31, 2019	1,634,525
Retained Earnings
Net Income Attributable to IDACORP, Inc.	199,910
Common stock dividends	(101,896)
Balance at end of period at Sep. 30, 2020	1,732,539
AOCI - Beginning Balance at Dec. 31, 2019	(36,284)
Accumulated Other Comprehensive (Loss) Income
Unfunded pension liability adjustment, net of tax	2,241
AOCI - Ending Balance at Sep. 30, 2020	(34,043)
Balance at beginning of period at Dec. 31, 2019	(1,920)
Treasury Stock
Issued	1,920
Acquired	0
Balance at end of period at Sep. 30, 2020	0
Balance at beginning of period at Dec. 31, 2019	5,925
Noncontrolling Interests
Income attributable to noncontrolling interests	509
Balance at end of period at Sep. 30, 2020	6,434
Balance at beginning of period at Jun. 30, 2020	866,127
Common Stock
Share-based Payment Arrangement, Expense	1,353
Share-based Payment Arrangement, Decrease for Tax Withholding Obligation	(11)
Treasury Stock Issued	0
Other common stock changes	22
Balance at end of period at Sep. 30, 2020	867,491
Balance at beginning of period at Jun. 30, 2020	1,664,468
Retained Earnings
Net Income Attributable to IDACORP, Inc.	102,031
Common stock dividends	(33,960)
Balance at end of period at Sep. 30, 2020	1,732,539
AOCI - Beginning Balance at Jun. 30, 2020	(34,790)
Accumulated Other Comprehensive (Loss) Income
Unfunded pension liability adjustment, net of tax	747
AOCI - Ending Balance at Sep. 30, 2020	(34,043)
Balance at beginning of period at Jun. 30, 2020	0
Treasury Stock
Issued	0
Acquired	0
Balance at end of period at Sep. 30, 2020	0
Balance at beginning of period at Jun. 30, 2020	6,163
Noncontrolling Interests
Income attributable to noncontrolling interests	271
Balance at end of period at Sep. 30, 2020	6,434
Treasury Stock
Total IDACORP, Inc. shareholders’ equity at end of period	2,565,987
Noncontrolling Interests
Total equity at end of period	$ 2,572,421

Condensed Consolidated Statem_6

Condensed Consolidated Statements of Equity (Parenthetical) (Parentheticals) - $ / shares	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Dividends Declared Per Share of Common Stock	$ 2.01	$ 1.89

CHANGES IN ACCUMULATED OTHER CO

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME: CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME:	9 Months Ended
	Sep. 30, 2020
Statement of Comprehensive Income [Abstract]
Changes in Accumulated Other Comprehensive Income [Text Block]	CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME The table below presents changes in components of accumulated other comprehensive income (AOCI), net of tax, during the three and nine months ended September 30, 2020 and 2019 (in thousands). Items in parentheses indicate charges to AOCI. Defined Benefit Pension Items Defined Benefit Pension Items Three months ended Nine months ended 2020 2019 2020 2019 Balance at beginning of period $ (34,790) $ (21,868) $ (36,284) $ (22,844) Amounts reclassified out of AOCI 747 488 2,241 1,464 Balance at end of period $ (34,043) $ (21,380) $ (34,043) $ (21,380) The table below presents amounts reclassified out of components of AOCI and the income statement location of those amounts reclassified during the three and nine months ended September 30, 2020 and 2019 (in thousands). Items in parentheses indicate increases to net income. Amount Reclassified from AOCI Details About AOCI Three months ended Nine months ended 2020 2019 2020 2019 Amortization of defined benefit pension items (1) Prior service cost $ 73 $ 24 $ 218 $ 72 Net loss 933 634 2,800 1,900 Total before tax 1,006 658 3,018 1,972 Tax benefit (2) (259) (170) (777) (508) Total reclassification for the period, net of tax $ 747 $ 488 $ 2,241 $ 1,464 (1) Amortization of these items is included in IDACORP's condensed consolidated income statements in other operating expenses and in Idaho Power's condensed consolidated statements of income in other expense, net. (2) The tax benefit is included in income tax expense in the condensed consolidated statements of income of both IDACORP and Idaho Power.

CHANGES IN ACCUMULATED OTHER _2

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME: Level 3	9 Months Ended
	Sep. 30, 2020
Statement of Comprehensive Income [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]	The table below presents changes in components of accumulated other comprehensive income (AOCI), net of tax, during the three and nine months ended September 30, 2020 and 2019 (in thousands). Items in parentheses indicate charges to AOCI. Defined Benefit Pension Items Defined Benefit Pension Items Three months ended Nine months ended 2020 2019 2020 2019 Balance at beginning of period $ (34,790) $ (21,868) $ (36,284) $ (22,844) Amounts reclassified out of AOCI 747 488 2,241 1,464 Balance at end of period $ (34,043) $ (21,380) $ (34,043) $ (21,380)
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]	The table below presents amounts reclassified out of components of AOCI and the income statement location of those amounts reclassified during the three and nine months ended September 30, 2020 and 2019 (in thousands). Items in parentheses indicate increases to net income. Amount Reclassified from AOCI Details About AOCI Three months ended Nine months ended 2020 2019 2020 2019 Amortization of defined benefit pension items (1) Prior service cost $ 73 $ 24 $ 218 $ 72 Net loss 933 634 2,800 1,900 Total before tax 1,006 658 3,018 1,972 Tax benefit (2) (259) (170) (777) (508) Total reclassification for the period, net of tax $ 747 $ 488 $ 2,241 $ 1,464 (1) Amortization of these items is included in IDACORP's condensed consolidated income statements in other operating expenses and in Idaho Power's condensed consolidated statements of income in other expense, net. (2) The tax benefit is included in income tax expense in the condensed consolidated statements of income of both IDACORP and Idaho Power.

CHANGES IN ACCUMULATED OTHER _3

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME: Level 4 - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Reclassification out of Accumulated Other Comprehensive Income
Amortization of prior service cost	[1]	$ 73	$ 24	$ 218	$ 72
Amortization of net loss	[1]	933	634	2,800	1,900
Total reclassification, before tax - pension and postretirement benefits		1,006	658	3,018	1,972
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	[2]	(259)	(170)	(777)	(508)
Reclassifications		747	488	2,241	1,464
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
AOCI - Beginning Balance		(34,790)	(21,868)	(36,284)	(22,844)
Reclassifications		747	488	2,241	1,464
AOCI - Ending Balance		(34,043)	(21,380)	(34,043)	(21,380)
Accumulated Defined Benefit Pension Items
Reclassification out of Accumulated Other Comprehensive Income
Reclassifications		747	488	2,241	1,464
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
AOCI - Beginning Balance		(34,790)	(21,868)	(36,284)	(22,844)
Reclassifications		747	488	2,241	1,464
AOCI - Ending Balance		$ (34,043)	$ (21,380)	$ (34,043)	$ (21,380)
[1]	Amortization of these items is included in IDACORP's condensed consolidated income statements in other operating expenses and in Idaho Power's condensed consolidated statements of income in other expense, net.
[2]	The tax benefit is included in income tax expense in the condensed consolidated statements of income of both IDACORP and Idaho Power.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:	9 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES This Quarterly Report on Form 10-Q is a combined report of IDACORP, Inc. (IDACORP) and Idaho Power Company (Idaho Power). Therefore, these Notes to Condensed Consolidated Financial Statements apply to both IDACORP and Idaho Power. However, Idaho Power makes no representation as to the information relating to IDACORP’s other operations. Nature of Business IDACORP is a holding company formed in 1998 whose principal operating subsidiary is Idaho Power. Idaho Power is an electric utility engaged in the generation, transmission, distribution, sale, and purchase of electric energy and capacity with a service area covering approximately 24,000 square miles in southern Idaho and eastern Oregon. Idaho Power is regulated primarily by the state utility regulatory commissions of Idaho and Oregon and the Federal Energy Regulatory Commission (FERC). Idaho Power is the parent of Idaho Energy Resources Co. (IERCo), a joint venturer in Bridger Coal Company (BCC), which mines and supplies coal to the Jim Bridger generating plant (Jim Bridger plant) owned in part by Idaho Power. IDACORP’s significant other wholly-owned subsidiaries include IDACORP Financial Services, Inc. (IFS), an investor in affordable housing and other real estate investments, and Ida-West Energy Company (Ida-West), an operator of small hydropower generation projects that satisfy the requirements of the Public Utility Regulatory Policies Act of 1978 (PURPA). Regulation of Utility Operations As a regulated utility, many of Idaho Power's fundamental business decisions are subject to the approval of governmental agencies, including the prices that Idaho Power is authorized to charge for its electric service. These approvals are a critical factor in determining IDACORP's and Idaho Power's results of operations and financial condition. IDACORP's and Idaho Power's financial statements reflect the effects of the different ratemaking principles followed by the jurisdictions regulating Idaho Power. The application of accounting principles related to regulated operations sometimes results in Idaho Power recording expenses and revenues in a different period than when an unregulated enterprise would record such expenses and revenues. In these instances, the amounts are deferred or accrued as regulatory assets or regulatory liabilities on the balance sheet. Regulatory assets represent incurred costs that have been deferred because it is probable they will be recovered from customers through future rates. Regulatory liabilities represent obligations to make refunds to customers for previous collections, or represent amounts collected in advance of incurring an expense. The effects of applying these regulatory accounting principles to Idaho Power's operations are discussed in more detail in Note 3 - "Regulatory Matters." Financial Statements In the opinion of management of IDACORP and Idaho Power, the accompanying unaudited condensed consolidated financial statements contain all adjustments necessary to present fairly each company's consolidated financial position as of September 30, 2020, consolidated results of operations for the three and nine months ended September 30, 2020 and 2019, and consolidated cash flows for the nine months ended September 30, 2020 and 2019. These adjustments are of a normal and recurring nature. These financial statements do not contain the complete detail or note disclosures concerning accounting policies and other matters that would be included in full-year financial statements and should be read in conjunction with the audited consolidated financial statements included in IDACORP’s and Idaho Power’s Annual Report on Form 10-K for the year ended December 31, 2019 (2019 Annual Report). The results of operations for the interim period are not necessarily indicative of the results to be expected for the full year. A change in management's estimates or assumptions could have a material impact on IDACORP's or Idaho Power's respective financial condition and results of operations during the period in which such change occurred. Management Estimates Management makes estimates and assumptions when preparing financial statements in conformity with generally accepted accounting principles. These estimates and assumptions include those related to rate regulation, retirement benefits, contingencies, asset impairment, income taxes, unbilled revenues, and bad debt. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. These estimates involve judgments with respect to, among other things, future economic factors that are difficult to predict and are beyond management's control. Accordingly, actual results could differ from those estimates. New and Recently Adopted Accounting Pronouncements In June 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments to provide financial statement users with more information about expected credit losses on financial instruments and other commitments. The ASU revises the incurred loss impairment methodology to reflect current expected credit losses and requires consideration of a broader range of information to estimate credit losses. IDACORP and Idaho Power adopted ASU 2016-13 on January 1, 2020. The adoption did not have a material impact on their respective financial statements but did result in the additional disclosure below. The measurement of expected credit losses on Idaho Power accounts receivable is based upon historical experience, current conditions, and forecasted information that may affect collections on the outstanding balance. Generally, this includes adjustments based upon a combination of historical write-off experience, aging of accounts receivable, an analysis of specific customer accounts, and an evaluation of whether there are current or forecasted economic conditions that might cause variation in collection from the historical experience. In response to the COVID-19 public health crisis, Idaho Power provided certain relief to customers including temporarily suspending disconnections for customers and temporarily waiving late fees. This relief as well as the economic conditions created by the response to the COVID-19 public health crisis have resulted in higher aged accounts receivable and an increase in the number of late payments. Idaho Power expects higher uncollectible account write-offs as a result of the COVID-19 public health crisis and, accordingly, increased its allowance for uncollectible accounts related to customer receivables at September 30, 2020. The allowance for uncollectible accounts increased to 3.7 percent of the total customer receivables balance at September 30, 2020, compared with 1.9 percent at December 31, 2019, and 1.4 percent at September 30, 2019. The following table provides a rollforward of the allowance for uncollectible accounts related to customer receivables for the nine months ended September 30, 2020 and 2019 (in thousands): Nine months ended 2020 2019 Balance at beginning of period $ 1,401 $ 1,725 Additions to the allowance 3,543 1,663 Write-offs, net of recoveries (1,020) (1,975) Balance at end of period $ 3,924 $ 1,413 Allowance for uncollectible accounts as a percentage of customer receivables 3.7 % 1.4 % In August 2018, the FASB issued ASU 2018-15, Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract , to provide guidance on implementation costs incurred in a cloud computing arrangement that is a service contract. ASU 2018-15 aligns the recognition of such implementation costs with the accounting for costs incurred to implement an internal-use software solution. However, the balance sheet line item for presentation of capitalized implementation costs for a cloud computing arrangement that is a service contract should be the same as that for the prepayment of fees related to the same arrangement, while capitalized implementation costs for internal-use software solutions are often included in property, plant, and equipment as an intangible asset. IDACORP and Idaho Power adopted ASU 2018-15 on January 1, 2020. The adoption did not have a material impact on their respective financial statements.

INCOME TAXES_

INCOME TAXES:	9 Months Ended
	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES In accordance with interim reporting requirements, IDACORP and Idaho Power use an estimated annual effective tax rate for computing their 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 effective 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. Income Tax Expense The following table provides a summary of income tax expense for the nine months ended September 30, 2020 and 2019 (in thousands): IDACORP Idaho Power 2020 2019 2020 2019 Income tax at statutory rates (federal and state) $ 57,420 $ 54,626 $ 56,718 $ 53,496 First mortgage bond redemption costs (890) — (890) — Excess deferred income tax reversal (3,222) (4,123) (3,222) (4,123) Income tax return adjustments (2,555) 1,071 (2,507) 993 Other (1) (27,587) (25,068) (25,839) (23,275) Income tax expense $ 23,166 $ 26,506 $ 24,260 $ 27,091 Effective tax rate 10.4 % 12.5 % 11.0 % 13.0 % (1) "Other" is primarily comprised of the net tax effect of Idaho Power's regulatory flow-through tax adjustments. The decrease in income tax expense for the nine months ended September 30, 2020, compared with the same period in 2019, was primarily due to the tax deduction for bond redemption costs incurred in the third quarter and other plant-related income tax return adjustments, partially offset by statutory taxes on greater 2020 pre-tax income and lower excess deferred income tax reversal. On a net basis, Idaho Power’s estimate of its annual 2020 regulatory flow-through tax adjustments is comparable to 2019.

REGULATORY MATTERS_

REGULATORY MATTERS:	9 Months Ended
	Sep. 30, 2020
Public Utilities, Rate Matters [Abstract]
Regulatory Matters	REGULATORY MATTERS Included below is a summary of Idaho Power's most recent general rate cases and base rate changes, as well as other recent or pending notable regulatory matters and proceedings. Idaho and Oregon General Rate Cases Idaho Power's current base rates result from orders from the Idaho Public Utilities Commission (IPUC) and Public Utility Commission of Oregon (OPUC), as described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 2019 Annual Report. Idaho Settlement Stipulations In October 2014, the IPUC issued an order approving an extension, with modifications, of the terms of a December 2011 Idaho settlement stipulation for the period from 2015 through 2019, or until otherwise modified or terminated by order of the IPUC (October 2014 Idaho Earnings Support and Sharing Settlement Stipulation). A May 2018 Idaho settlement stipulation related to tax reform (May 2018 Idaho Tax Reform Settlement Stipulation) provides for the extension of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation beyond the initial termination date of December 31, 2019, with modified terms that became effective beginning January 1, 2020, related to the accumulated deferred investment tax credits (ADITC) and revenue sharing mechanism. The October 2014 Idaho Earnings Support and Sharing Settlement Stipulation and the May 2018 Idaho Tax Reform Settlement Stipulation are described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 2019 Annual Report and include provisions for the accelerated amortization of ADITC to help achieve a minimum 9.4 percent (9.5 percent prior to 2020) return on year-end equity in the Idaho jurisdiction (Idaho ROE). In addition, under the May 2018 Idaho Tax Reform Settlement Stipulation, minimum Idaho ROE would revert back to 95 percent of the authorized return on equity in the next general rate case. The settlement stipulations also provide for the potential sharing between Idaho Power and Idaho customers of Idaho-jurisdictional earnings in excess of 10.0 percent of Idaho ROE. Based on its estimate of full-year 2020 Idaho ROE, in both the third quarter and first nine months of 2020, Idaho Power recorded no additional ADITC amortization or provision against current revenues for sharing of earnings with customers for 2020 under the May 2018 Idaho Tax Reform Settlement Stipulation. Accordingly, at September 30, 2020, the full $45 million of additional ADITC remains available for future use. Idaho Power recorded no additional ADITC amortization or provision against revenues for sharing of earnings with customers during the third quarter and first nine months of 2019, based on its then-current estimate of full-year 2019 Idaho ROE. Idaho Power Cost Adjustment Mechanisms In both its Idaho and Oregon jurisdictions, Idaho Power's power cost adjustment mechanisms address the volatility of power supply costs and provide for annual adjustments to the rates charged to its retail customers. The power cost adjustment mechanisms compare Idaho Power's actual net power supply costs (primarily fuel and purchased power less wholesale energy sales) against net power supply costs being recovered in Idaho Power's retail rates. Under the power cost adjustment mechanisms, certain differences between actual net power supply costs incurred by Idaho Power and costs being recovered in retail rates are recorded as a deferred charge or credit on the balance sheet for future recovery or refund. The power supply costs deferred primarily result from changes in contracted power purchase prices and volumes, changes in wholesale market prices and transaction volumes, fuel prices, and the levels of Idaho Power's own generation. In May 2020, the IPUC approved a $58.7 million net increase in Idaho-jurisdiction power cost adjustment (PCA) revenues, effective for the 2020-2021 PCA collection period from June 1, 2020, to May 31, 2021. The net increase in PCA revenues reflects a return to a more normal level of power supply costs as wholesale market energy prices have come down from unusually high levels reflected in last year's PCA. The reduction in market energy prices results in Idaho Power forecasting lower wholesale energy sales, which serve as an offset to power supply costs. The net increase in PCA revenues also reflects a forecasted reduction in low-cost hydropower generation. The previous PCA for the 2019-2020 collection period also included $7.7 million in one-time customer benefits associated with revenue sharing and income tax reform benefits, which expired in May 2020. Previously, in May 2019, the IPUC issued an order approving a $50.1 million net decrease in PCA rates, effective for the 2019-2020 PCA collection period from June 1, 2019, to May 31, 2020. The net decrease in PCA revenues reflected reduced power supply costs due to higher-than-expected wholesale energy sales and positive results from natural gas hedging activities, which combined to reduce actual net power supply costs for the 2018-2019 PCA year (April 2018 through March 2019). The net decrease in PCA revenues for the 2019-2020 PCA collection period also included a $5.0 million credit to customers for sharing of 2018 earnings under the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation and a $2.7 million credit for income tax reform benefits related to Idaho Power's open access transmission tariff (OATT) rate under the May 2018 Idaho Tax Reform Settlement Stipulation. Idaho Fixed Cost Adjustment Mechanism The Idaho jurisdiction fixed cost adjustment (FCA) mechanism, applicable to Idaho residential and small general service customers, is designed to remove a portion of Idaho Power’s financial disincentive to invest in energy efficiency programs by separating (or decoupling) the recovery of fixed costs from the variable kilowatt-hour charge and linking it instead to a set amount per customer. Under Idaho Power's current rate design, Idaho Power recovers a portion of fixed costs through the variable kilowatt-hour charge, which may result in over-collection or under-collection of fixed costs. To return over-collection to customers or to collect under-collection from customers, the FCA mechanism allows Idaho Power to accrue, or defer, the difference between the authorized fixed-cost recovery amount per customer and the actual fixed costs per customer recovered by Idaho Power during the year. The IPUC has discretion to cap the annual increase in the FCA recovery at 3 percent of base revenue, with any excess deferred for collection in a subsequent year. In June 2020, the IPUC approved an increase of $0.7 million in recovery from the FCA from $34.8 million to $35.5 million, with new rates effective for the period from June 1, 2020, to May 31, 2021. Previously, in May 2019, the IPUC issued an order approving an increase of $19.2 million in the FCA from $15.6 million to $34.8 million, with rates effective for the period from June 1, 2019, to May 31, 2020. Deferred Costs for COVID-19 Public Health Crisis Idaho Power has incurred, and expects to continue to incur, costs associated with its response to the COVID-19 public health crisis, including information technology expenditures for remote work, higher than average levels of bad debt expense related to uncollectible accounts associated in part with its temporary suspension of disconnects and late payment fees. Accordingly, in March and April 2020, Idaho Power submitted applications to the OPUC and IPUC, respectively, requesting authorization to defer incremental costs associated with its response to the COVID-19 public health crisis. Idaho Power requested authorization to establish a new regulatory asset to record the deferral of incremental costs and, in the Idaho jurisdiction, unrecovered costs associated with the COVID-19 response. Both applications requested only the authority to defer these costs and to determine ratemaking treatment at a later date. Subsequent to Idaho Power's application, the IPUC opened a general docket to address the issue. In July 2020, the IPUC issued an order authorizing Idaho Power and other utilities to account for unanticipated, emergency-related expenses incurred due to the COVID-19 public health crisis by recording the expenses as regulatory assets

Long-Term Debt (Notes)

Long-Term Debt (Notes)	9 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Long-term Debt [Text Block]	LONG-TERM DEBT In April 2020, Idaho Power issued $230 million in principal amount of 4.20 percent first mortgage bonds, secured medium term notes, Series K, maturing March 1, 2048. The bonds were issued at a reoffer yield of 3.422 percent, which resulted in a net premium of 13.0 percent and net proceeds to Idaho Power of $259.9 million. After this offering the aggregate principal amount of the 4.20 percent first mortgage bonds is $450 million. In June 2020, Idaho Power entered into a selling agency agreement with six banks named in the agreement in connection with the potential issuance and sale from time to time of up to $500 million aggregate principal amount of first mortgage bonds, secured medium term notes, Series L (Series L Notes), under Idaho Power’s Indenture of Mortgage and Deed of Trust, dated as of October 1, 1937, as amended and supplemented (Indenture). Also in June 2020, Idaho Power entered into the Forty-ninth Supplemental Indenture, dated effective as of June 5, 2020, to the Indenture (Forty-ninth Supplemental Indenture). The Forty-ninth Supplemental Indenture provides for, among other items, the issuance of up to $500 million in aggregate principal amount of Series L Notes pursuant to the Indenture. In June 2020, Idaho Power issued $80 million in principal amount of 1.90 percent first mortgage bonds, secured medium term notes, Series L, maturing July 15, 2030. In July 2020, Idaho Power redeemed, prior to maturity, $75 million in principal amount of 2.95 percent first mortgage bonds, medium-term notes, Series H due in April 2022. In accordance with the redemption provisions of the notes, the redemption included Idaho Power's payment of a make-whole premium to the holders of the redeemed notes in the aggregate amount of $3.3 million. In August 2020, Idaho Power redeemed $100 million in principal amount of 3.40 percent first mortgage bonds due in November 2020.

REVENUES_ (Notes)

REVENUES: (Notes)	9 Months Ended
	Sep. 30, 2020
Revenues [Abstract]
Revenue from Contract with Customer [Text Block]	REVENUES The following table provides a summary of electric utility operating revenues for IDACORP and Idaho Power for the three and nine months ended September 30, 2020 and 2019 (in thousands): Three months ended Nine months ended 2020 2019 2020 2019 Electric utility operating revenues: Revenue from contracts with customers $ 402,941 $ 367,101 $ 984,096 $ 1,010,281 Alternative revenue programs and other revenues 21,229 17,927 48,228 40,293 Total electric utility operating revenues $ 424,170 $ 385,028 $ 1,032,324 $ 1,050,574 Revenues from Contracts with Customers The following table presents revenues from contracts with customers disaggregated by revenue source for the three and nine months ended September 30, 2020 and 2019 (in thousands): Three months ended Nine months ended 2020 2019 2020 2019 Revenues from contracts with customers: Retail revenues: Residential (includes $4,896, $6,446, $24,740, and $24,988, respectively, related to the FCA) (1) $ 143,822 $ 133,550 $ 398,180 $ 388,566 Commercial (includes $330, $330, $1,211, and $1,022, respectively, related to the FCA) (1) 82,279 80,304 219,006 224,382 Industrial 50,154 47,122 136,001 138,222 Irrigation 88,188 82,659 149,711 132,613 Deferred revenue related to HCC relicensing AFUDC (2) (2,815) (2,815) (6,861) (6,861) Total retail revenues 361,628 340,820 896,037 876,922 Less: FCA mechanism revenues (1) (5,226) (6,776) (25,951) (26,010) Wholesale energy sales 12,178 5,321 22,952 68,693 Transmission wheeling-related revenues 16,896 12,498 38,750 40,743 Energy efficiency program revenues 10,530 8,439 31,957 30,008 Other revenues from contracts with customers 6,935 6,799 20,351 19,925 Total revenues from contracts with customers $ 402,941 $ 367,101 $ 984,096 $ 1,010,281 (1) The FCA mechanism is an alternative revenue program in the Idaho jurisdiction and does not represent revenue from contracts with customers. (2) As part of its January 30, 2009, general rate case order, the IPUC is allowing Idaho Power to recover a portion of the allowance for funds used during construction (AFUDC) on construction work in progress related to the Hells Canyon Complex (HCC) relicensing process, even though the relicensing process is not yet complete and the costs have not been moved to electric plant in service. Idaho Power is collecting $8.8 million annually in the Idaho jurisdiction but is deferring revenue recognition of the amounts collected until the license is issued and the accumulated license costs approved for recovery are placed in service. Alternative Revenue Programs and Other Revenues While revenues from contracts with customers make up most of Idaho Power’s revenues, the IPUC has authorized the use of an additional regulatory mechanism, the Idaho FCA mechanism, which may increase or decrease tariff-based customer rates. The Idaho FCA mechanism is described in Note 3 - "Regulatory Matters." The FCA mechanism revenues include only the initial recognition of FCA revenues when they meet the regulator-specified conditions for recognition. Revenue from contracts with customers excludes the portion of the tariff price representing FCA revenues that Idaho Power initially recorded in prior periods when revenues met regulator-specified conditions. When Idaho Power includes those amounts in the price of utility service billed to customers, Idaho Power records such amounts as recovery of the associated regulatory asset or liability and not as revenues. Derivative revenues include gains from settled electricity swaps and sales of electricity under forward sales contracts that are bundled with renewable energy credits. Related to these forward sales, Idaho Power simultaneously enters into forward purchases of electricity for the same quantity at the same location, which are recorded in purchased power on the condensed consolidated statements of income. For more information on settled electricity swaps, see Note 11 - "Derivative Financial Instruments." The table below presents the FCA mechanism revenues and other revenues for the three and nine months ended September 30, 2020 and 2019 (in thousands): Three months ended Nine months ended 2020 2019 2020 2019 Alternative revenue programs and other revenues: FCA mechanism revenues $ 5,226 6,776 $ 25,951 $ 26,010 Derivative revenues 16,003 11,151 22,277 14,283 Total alternative revenue programs and other revenues $ 21,229 $ 17,927 $ 48,228 $ 40,293

COMMON STOCK_

COMMON STOCK:	9 Months Ended
	Sep. 30, 2020
Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Common Stock	COMMON STOCK IDACORP Common Stock During the nine months ended September 30, 2020, IDACORP granted 75,030 restricted stock unit awards to employees and issued 41,410 shares of common stock using original issuances of shares pursuant to the IDACORP, Inc. 2000 Long-Term Incentive and Compensation Plan, including 8,480 shares of common stock issued to members of the board of directors. As directed by IDACORP, plan administrators of the IDACORP, Inc. Dividend Reinvestment and Stock Purchase Plan and Idaho Power Company Employee Savings Plan used market purchases of IDACORP common stock to acquire shares of IDACORP common stock for the plans. Restrictions on Dividends Idaho Power’s ability to pay dividends on its common stock held by IDACORP and IDACORP’s ability to pay dividends on its common stock are limited to the extent payment of such dividends would violate the covenants in their respective credit facilities or Idaho Power’s Revised Code of Conduct. A covenant under IDACORP’s credit facility and Idaho Power’s credit facility requires IDACORP and Idaho Power to maintain leverage ratios of consolidated indebtedness to consolidated total capitalization, as defined therein, of no more than 65 percent at the end of each fiscal quarter. At September 30, 2020, the leverage ratios for IDACORP and Idaho Power were 44 percent and 46 percent, respectively. Based on these restrictions, IDACORP’s and Idaho Power’s dividends were limited to $1.5 billion and $1.3 billion, respectively, at September 30, 2020. There are additional facility covenants, subject to exceptions, that prohibit or restrict the sale or disposition of property without consent and any agreements restricting dividend payments to IDACORP and Idaho Power from any material subsidiary. At September 30, 2020, IDACORP and Idaho Power were in compliance with those financial covenants. Idaho Power’s Revised Code of Conduct relating to transactions between and among Idaho Power, IDACORP, and other affiliates, which was approved by the IPUC in April 2008, provides that Idaho Power will not pay any dividends to IDACORP that will reduce Idaho Power’s common equity capital below 35 percent of its total adjusted capital without IPUC approval. At September 30, 2020, Idaho Power's common equity capital was 54 percent of its total adjusted capital. Further, Idaho Power must obtain approval from the OPUC before it can directly or indirectly loan funds or issue notes or give credit on its books to IDACORP. Idaho Power’s articles of incorporation contain restrictions on the payment of dividends on its common stock if preferred stock dividends are in arrears. As of the date of this report, Idaho Power has no preferred stock outstanding. In addition to contractual restrictions on the amount and payment of dividends, the Federal Power Act (FPA) prohibits the payment of dividends from "capital accounts." The term "capital account" is undefined in the FPA or its regulations, but Idaho Power does not believe the restriction would limit Idaho Power's ability to pay dividends out of current year earnings or retained earnings.

EARNINGS PER SHARE_

EARNINGS PER SHARE:	9 Months Ended
	Sep. 30, 2020
Earnings Per Share [Abstract]
Earnings Per Share	EARNINGS PER SHARE The table below presents the computation of IDACORP’s basic and diluted earnings per share for the three and nine months ended September 30, 2020 and 2019 (in thousands, except for per share amounts). Three months ended Nine months ended 2020 2019 2020 2019 Numerator: Net income attributable to IDACORP, Inc. $ 102,031 $ 89,876 $ 199,910 $ 185,718 Denominator: Weighted-average common shares outstanding - basic 50,541 50,499 50,534 50,502 Effect of dilutive securities 35 59 20 26 Weighted-average common shares outstanding - diluted 50,576 50,558 50,554 50,528 Basic earnings per share $ 2.02 $ 1.78 $ 3.96 $ 3.68 Diluted earnings per share $ 2.02 $ 1.78 $ 3.95 $ 3.68

COMMITMENTS_

COMMITMENTS:	9 Months Ended
	Sep. 30, 2020
Disclosure Text Block Supplement [Abstract]
Commitments	COMMITMENTS Purchase Obligations During the nine months ended September 30, 2020, IDACORP's and Idaho Power's contractual obligations, outside the ordinary course of business, did not change materially from the amounts disclosed in the notes to the consolidated financial statements in the 2019 Annual Report, except that Idaho Power entered into one new contract with a hydropower PURPA-qualifying facility and ten new replacement contracts for expiring power purchase agreements with hydropower and cogeneration PURPA-qualifying facilities, which increased Idaho Power's contractual purchase obligations by approximately $28 million over the 20-year terms of the contracts. Guarantees Through a self-bonding mechanism, Idaho Power guarantees its portion of reclamation activities and obligations at BCC, of which IERCo owns a one-third interest. This guarantee, which is renewed annually with the Wyoming Department of Environmental Quality, was $58.3 million at September 30, 2020, representing IERCo's one-third share of BCC's total reclamation obligation of $175.0 million. BCC has a reclamation trust fund set aside specifically for the purpose of paying these reclamation costs. At September 30, 2020, the value of BCC's reclamation trust fund was $157.5 million. During the nine months ended September 30, 2020, the reclamation trust fund made $3.3 million of distributions for reclamation activity costs associated with the BCC surface mine. BCC periodically assesses the adequacy of the reclamation trust fund and its estimate of future reclamation costs. To ensure that the reclamation trust fund maintains adequate reserves, BCC has the ability to, and does, add a per-ton surcharge to coal sales, all of which are made to the Jim Bridger plant. Because of the existence of the fund and the ability to apply a per-ton surcharge, the estimated fair value of this guarantee is minimal. In May 2019, the state of Wyoming enacted legislation that limits a mine operator's maximum amount of self-bonding. Idaho Power and the co-owners of BCC have until November 2020 to comply with the new regulations, which would reduce the portion of Idaho Power's guarantee of reclamation activities and obligations at BCC that Idaho Power is allowed to self-bond and require Idaho Power to acquire a surety bond, or provide other collateral, to secure the remaining portion of its guarantee. As of the date of this report, Idaho Power expects that the cost of a surety bond will be immaterial to IDACORP's and Idaho Power's consolidated financial statements. IDACORP and Idaho Power enter into financial agreements and power purchase and sale agreements that include indemnification provisions relating to various forms of claims or liabilities that may arise from the transactions contemplated by these agreements. Generally, a maximum obligation is not explicitly stated in the indemnification provisions and, therefore, the overall maximum amount of the obligation under such indemnification provisions cannot be reasonably estimated. IDACORP and Idaho Power periodically evaluate the likelihood of incurring costs under such indemnities based on their historical experience and the evaluation of the specific indemnities. As of September 30, 2020, the companies believe the likelihood is remote that IDACORP or Idaho Power would be required to perform under such indemnification provisions or otherwise incur any significant losses with respect to such indemnification obligations. Neither IDACORP nor Idaho Power has recorded any liability on their respective condensed consolidated balance sheets with respect to these indemnification obligations.

CONTINGENCIES_

CONTINGENCIES:	9 Months Ended
	Sep. 30, 2020
Loss Contingency [Abstract]
Contingencies	CONTINGENCIES IDACORP and Idaho Power have in the past and expect in the future to become involved in various claims, controversies, disputes, and other contingent matters, some of which involve litigation and regulatory or other contested proceedings. The ultimate resolution and outcome of litigation and regulatory proceedings is inherently difficult to determine, particularly where (a) the remedies or penalties sought are indeterminate, (b) the proceedings are in the early stages or the substantive issues have not been well developed, or (c) the matters involve complex or novel legal theories or a large number of parties. In accordance with applicable accounting guidance, IDACORP and Idaho Power, as applicable, establish an accrual for legal proceedings when those matters proceed to a stage where they present loss contingencies that are both probable and reasonably estimable. If the loss contingency at issue is not both probable and reasonably estimable, IDACORP and Idaho Power do not establish an accrual and the matter will continue to be monitored for any developments that would make the loss contingency both probable and reasonably estimable. As of the date of this report, IDACORP's and Idaho Power's accruals for loss contingencies are not material to their financial statements as a whole; however, future accruals could be material in a given period. IDACORP's and Idaho Power's determination is based on currently available information, and estimates presented in financial statements and other financial disclosures involve significant judgment and may be subject to significant uncertainty. IDACORP and Idaho Power are parties to legal claims and legal, tax, and regulatory actions and proceedings in the ordinary course of business and, as noted above, record an accrual for associated loss contingencies when they are probable and

BENEFIT PLANS_

BENEFIT PLANS:	9 Months Ended
	Sep. 30, 2020
Retirement Benefits, Description [Abstract]
Benefit Plans	BENEFIT PLANS Idaho Power has a noncontributory defined benefit pension plan (pension plan) and two nonqualified defined benefit plans for certain senior management employees called the Security Plan for Senior Management Employees I and Security Plan for Senior Management Employees II (together, SMSP). Idaho Power also has a nonqualified defined benefit pension plan for directors that was frozen in 2002. Remaining vested benefits from that plan are included with the SMSP in the disclosures below. The benefits under the pension plan are based on years of service and the employee’s final average earnings. Idaho Power also maintains a defined benefit postretirement benefit plan (consisting of health care and death benefits) that covers all employees who were enrolled in the active-employee group plan at the time of retirement as well as their spouses and qualifying dependents. The table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the three months ended September 30, 2020 and 2019 (in thousands). Pension Plan SMSP Postretirement Total 2020 2019 2020 2019 2020 2019 2020 2019 Service cost $ 10,747 $ 8,516 $ 54 $ (46) $ 258 $ 213 $ 11,059 $ 8,683 Interest cost 10,004 10,578 1,087 1,143 623 748 11,714 12,469 Expected return on plan assets (14,060) (12,156) — — (601) (555) (14,661) (12,711) Amortization of prior service cost 1 1 73 24 11 11 85 36 Amortization of net loss 4,331 3,391 933 634 — — 5,264 4,025 Net periodic benefit cost 11,023 10,330 2,147 1,755 291 417 13,461 12,502 Regulatory deferral of net periodic benefit cost (1) (10,511) (9,845) — — — — (10,511) (9,845) Previously deferred pension costs recognized (1) 4,288 4,288 — — — — 4,288 4,288 Net periodic benefit cost recognized for financial reporting (1)(2) $ 4,800 $ 4,773 $ 2,147 $ 1,755 $ 291 $ 417 $ 7,238 $ 6,945 (1) Net periodic benefit costs for the pension plan are recognized for financial reporting based upon the authorization of each regulatory jurisdiction in which Idaho Power operates. Under IPUC order, the Idaho portion of net periodic benefit cost is recorded as a regulatory asset and is recognized in the income statement as those costs are recovered through rates. (2) Of total net periodic benefit cost recognized for financial reporting, $4.3 million and $4.2 million, respectively, were recognized in "Other operations and maintenance" and $3.0 million and $2.7 million, respectively, were recognized in "Other expense, net" on the condensed consolidated statements of income of the companies for the three months ended September 30, 2020 and 2019. The table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the nine months ended September 30, 2020 and 2019 (in thousands). Pension Plan SMSP Postretirement Total 2020 2019 2020 2019 2020 2019 2020 2019 Service cost $ 32,240 $ 25,546 $ 160 $ (136) $ 772 $ 640 $ 33,172 $ 26,050 Interest cost 30,010 31,734 3,262 3,432 1,870 2,242 35,142 37,408 Expected return on plan assets (42,179) (36,467) — — (1,803) (1,665) (43,982) (38,132) Amortization of prior service cost 4 4 218 72 35 35 257 111 Amortization of net loss 12,994 10,173 2,800 1,900 — — 15,794 12,073 Net periodic benefit cost 33,069 30,990 6,440 5,268 874 1,252 40,383 37,510 Regulatory deferral of net periodic benefit cost (1) (31,532) (29,534) — — — — (31,532) (29,534) Previously deferred pension costs recognized (1) 12,865 12,865 — — — — 12,865 12,865 Net periodic benefit cost recognized for financial reporting (1)(2) $ 14,402 $ 14,321 $ 6,440 $ 5,268 $ 874 $ 1,252 $ 21,716 $ 20,841 (1) Net periodic benefit costs for the pension plan are recognized for financial reporting based upon the authorization of each regulatory jurisdiction in which Idaho Power operates. Under IPUC order, the Idaho portion of net periodic benefit cost is recorded as a regulatory asset and is recognized in the income statement as those costs are recovered through rates. (2) Of total net periodic benefit cost recognized for financial reporting, $12.8 million and $12.6 million, respectively, were recognized in "Other operations and maintenance" and $8.9 million and $8.2 million, respectively, were recognized in "Other expense, net" on the condensed consolidated statements of income of the companies for the nine months ended September 30, 2020 and 2019. During the nine months ended September 30, 2020, Idaho Power made $40 million of contributions to its defined benefit pension plan, in a continued effort to balance the regulatory collection of these expenditures with the amount and timing of contributions and to mitigate the cost of being in an underfunded position. Idaho Power has no further minimum contribution requirement to its defined benefit pension plan in 2020. The primary impact of pension contributions is on the timing of cash flows, as the timing of cost recovery lags behind contributions. Idaho Power also has an Employee Savings Plan that complies with Section 401(k) of the Internal Revenue Code and covers substantially all employees. Idaho Power matches specified percentages of employee contributions to the Employee Savings Plan.

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS:	9 Months Ended
	Sep. 30, 2020
General Discussion of Derivative Instruments and Hedging Activities [Abstract]
Derivative Financial Instruments	DERIVATIVE FINANCIAL INSTRUMENTS Commodity Price Risk Idaho Power is exposed to market risk relating to electricity, natural gas, and other fuel commodity prices, all of which are heavily influenced by supply and demand. Market risk may be influenced by market participants’ nonperformance of their contractual obligations and commitments, which affects the supply of or demand for the commodity. Idaho Power uses derivative instruments, such as physical and financial forward contracts, for both electricity and fuel to manage the risks relating to these commodity price exposures. The primary objectives of Idaho Power’s energy purchase and sale activity are to meet the demand of retail electric customers, maintain appropriate physical reserves to ensure reliability, and make economic use of temporary surpluses that may develop. All of Idaho Power's derivative instruments have been entered into for the purpose of economically hedging forecasted purchases and sales, though none of these instruments have been designated as cash flow hedges. Idaho Power offsets fair value amounts recognized on its balance sheet and applies collateral related to derivative instruments executed with the same counterparty under the same master netting agreement. Idaho Power does not offset a counterparty's current derivative contracts with the counterparty's long-term derivative contracts, although Idaho Power's master netting arrangements would allow current and long-term positions to be offset in the event of default. Also, in the event of default, Idaho Power's master netting arrangements would allow for the offsetting of all transactions executed under the master netting arrangement. These types of transactions may include non-derivative instruments, derivatives qualifying for scope exceptions, receivables and payables arising from settled positions, and other forms of non-cash collateral (such as letters of credit). These types of transactions are excluded from the offsetting presented in the derivative fair value and offsetting table that follows. The table below presents the gains and losses on derivatives not designated as hedging instruments for the three and nine months ended September 30, 2020 and 2019 (in thousands). Gain/(Loss) on Derivatives Recognized in Income (1) Location of Realized Gain/(Loss) on Derivatives Recognized in Income Three months ended Nine months ended 2020 2019 2020 2019 Financial swaps Operating revenues $ 1,039 $ 3,693 $ 2,173 $ 904 Financial swaps Purchased power (2,264) (2,981) (3,579) (2,294) Financial swaps Fuel expense (1,115) (815) (4,032) 11,587 Forward contracts Operating revenues 229 106 349 170 Forward contracts Purchased power (198) (106) (313) (170) Forward contracts Fuel expense (6) 191 (25) 607 (1) Excludes unrealized gains or losses on derivatives, which are recorded on the balance sheet as regulatory assets or regulatory liabilities. Settlement gains and losses on electricity swap contracts are recorded on the income statement in operating revenues or purchased power depending on the forecasted position being economically hedged by the derivative contract. Settlement gains and losses on contracts for natural gas are reflected in fuel expense. Settlement gains and losses on diesel derivatives are recorded in other operations and maintenance expense. See Note 12 - "Fair Value Measurements" for additional information concerning the determination of fair value for Idaho Power’s assets and liabilities from price risk management activities. Credit Risk At September 30, 2020, Idaho Power did not have material credit risk exposure from financial instruments, including derivatives. Idaho Power monitors credit risk exposure through reviews of counterparty credit quality, corporate-wide counterparty credit exposure, and corporate-wide counterparty concentration levels. Idaho Power manages these risks by establishing credit and concentration limits on transactions with counterparties and requiring contractual guarantees, cash deposits, or letters of credit from counterparties or their affiliates, as deemed necessary. Idaho Power’s physical power, physical gas, and financial transactions are generally under standardized industry contracts. These contracts contain adequate assurance clauses requiring collateralization if a counterparty has debt that is downgraded below investment grade by at least one rating agency. Credit-Contingent Features Certain Idaho Power derivative instruments contain provisions that require Idaho Power's unsecured debt to maintain an investment grade credit rating from Moody's Investors Service and Standard & Poor's Ratings Services. If Idaho Power's unsecured debt 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 full overnight collateralization on derivative instruments in net liability positions. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position at September 30, 2020, was $0.3 million. Idaho Power posted no cash collateral related to this amount. If the credit-risk-related contingent features underlying these agreements were triggered on September 30, 2020, Idaho Power would have been required to pay or post collateral to its counterparties up to an additional $4.6 million to cover the open liability positions as well as completed transactions that have not yet been paid. Derivative Instrument Summary The table below presents the fair values and locations of derivative instruments not designated as hedging instruments recorded on the balance sheets and reconciles the gross amounts of derivatives recognized as assets and as liabilities to the net amounts presented in the balance sheets at September 30, 2020, and December 31, 2019 (in thousands). Asset Derivatives Liability Derivatives Balance Sheet Location Gross Fair Value Amounts Offset Net Assets Gross Fair Value Amounts Offset Net Liabilities September 30, 2020 Current: Financial swaps Other current assets $ 3,270 $ (817) (1) $ 2,453 $ 65 $ (65) $ — Financial swaps Other current liabilities 6 (6) — 152 (6) 146 Forward contracts Other current liabilities — — — 24 — 24 Long-term: Financial swaps Other assets 111 (23) 88 23 (23) — Total $ 3,387 $ (846) $ 2,541 $ 264 $ (94) $ 170 December 31, 2019 Current: Financial swaps Other current assets $ 2,426 $ (2,034) $ 392 $ 2,034 $ (2,034) $ — Financial swaps Other current liabilities 134 (134) — 924 (134) 790 Forward contracts Other current assets 13 — 13 — — — Forward contracts Other current liabilities — — — 32 — 32 Long-term: Financial swaps Other liabilities 3 (3) — 27 (3) 24 Total $ 2,576 $ (2,171) $ 405 $ 3,017 $ (2,171) $ 846 (1) Current asset derivative amounts offset include $0.8 million of collateral payable for the period ended September 30, 2020. The table below presents the volume of derivative commodity forward contracts and swaps outstanding at September 30, 2020 and 2019 (in thousands of units). September 30, Commodity Units 2020 2019 Electricity purchases MWh 113 109 Electricity sales MWh — 10 Natural gas purchases MMBtu 7,930 7,798 Natural gas sales MMBtu 775 —

FAIR VALUE MEASUREMENTS_

FAIR VALUE MEASUREMENTS:	9 Months Ended
	Sep. 30, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS IDACORP and Idaho Power have categorized their financial instruments into a three-level fair value hierarchy, based on the priority of the inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). If the inputs used to measure the financial instruments fall within different levels of the hierarchy, the categorization is based on the lowest level input that is significant to the fair value measurement of the instrument. Financial assets and liabilities recorded on the condensed consolidated balance sheets are categorized based on the inputs to the valuation techniques as follows: • Level 1: Financial assets and liabilities whose values are based on unadjusted quoted prices for identical assets or liabilities in an active market that IDACORP and Idaho Power have the ability to access. • Level 2: Financial assets and liabilities whose values are based on the following: a) quoted prices for similar assets or liabilities in active markets; b) quoted prices for identical or similar assets or liabilities in non-active markets; c) pricing models whose inputs are observable for substantially the full term of the asset or liability; and d) pricing models whose inputs are derived principally from or corroborated by observable market data through correlation or other means for substantially the full term of the asset or liability. IDACORP and Idaho Power Level 2 inputs are based on quoted market prices adjusted for location using corroborated, observable market data. • Level 3: Financial assets and liabilities whose values are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. These inputs reflect management’s own assumptions about the assumptions a market participant would use in pricing the asset or liability. IDACORP’s and Idaho Power’s assessment of a particular input's significance 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. An item recorded at fair value is reclassified among levels when changes in the nature of valuation inputs cause the item to no longer meet the criteria for the level in which it was previously categorized. There were no transfers between levels or material changes in valuation techniques or inputs during the nine months ended September 30, 2020. The table below presents information about IDACORP’s and Idaho Power’s assets and liabilities measured at fair value on a recurring basis as of September 30, 2020, and December 31, 2019 (in thousands). September 30, 2020 December 31, 2019 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets: Money market funds IDACORP (1) $ 30,682 $ — $ — $ 30,682 $ 64,173 $ — $ — $ 64,173 Idaho Power 56,798 — — 56,798 26,510 — — 26,510 Derivatives 2,541 — — 2,541 392 13 — 405 Equity securities 42,401 — — 42,401 42,738 — — 42,738 Liabilities: Derivatives 146 24 — 170 814 32 — 846 (1) Holding company only. Does not include amounts held by Idaho Power. Idaho Power’s derivatives are contracts entered into as part of its management of loads and resources. Electricity derivatives are valued on the Intercontinental Exchange (ICE) with quoted prices in an active market. Natural gas and diesel derivatives are valued using New York Mercantile Exchange (NYMEX) and ICE pricing, adjusted for location basis, which are also quoted under NYMEX and ICE pricing. Equity securities consist of employee-directed investments related to an executive deferred compensation plan and actively traded money market and exchange traded funds related to the SMSP. The investments are measured using quoted prices in active markets and are held in a Rabbi trust. The table below presents the carrying value and estimated fair value of financial instruments that are not reported at fair value, as of September 30, 2020, and December 31, 2019, using available market information and appropriate valuation methodologies (in thousands). September 30, 2020 December 31, 2019 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value IDACORP Assets: Notes receivable (1) $ 3,804 $ 3,804 $ 3,804 $ 3,804 Liabilities: Long-term debt, including current portion (1) 2,000,358 2,440,622 1,836,659 2,083,931 Idaho Power Liabilities: Long-term debt, including current portion (1) 2,000,358 2,440,622 1,836,659 2,083,931 (1) Notes receivable and long-term debt are categorized as Level 3 and Level 2, respectively, of the fair value hierarchy, as defined earlier in this Note 12 - "Fair Value Measurements." Notes receivable are related to Ida-West and are valued based on unobservable inputs, including discounted cash flows, which are partially based on forecasted hydropower conditions. Long-term debt is not traded on an exchange and is valued using quoted rates for similar debt in active markets. Carrying values for cash and cash equivalents, deposits, customer and other receivables, notes payable, accounts payable, interest accrued, and taxes accrued approximate fair value.

SEGMENT INFORMATION_

SEGMENT INFORMATION:	9 Months Ended
	Sep. 30, 2020
Segment Reporting, Measurement Disclosures [Abstract]
Segment Information	SEGMENT INFORMATION IDACORP’s only reportable segment is utility operations. The utility operations segment’s primary source of revenue is the regulated operations of Idaho Power. Idaho Power’s regulated operations include the generation, transmission, distribution, purchase, and sale of electricity. This segment also includes income from IERCo, a wholly-owned subsidiary of Idaho Power that is also subject to regulation and is a one-third owner of BCC, an unconsolidated joint venture. IDACORP’s other operating segments are below the quantitative and qualitative thresholds for reportable segments and are included in the "All Other" category in the table below. This category is comprised of IFS’s investments in affordable housing developments and historic rehabilitation projects, Ida-West’s joint venture investments in small hydropower generation projects, and IDACORP’s holding company expenses. The table below summarizes the segment information for IDACORP’s utility operations and the total of all other segments, and reconciles this information to total enterprise amounts (in thousands). Utility All Eliminations Consolidated Three months ended September 30, 2020: Revenues $ 424,170 1,091 $ — $ 425,261 Net income attributable to IDACORP, Inc. 100,389 1,642 — 102,031 Total assets as of September 30, 2020 6,769,567 247,753 (87,161) 6,930,159 Three months ended September 30, 2019: Revenues $ 385,028 $ 1,292 $ — $ 386,320 Net income attributable to IDACORP, Inc. 87,979 1,897 — 89,876 Nine months ended September 30, 2020: Revenues $ 1,032,324 $ 2,711 $ — $ 1,035,035 Net income attributable to IDACORP, Inc. 196,089 3,821 — 199,910 Nine months ended September 30, 2019: Revenues $ 1,050,574 $ 2,961 $ — $ 1,053,535 Net income attributable to IDACORP, Inc. 180,740 4,978 — 185,718

CHANGES IN IDAHO POWER RETAINED

CHANGES IN IDAHO POWER RETAINED EARNINGS (Notes)	9 Months Ended
	Sep. 30, 2020
Changes in Retained Earnings [Line Items]
Changes in Idaho Power Retained Earnings	CHANGES IN IDAHO POWER RETAINED EARNINGS The table below presents changes in Idaho Power retained earnings during the three and nine months ended September 30, 2020 and 2019 (in thousands). Three months ended Nine months ended 2020 2019 2020 2019 Balance at beginning of period $ 1,531,566 $ 1,438,019 $ 1,503,805 $ 1,409,245 Net income 100,389 87,979 196,089 180,740 Dividends to parent (33,959) (31,932) (101,898) (95,919) Balance at end of period $ 1,597,996 $ 1,494,066 $ 1,597,996 $ 1,494,066

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES: Organization, Consolidation, Presentation, and Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Revenue Recognition, Policy	The FCA mechanism revenues include only the initial recognition of FCA revenues when they meet the regulator-specified conditions for recognition. Revenue from contracts with customers excludes the portion of the tariff price representing FCA revenues that Idaho Power initially recorded in prior periods when revenues met regulator-specified conditions. When Idaho Power includes those amounts in the price of utility service billed to customers, Idaho Power records such amounts as recovery of the associated regulatory asset or liability and not as revenues. Derivative revenues include gains from settled electricity swaps and sales of electricity under forward sales contracts that are bundled with renewable energy credits. Related to these forward sales, Idaho Power simultaneously enters into forward purchases of electricity for the same quantity at the same location, which are recorded in purchased power on the condensed consolidated statements of income.
Nature of Business	IDACORP is a holding company formed in 1998 whose principal operating subsidiary is Idaho Power. Idaho Power is an electric utility engaged in the generation, transmission, distribution, sale, and purchase of electric energy and capacity with a service area covering approximately 24,000 square miles in southern Idaho and eastern Oregon. Idaho Power is regulated primarily by the state utility regulatory commissions of Idaho and Oregon and the Federal Energy Regulatory Commission (FERC). Idaho Power is the parent of Idaho Energy Resources Co. (IERCo), a joint venturer in Bridger Coal Company (BCC), which mines and supplies coal to the Jim Bridger generating plant (Jim Bridger plant) owned in part by Idaho Power.
Regulation of Utility Operations	As a regulated utility, many of Idaho Power's fundamental business decisions are subject to the approval of governmental agencies, including the prices that Idaho Power is authorized to charge for its electric service. These approvals are a critical factor in determining IDACORP's and Idaho Power's results of operations and financial condition.IDACORP's and Idaho Power's financial statements reflect the effects of the different ratemaking principles followed by the jurisdictions regulating Idaho Power. The application of accounting principles related to regulated operations sometimes results in Idaho Power recording expenses and revenues in a different period than when an unregulated enterprise would record such expenses and revenues. In these instances, the amounts are deferred or accrued as regulatory assets or regulatory liabilities on the balance sheet. Regulatory assets represent incurred costs that have been deferred because it is probable they will be recovered from customers through future rates. Regulatory liabilities represent obligations to make refunds to customers for previous collections, or represent amounts collected in advance of incurring an expense.
Financial Statements	In the opinion of management of IDACORP and Idaho Power, the accompanying unaudited condensed consolidated financial statements contain all adjustments necessary to present fairly each company's consolidated financial position as of September 30, 2020, consolidated results of operations for the three and nine months ended September 30, 2020 and 2019, and consolidated cash flows for the nine months ended September 30, 2020 and 2019. These adjustments are of a normal and recurring nature. These financial statements do not contain the complete detail or note disclosures concerning accounting policies and other matters that would be included in full-year financial statements and should be read in conjunction with the audited consolidated financial statements included in IDACORP’s and Idaho Power’s Annual Report on Form 10-K for the year ended December 31, 2019 (2019 Annual Report). The results of operations for the interim period are not necessarily indicative of the results to be expected for the full year. A change in management's estimates or assumptions could have a material impact on IDACORP's or Idaho Power's respective financial condition and results of operations during the period in which such change occurred.
Management Estimates	Management makes estimates and assumptions when preparing financial statements in conformity with generally accepted accounting principles. These estimates and assumptions include those related to rate regulation, retirement benefits, contingencies, asset impairment, income taxes, unbilled revenues, and bad debt. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. These estimates involve judgments with respect to, among other things, future economic factors that are difficult to predict and are beyond management's control. Accordingly, actual results could differ from those estimates.
Income Tax	In accordance with interim reporting requirements, IDACORP and Idaho Power use an estimated annual effective tax rate for computing their 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 effective 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.
Fair Value of Financial Instruments	IDACORP and Idaho Power have categorized their financial instruments into a three-level fair value hierarchy, based on the priority of the inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). If the inputs used to measure the financial instruments fall within different levels of the hierarchy, the categorization is based on the lowest level input that is significant to the fair value measurement of the instrument. Financial assets and liabilities recorded on the condensed consolidated balance sheets are categorized based on the inputs to the valuation techniques as follows: • Level 1: Financial assets and liabilities whose values are based on unadjusted quoted prices for identical assets or liabilities in an active market that IDACORP and Idaho Power have the ability to access. • Level 2: Financial assets and liabilities whose values are based on the following: a) quoted prices for similar assets or liabilities in active markets; b) quoted prices for identical or similar assets or liabilities in non-active markets; c) pricing models whose inputs are observable for substantially the full term of the asset or liability; and d) pricing models whose inputs are derived principally from or corroborated by observable market data through correlation or other means for substantially the full term of the asset or liability. IDACORP and Idaho Power Level 2 inputs are based on quoted market prices adjusted for location using corroborated, observable market data. • Level 3: Financial assets and liabilities whose values are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. These inputs reflect management’s own assumptions about the assumptions a market participant would use in pricing the asset or liability.
New Accounting Pronouncements	New and Recently Adopted Accounting Pronouncements In June 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments to provide financial statement users with more information about expected credit losses on financial instruments and other commitments. The ASU revises the incurred loss impairment methodology to reflect current expected credit losses and requires consideration of a broader range of information to estimate credit losses. IDACORP and Idaho Power adopted ASU 2016-13 on January 1, 2020. The adoption did not have a material impact on their respective financial statements but did result in the additional disclosure below. The measurement of expected credit losses on Idaho Power accounts receivable is based upon historical experience, current conditions, and forecasted information that may affect collections on the outstanding balance. Generally, this includes adjustments based upon a combination of historical write-off experience, aging of accounts receivable, an analysis of specific customer accounts, and an evaluation of whether there are current or forecasted economic conditions that might cause variation in collection from the historical experience. In response to the COVID-19 public health crisis, Idaho Power provided certain relief to customers including temporarily suspending disconnections for customers and temporarily waiving late fees. This relief as well as the economic conditions created by the response to the COVID-19 public health crisis have resulted in higher aged accounts receivable and an increase in the number of late payments. Idaho Power expects higher uncollectible account write-offs as a result of the COVID-19 public health crisis and, accordingly, increased its allowance for uncollectible accounts related to customer receivables at September 30, 2020. The allowance for uncollectible accounts increased to 3.7 percent of the total customer receivables balance at September 30, 2020, compared with 1.9 percent at December 31, 2019, and 1.4 percent at September 30, 2019. The following table provides a rollforward of the allowance for uncollectible accounts related to customer receivables for the nine months ended September 30, 2020 and 2019 (in thousands): Nine months ended 2020 2019 Balance at beginning of period $ 1,401 $ 1,725 Additions to the allowance 3,543 1,663 Write-offs, net of recoveries (1,020) (1,975) Balance at end of period $ 3,924 $ 1,413 Allowance for uncollectible accounts as a percentage of customer receivables 3.7 % 1.4 % In August 2018, the FASB issued ASU 2018-15, Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract , to provide guidance on implementation costs incurred in a cloud computing arrangement that is a service contract. ASU 2018-15 aligns the recognition of such implementation costs with the accounting for costs incurred to implement an internal-use software solution. However, the balance sheet line item for presentation of capitalized implementation costs for a cloud computing arrangement that is a service contract should be the same as that for the prepayment of fees related to the same arrangement, while capitalized implementation costs for internal-use software solutions are often included in property, plant, and equipment as an intangible asset. IDACORP and Idaho Power adopted ASU 2018-15 on January 1, 2020. The adoption did not have a material impact on their respective financial statements.
Derivatives, Methods of Accounting, Derivatives Not Designated or Qualifying as Hedges [Policy Text Block]	Idaho Power is exposed to market risk relating to electricity, natural gas, and other fuel commodity prices, all of which are heavily influenced by supply and demand. Market risk may be influenced by market participants’ nonperformance of their contractual obligations and commitments, which affects the supply of or demand for the commodity. Idaho Power uses derivative instruments, such as physical and financial forward contracts, for both electricity and fuel to manage the risks relating to these commodity price exposures. The primary objectives of Idaho Power’s energy purchase and sale activity are to meet the demand of retail electric customers, maintain appropriate physical reserves to ensure reliability, and make economic use of temporary surpluses that may develop. All of Idaho Power's derivative instruments have been entered into for the purpose of economically hedging forecasted purchases and sales, though none of these instruments have been designated as cash flow hedges. Idaho Power offsets fair value amounts recognized on its balance sheet and applies collateral related to derivative instruments executed with the same counterparty under the same master netting agreement. Idaho Power does not offset a counterparty's current derivative contracts with the counterparty's long-term derivative contracts, although Idaho Power's master netting arrangements would allow current and long-term positions to be offset in the event of default. Also, in the event of default, Idaho Power's master netting arrangements would allow for the offsetting of all transactions executed under the master netting arrangement. These types of transactions may include non-derivative instruments, derivatives qualifying for scope exceptions, receivables and payables arising from settled positions, and other forms of non-cash collateral (such as letters of credit). These types of transactions are excluded from the offsetting presented in the derivative fair value and offsetting table that follows.
Derivatives, Reporting of Derivative Activity	Settlement gains and losses on electricity swap contracts are recorded on the income statement in operating revenues or purchased power depending on the forecasted position being economically hedged by the derivative contract. Settlement gains and losses on contracts for natural gas are reflected in fuel expense. Settlement gains and losses on diesel derivatives are recorded in other operations and maintenance expense.
Segment Reporting	IDACORP’s only reportable segment is utility operations. The utility operations segment’s primary source of revenue is the regulated operations of Idaho Power. Idaho Power’s regulated operations include the generation, transmission, distribution, purchase, and sale of electricity. This segment also includes income from IERCo, a wholly-owned subsidiary of Idaho Power that is also subject to regulation and is a one-third owner of BCC, an unconsolidated joint venture. IDACORP’s other operating segments are below the quantitative and qualitative thresholds for reportable segments and are included in the "All Other" category in the table below. This category is comprised of IFS’s investments in affordable housing developments and historic rehabilitation projects, Ida-West’s joint venture investments in small hydropower generation projects, and IDACORP’s holding company expenses.

REVENUES_ (Policies)

REVENUES: (Policies)	9 Months Ended
	Sep. 30, 2020
Revenues [Abstract]
Revenue Recognition, Policy	The FCA mechanism revenues include only the initial recognition of FCA revenues when they meet the regulator-specified conditions for recognition. Revenue from contracts with customers excludes the portion of the tariff price representing FCA revenues that Idaho Power initially recorded in prior periods when revenues met regulator-specified conditions. When Idaho Power includes those amounts in the price of utility service billed to customers, Idaho Power records such amounts as recovery of the associated regulatory asset or liability and not as revenues. Derivative revenues include gains from settled electricity swaps and sales of electricity under forward sales contracts that are bundled with renewable energy credits. Related to these forward sales, Idaho Power simultaneously enters into forward purchases of electricity for the same quantity at the same location, which are recorded in purchased power on the condensed consolidated statements of income.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities (Policies)	9 Months Ended
	Sep. 30, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives, Reporting of Derivative Activity	Settlement gains and losses on electricity swap contracts are recorded on the income statement in operating revenues or purchased power depending on the forecasted position being economically hedged by the derivative contract. Settlement gains and losses on contracts for natural gas are reflected in fuel expense. Settlement gains and losses on diesel derivatives are recorded in other operations and maintenance expense.
Derivatives, Methods of Accounting, Derivatives Not Designated or Qualifying as Hedges [Policy Text Block]	Idaho Power is exposed to market risk relating to electricity, natural gas, and other fuel commodity prices, all of which are heavily influenced by supply and demand. Market risk may be influenced by market participants’ nonperformance of their contractual obligations and commitments, which affects the supply of or demand for the commodity. Idaho Power uses derivative instruments, such as physical and financial forward contracts, for both electricity and fuel to manage the risks relating to these commodity price exposures. The primary objectives of Idaho Power’s energy purchase and sale activity are to meet the demand of retail electric customers, maintain appropriate physical reserves to ensure reliability, and make economic use of temporary surpluses that may develop. All of Idaho Power's derivative instruments have been entered into for the purpose of economically hedging forecasted purchases and sales, though none of these instruments have been designated as cash flow hedges. Idaho Power offsets fair value amounts recognized on its balance sheet and applies collateral related to derivative instruments executed with the same counterparty under the same master netting agreement. Idaho Power does not offset a counterparty's current derivative contracts with the counterparty's long-term derivative contracts, although Idaho Power's master netting arrangements would allow current and long-term positions to be offset in the event of default. Also, in the event of default, Idaho Power's master netting arrangements would allow for the offsetting of all transactions executed under the master netting arrangement. These types of transactions may include non-derivative instruments, derivatives qualifying for scope exceptions, receivables and payables arising from settled positions, and other forms of non-cash collateral (such as letters of credit). These types of transactions are excluded from the offsetting presented in the derivative fair value and offsetting table that follows.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2020
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Allowance for Credit Loss [Table Text Block]	The following table provides a rollforward of the allowance for uncollectible accounts related to customer receivables for the nine months ended September 30, 2020 and 2019 (in thousands): Nine months ended 2020 2019 Balance at beginning of period $ 1,401 $ 1,725 Additions to the allowance 3,543 1,663 Write-offs, net of recoveries (1,020) (1,975) Balance at end of period $ 3,924 $ 1,413 Allowance for uncollectible accounts as a percentage of customer receivables 3.7 % 1.4 %

INCOME TAXES_ Level 3 (Tables)

INCOME TAXES: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	The following table provides a summary of income tax expense for the nine months ended September 30, 2020 and 2019 (in thousands): IDACORP Idaho Power 2020 2019 2020 2019 Income tax at statutory rates (federal and state) $ 57,420 $ 54,626 $ 56,718 $ 53,496 First mortgage bond redemption costs (890) — (890) — Excess deferred income tax reversal (3,222) (4,123) (3,222) (4,123) Income tax return adjustments (2,555) 1,071 (2,507) 993 Other (1) (27,587) (25,068) (25,839) (23,275) Income tax expense $ 23,166 $ 26,506 $ 24,260 $ 27,091 Effective tax rate 10.4 % 12.5 % 11.0 % 13.0 %

REVENUES_ Electric utility oper

REVENUES: Electric utility operating revenues (Tables)	9 Months Ended
	Sep. 30, 2020
Electric utility operating revenues [Line Items]
Electric utility operating revenues [Table Text Block]	The following table provides a summary of electric utility operating revenues for IDACORP and Idaho Power for the three and nine months ended September 30, 2020 and 2019 (in thousands): Three months ended Nine months ended 2020 2019 2020 2019 Electric utility operating revenues: Revenue from contracts with customers $ 402,941 $ 367,101 $ 984,096 $ 1,010,281 Alternative revenue programs and other revenues 21,229 17,927 48,228 40,293 Total electric utility operating revenues $ 424,170 $ 385,028 $ 1,032,324 $ 1,050,574

REVENUES_ (Tables)

REVENUES: (Tables)	9 Months Ended
	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Disaggregation of Revenue [Table Text Block]	The following table presents revenues from contracts with customers disaggregated by revenue source for the three and nine months ended September 30, 2020 and 2019 (in thousands): Three months ended Nine months ended 2020 2019 2020 2019 Revenues from contracts with customers: Retail revenues: Residential (includes $4,896, $6,446, $24,740, and $24,988, respectively, related to the FCA) (1) $ 143,822 $ 133,550 $ 398,180 $ 388,566 Commercial (includes $330, $330, $1,211, and $1,022, respectively, related to the FCA) (1) 82,279 80,304 219,006 224,382 Industrial 50,154 47,122 136,001 138,222 Irrigation 88,188 82,659 149,711 132,613 Deferred revenue related to HCC relicensing AFUDC (2) (2,815) (2,815) (6,861) (6,861) Total retail revenues 361,628 340,820 896,037 876,922 Less: FCA mechanism revenues (1) (5,226) (6,776) (25,951) (26,010) Wholesale energy sales 12,178 5,321 22,952 68,693 Transmission wheeling-related revenues 16,896 12,498 38,750 40,743 Energy efficiency program revenues 10,530 8,439 31,957 30,008 Other revenues from contracts with customers 6,935 6,799 20,351 19,925 Total revenues from contracts with customers $ 402,941 $ 367,101 $ 984,096 $ 1,010,281 (1) The FCA mechanism is an alternative revenue program in the Idaho jurisdiction and does not represent revenue from contracts with customers. (2) As part of its January 30, 2009, general rate case order, the IPUC is allowing Idaho Power to recover a portion of the allowance for funds used during construction (AFUDC) on construction work in progress related to the Hells Canyon Complex (HCC) relicensing process, even though the relicensing process is not yet complete and the costs have not been moved to electric plant in service. Idaho Power is collecting $8.8 million annually in the Idaho jurisdiction but is deferring revenue recognition of the amounts collected until the license is issued and the accumulated license costs approved for recovery are placed in service.

REVENUES_ Alternative revenue p

REVENUES: Alternative revenue program and other revenues (Tables)	9 Months Ended
	Sep. 30, 2020
Regulated Operations [Abstract]
Alternative revenue programs and other revenues [Table Text Block]	The table below presents the FCA mechanism revenues and other revenues for the three and nine months ended September 30, 2020 and 2019 (in thousands): Three months ended Nine months ended 2020 2019 2020 2019 Alternative revenue programs and other revenues: FCA mechanism revenues $ 5,226 6,776 $ 25,951 $ 26,010 Derivative revenues 16,003 11,151 22,277 14,283 Total alternative revenue programs and other revenues $ 21,229 $ 17,927 $ 48,228 $ 40,293

EARNINGS PER SHARE_ Level 3 (Ta

EARNINGS PER SHARE: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2020
Earnings Per Share, Basic and Diluted [Abstract]
Schedule of Earnings Per Share, Diluted, by Common Class, Including Two Class Method	The table below presents the computation of IDACORP’s basic and diluted earnings per share for the three and nine months ended September 30, 2020 and 2019 (in thousands, except for per share amounts). Three months ended Nine months ended 2020 2019 2020 2019 Numerator: Net income attributable to IDACORP, Inc. $ 102,031 $ 89,876 $ 199,910 $ 185,718 Denominator: Weighted-average common shares outstanding - basic 50,541 50,499 50,534 50,502 Effect of dilutive securities 35 59 20 26 Weighted-average common shares outstanding - diluted 50,576 50,558 50,554 50,528 Basic earnings per share $ 2.02 $ 1.78 $ 3.96 $ 3.68 Diluted earnings per share $ 2.02 $ 1.78 $ 3.95 $ 3.68

BENEFIT PLANS_ Level 3 (Tables)

BENEFIT PLANS: Level 3 (Tables)	3 Months Ended
	Sep. 30, 2020
Defined Benefit Plan Disclosure
Schedule of Defined Benefit Plans Disclosures [Table Text Block]	The table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the three months ended September 30, 2020 and 2019 (in thousands). Pension Plan SMSP Postretirement Total 2020 2019 2020 2019 2020 2019 2020 2019 Service cost $ 10,747 $ 8,516 $ 54 $ (46) $ 258 $ 213 $ 11,059 $ 8,683 Interest cost 10,004 10,578 1,087 1,143 623 748 11,714 12,469 Expected return on plan assets (14,060) (12,156) — — (601) (555) (14,661) (12,711) Amortization of prior service cost 1 1 73 24 11 11 85 36 Amortization of net loss 4,331 3,391 933 634 — — 5,264 4,025 Net periodic benefit cost 11,023 10,330 2,147 1,755 291 417 13,461 12,502 Regulatory deferral of net periodic benefit cost (1) (10,511) (9,845) — — — — (10,511) (9,845) Previously deferred pension costs recognized (1) 4,288 4,288 — — — — 4,288 4,288 Net periodic benefit cost recognized for financial reporting (1)(2) $ 4,800 $ 4,773 $ 2,147 $ 1,755 $ 291 $ 417 $ 7,238 $ 6,945 (1) Net periodic benefit costs for the pension plan are recognized for financial reporting based upon the authorization of each regulatory jurisdiction in which Idaho Power operates. Under IPUC order, the Idaho portion of net periodic benefit cost is recorded as a regulatory asset and is recognized in the income statement as those costs are recovered through rates. (2) Of total net periodic benefit cost recognized for financial reporting, $4.3 million and $4.2 million, respectively, were recognized in "Other operations and maintenance" and $3.0 million and $2.7 million, respectively, were recognized in "Other expense, net" on the condensed consolidated statements of income of the companies for the three months ended September 30, 2020 and 2019. The table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the nine months ended September 30, 2020 and 2019 (in thousands). Pension Plan SMSP Postretirement Total 2020 2019 2020 2019 2020 2019 2020 2019 Service cost $ 32,240 $ 25,546 $ 160 $ (136) $ 772 $ 640 $ 33,172 $ 26,050 Interest cost 30,010 31,734 3,262 3,432 1,870 2,242 35,142 37,408 Expected return on plan assets (42,179) (36,467) — — (1,803) (1,665) (43,982) (38,132) Amortization of prior service cost 4 4 218 72 35 35 257 111 Amortization of net loss 12,994 10,173 2,800 1,900 — — 15,794 12,073 Net periodic benefit cost 33,069 30,990 6,440 5,268 874 1,252 40,383 37,510 Regulatory deferral of net periodic benefit cost (1) (31,532) (29,534) — — — — (31,532) (29,534) Previously deferred pension costs recognized (1) 12,865 12,865 — — — — 12,865 12,865 Net periodic benefit cost recognized for financial reporting (1)(2) $ 14,402 $ 14,321 $ 6,440 $ 5,268 $ 874 $ 1,252 $ 21,716 $ 20,841 (1) Net periodic benefit costs for the pension plan are recognized for financial reporting based upon the authorization of each regulatory jurisdiction in which Idaho Power operates. Under IPUC order, the Idaho portion of net periodic benefit cost is recorded as a regulatory asset and is recognized in the income statement as those costs are recovered through rates. (2) Of total net periodic benefit cost recognized for financial reporting, $12.8 million and $12.6 million, respectively, were recognized in "Other operations and maintenance" and $8.9 million and $8.2 million, respectively, were recognized in "Other expense, net" on the condensed consolidated statements of income of the companies for the nine months ended September 30, 2020 and 2019.

DERIVATIVE FINANCIAL INSTRUME_2

DERIVATIVE FINANCIAL INSTRUMENTS: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2020
Summary of Derivative Instruments [Abstract]
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	The table below presents the gains and losses on derivatives not designated as hedging instruments for the three and nine months ended September 30, 2020 and 2019 (in thousands). Gain/(Loss) on Derivatives Recognized in Income (1) Location of Realized Gain/(Loss) on Derivatives Recognized in Income Three months ended Nine months ended 2020 2019 2020 2019 Financial swaps Operating revenues $ 1,039 $ 3,693 $ 2,173 $ 904 Financial swaps Purchased power (2,264) (2,981) (3,579) (2,294) Financial swaps Fuel expense (1,115) (815) (4,032) 11,587 Forward contracts Operating revenues 229 106 349 170 Forward contracts Purchased power (198) (106) (313) (170) Forward contracts Fuel expense (6) 191 (25) 607 (1) Excludes unrealized gains or losses on derivatives, which are recorded on the balance sheet as regulatory assets or regulatory liabilities.
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The table below presents the fair values and locations of derivative instruments not designated as hedging instruments recorded on the balance sheets and reconciles the gross amounts of derivatives recognized as assets and as liabilities to the net amounts presented in the balance sheets at September 30, 2020, and December 31, 2019 (in thousands). Asset Derivatives Liability Derivatives Balance Sheet Location Gross Fair Value Amounts Offset Net Assets Gross Fair Value Amounts Offset Net Liabilities September 30, 2020 Current: Financial swaps Other current assets $ 3,270 $ (817) (1) $ 2,453 $ 65 $ (65) $ — Financial swaps Other current liabilities 6 (6) — 152 (6) 146 Forward contracts Other current liabilities — — — 24 — 24 Long-term: Financial swaps Other assets 111 (23) 88 23 (23) — Total $ 3,387 $ (846) $ 2,541 $ 264 $ (94) $ 170 December 31, 2019 Current: Financial swaps Other current assets $ 2,426 $ (2,034) $ 392 $ 2,034 $ (2,034) $ — Financial swaps Other current liabilities 134 (134) — 924 (134) 790 Forward contracts Other current assets 13 — 13 — — — Forward contracts Other current liabilities — — — 32 — 32 Long-term: Financial swaps Other liabilities 3 (3) — 27 (3) 24 Total $ 2,576 $ (2,171) $ 405 $ 3,017 $ (2,171) $ 846 (1) Current asset derivative amounts offset include $0.8 million of collateral payable for the period ended September 30, 2020.	[1]
Schedule of Derivative Instruments	The table below presents the volume of derivative commodity forward contracts and swaps outstanding at September 30, 2020 and 2019 (in thousands of units). September 30, Commodity Units 2020 2019 Electricity purchases MWh 113 109 Electricity sales MWh — 10 Natural gas purchases MMBtu 7,930 7,798 Natural gas sales MMBtu 775 —
[1]	Current asset derivative amounts offset include $0.8 million of collateral payable for the period ended September 30, 2020.

FAIR VALUE MEASUREMENTS_ Level

FAIR VALUE MEASUREMENTS: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2020
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The table below presents information about IDACORP’s and Idaho Power’s assets and liabilities measured at fair value on a recurring basis as of September 30, 2020, and December 31, 2019 (in thousands). September 30, 2020 December 31, 2019 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets: Money market funds IDACORP (1) $ 30,682 $ — $ — $ 30,682 $ 64,173 $ — $ — $ 64,173 Idaho Power 56,798 — — 56,798 26,510 — — 26,510 Derivatives 2,541 — — 2,541 392 13 — 405 Equity securities 42,401 — — 42,401 42,738 — — 42,738 Liabilities: Derivatives 146 24 — 170 814 32 — 846 (1) Holding company only. Does not include amounts held by Idaho Power.
Fair Value, by Balance Sheet Grouping [Table Text Block]	The table below presents the carrying value and estimated fair value of financial instruments that are not reported at fair value, as of September 30, 2020, and December 31, 2019, using available market information and appropriate valuation methodologies (in thousands). September 30, 2020 December 31, 2019 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value IDACORP Assets: Notes receivable (1) $ 3,804 $ 3,804 $ 3,804 $ 3,804 Liabilities: Long-term debt, including current portion (1) 2,000,358 2,440,622 1,836,659 2,083,931 Idaho Power Liabilities: Long-term debt, including current portion (1) 2,000,358 2,440,622 1,836,659 2,083,931 (1) Notes receivable and long-term debt are categorized as Level 3 and Level 2, respectively, of the fair value hierarchy, as defined earlier in this Note 12 - "Fair Value Measurements."

SEGMENT INFORMATION_ Level 3 (T

SEGMENT INFORMATION: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2020
Segment Information [Abstract]
Schedule of Segment Reporting Information, by Segment	The table below summarizes the segment information for IDACORP’s utility operations and the total of all other segments, and reconciles this information to total enterprise amounts (in thousands). Utility All Eliminations Consolidated Three months ended September 30, 2020: Revenues $ 424,170 1,091 $ — $ 425,261 Net income attributable to IDACORP, Inc. 100,389 1,642 — 102,031 Total assets as of September 30, 2020 6,769,567 247,753 (87,161) 6,930,159 Three months ended September 30, 2019: Revenues $ 385,028 $ 1,292 $ — $ 386,320 Net income attributable to IDACORP, Inc. 87,979 1,897 — 89,876 Nine months ended September 30, 2020: Revenues $ 1,032,324 $ 2,711 $ — $ 1,035,035 Net income attributable to IDACORP, Inc. 196,089 3,821 — 199,910 Nine months ended September 30, 2019: Revenues $ 1,050,574 $ 2,961 $ — $ 1,053,535 Net income attributable to IDACORP, Inc. 180,740 4,978 — 185,718

CHANGES IN IDAHO POWER RETAIN_2

CHANGES IN IDAHO POWER RETAINED EARNINGS (Tables)	9 Months Ended
	Sep. 30, 2020
Changes in Idaho Power Retained Earnings [Abstract]
Changes in Idaho Power Retained Earnings Table	Three months ended Nine months ended 2020 2019 2020 2019 Balance at beginning of period $ 1,531,566 $ 1,438,019 $ 1,503,805 $ 1,409,245 Net income 100,389 87,979 196,089 180,740 Dividends to parent (33,959) (31,932) (101,898) (95,919) Balance at end of period $ 1,597,996 $ 1,494,066 $ 1,597,996 $ 1,494,066

SUMMARY OF SIGNIFICANT ACCOUN_4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES: Accounting Adoption Pronouncement (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019	Dec. 31, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Accounts Receivable, Allowance for Credit Loss	$ 3,924	$ 1,413	$ 1,401	$ 1,725
Accounts Receivable, Credit Loss Expense (Reversal)	3,543	1,663
Accounts Receivable, Allowance for Credit Loss, Writeoff	$ (1,020)	$ (1,975)
Allowance for uncollectible accounts as a percentage of customer receivables	3.70%	1.40%	1.90%

INCOME TAXES_ Level 4 (Details)

INCOME TAXES: Level 4 (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Income Tax Expense [Line Items]
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount				$ 57,420	$ 54,626
First mortgage bond redemption costs				(890)	0
Excess deferred income tax reversal				(3,222)	(4,123)
Income tax return adjustments				(2,555)	1,071
Other	[1]			(27,587)	(25,068)
Income Tax Expense		$ 12,345	$ 15,161	$ 23,166	$ 26,506
Effective tax rate				10.40%	12.50%
Idaho Power Company
Income Tax Expense [Line Items]
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount				$ 56,718	$ 53,496
First mortgage bond redemption costs				(890)	0
Excess deferred income tax reversal				(3,222)	(4,123)
Income tax return adjustments				(2,507)	993
Other	[1]			(25,839)	(23,275)
Income Tax Expense		$ 12,682	$ 15,054	$ 24,260	$ 27,091
Effective tax rate				11.00%	13.00%
[1]	"Other" is primarily comprised of the net tax effect of Idaho Power's regulatory flow-through tax adjustments.

REGULATORY MATTERS_ Level 4 (De

REGULATORY MATTERS: Level 4 (Details) - USD ($) $ in Thousands	9 Months Ended		12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	May 31, 2021	May 31, 2020	Jun. 01, 2020	Jun. 01, 2019	Dec. 31, 2018	Jun. 01, 2018	Apr. 30, 2018	Oct. 31, 2014
Regulatory Matters
Additional accumulated deferred investment tax credits (ADITC) amortization	$ 890	$ 0
Idaho Power Company
Regulatory Matters
Additional accumulated deferred investment tax credits (ADITC) amortization	890	0
Power cost adjustment mechanism | IDAHO
Regulatory Matters
Amount of approved rate change				$ (50,100)
Idaho fixed cost adjustment mechanism
Regulatory Matters
Percentage cap on the FCA adjustment					3.00%
Idaho fixed cost adjustment mechanism | IDAHO
Regulatory Matters
Amount of approved rate change				19,200
Annual fixed cost adjustment mechanism deferral					$ 35,500	$ 34,800		$ 15,600
October 2014 Idaho Settlement Stipulation | IDAHO
Regulatory Matters
Minimum authorized return on equity										9.50%
Investment Tax Credits, Maximum, in Rate Case										$ 45,000
May 2018 Tax Reform Settlement Stipulation | IDAHO
Regulatory Matters
Minimum authorized return on equity									9.40%
Target authorized return on equity									10.00%
Settlement Stipulation - Investment Tax Credits and Idaho Sharing Mechanism [Member]
Regulatory Matters
Additional accumulated deferred investment tax credits (ADITC) amortization	0	$ 0
Non-recurring [Member] | IDAHO
Regulatory Matters
Amount of approved rate change				7,700
Non-recurring [Member] | May 2018 Tax Reform Settlement Stipulation | IDAHO
Regulatory Matters
Amount of approved rate change				$ 2,700
Forecast [Member] | Power cost adjustment mechanism | IDAHO
Regulatory Matters
Amount of approved rate change			$ 58,700
Forecast [Member] | Idaho fixed cost adjustment mechanism | IDAHO
Regulatory Matters
Amount of approved rate change			$ 700
COVID-19 Deferral [Member] | IDAHO
Regulatory Matters
Regulatory Assets	$ 700
Settlement agreement sharing [Member] | IDAHO
Regulatory Matters
Regulatory liabilities							$ 5,000

Long-Term Debt (Details)

Long-Term Debt (Details) - Idaho Power [Member] - USD ($) $ in Millions	Jul. 29, 2020	Oct. 23, 2020	Aug. 03, 2020	Jun. 22, 2020	Jun. 05, 2020	Apr. 03, 2020
First Mortgage Bonds 4.20 K Series due 2048 [Domain]
Debt Instrument [Line Items]
Secured Long-term Debt, Noncurrent						$ 230
Debt Instrument, Interest Rate, Stated Percentage						4.20%
debt Instrument, Net Premium						13.00%
debt Instrument, net proceeds						$ 259.9
Principal amount of debt securities in Selling Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount					$ 500
Supplemental Indenture [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount					$ 500
First Mortgage Bonds 1.90 L Series due 2030 [Domain]
Debt Instrument [Line Items]
Secured Long-term Debt, Noncurrent				$ 80
Debt Instrument, Interest Rate, Stated Percentage				1.90%
First Mortgage Bonds 2.95 Series due 2022 [Domain]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.95%
Premium on Repayment on Debt	$ 3.3
Repayments of Debt	$ 75
First mortgage bonds 4.50 Series due 2020 [Member]
Debt Instrument [Line Items]
Secured Long-term Debt, Noncurrent			$ 100
Debt Instrument, Interest Rate, Stated Percentage			3.40%
Subsequent Event
Debt Instrument [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount		$ 420
debt instrument, unused borrowing capacity, Regulatory Authority Amount		$ 190

REVENUES_ Electric utility op_2

REVENUES: Electric utility operating revenues (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Revenue from contracts with customers	$ 402,941	$ 367,101	$ 984,096	$ 1,010,281
Alternative revenue programs and other revenues	21,229	17,927	48,228	40,293
Electric utility revenues	$ 424,170	$ 385,028	$ 1,032,324	$ 1,050,574

REVENUES_ (Details)

REVENUES: (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		$ 402,941	$ 367,101	$ 984,096	$ 1,010,281
Alternative revenue programs and other revenues		21,229	17,927	48,228	40,293
Retail revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		361,628	340,820	896,037	876,922
Derivative revenues
Disaggregation of Revenue [Line Items]
Alternative revenue programs and other revenues		16,003	11,151	22,277	14,283
Idaho fixed cost adjustment mechanism
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	[1]	(5,226)	(6,776)	(25,951)	(26,010)
Alternative revenue programs and other revenues		5,226	6,776	25,951	26,010
Wholesale energy sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		12,178	5,321	22,952	68,693
Transmission Service Agreement
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		16,896	12,498	38,750	40,743
Energy efficiency program revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		10,530	8,439	31,957	30,008
Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		6,935	6,799	20,351	19,925
Residential Retail Revenue | Retail revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	[1]	143,822	133,550	398,180	388,566
Residential Retail Revenue | Idaho fixed cost adjustment mechanism
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		4,896	6,446	24,740	24,988
Commercial Retail Revenue | Retail revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	[1]	82,279	80,304	219,006	224,382
Commercial Retail Revenue | Idaho fixed cost adjustment mechanism
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		330	330	1,211	1,022
Industrial Retail Revenue | Retail revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		50,154	47,122	136,001	138,222
Irrigation Retail Revenue | Retail revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		88,188	82,659	149,711	132,613
Deferred revenue-AFUDC | Retail revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	[2]	(2,815)	$ (2,815)	(6,861)	$ (6,861)
IPUC authorized AFUDC Collection HCC Relicensing - Gross | Idaho Power Company | Hells Canyon Complex
Disaggregation of Revenue [Line Items]
Regulatory liabilities		$ (8,800)		$ (8,800)
[1]	The FCA mechanism is an alternative revenue program in the Idaho jurisdiction and does not represent revenue from contracts with customers.
[2]	As part of its January 30, 2009, general rate case order, the IPUC is allowing Idaho Power to recover a portion of the allowance for funds used during construction (AFUDC) on construction work in progress related to the Hells Canyon Complex (HCC) relicensing process, even though the relicensing process is not yet complete and the costs have not been moved to electric plant in service. Idaho Power is collecting $8.8 million annually in the Idaho jurisdiction but is deferring revenue recognition of the amounts collected until the license is issued and the accumulated license costs approved for recovery are placed in service.

COMMON STOCK_ Level 4 (Details)

COMMON STOCK: Level 4 (Details) $ in Billions	9 Months Ended
	Sep. 30, 2020USD ($)shares
Shareholders' equity
Restricted Stock Unit Awards to Employees	75,030
Restricted stock awards to directors	8,480
IDACORP
Shareholders' equity
Stock Issued During Period, Shares, New Issues	41,410
Maximum leverage ratio requirement	0.65
Ratio of Indebtedness to Net Capital	0.44
Dividend Distribution Restriction Amount | $	$ 1.5
Idaho Power Company
Shareholders' equity
Maximum leverage ratio requirement	0.65
Ratio of Indebtedness to Net Capital	0.46
Dividend Distribution Restriction Amount | $	$ 1.3
Dividend Distribution Restriction Threshold	0.35
Ratio of total Capital to total capital and long-term debt	0.54
Preferred Stock, Shares Outstanding	0

EARNINGS PER SHARE_ Level 4 (De

EARNINGS PER SHARE: Level 4 (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Numerator:
Net Income Attributable to IDACORP, Inc.	$ 102,031	$ 89,876	$ 199,910	$ 185,718
Denominator:
Weighted-average common shares outstanding - basic	50,541	50,499	50,534	50,502
Effect of dilutive securities	35	59	20	26
Weighted-average common shares outstanding - diluted	50,576	50,558	50,554	50,528
Earnings attributable to IDACORP, Inc. - basic (in dollars per share)	$ 2.02	$ 1.78	$ 3.96	$ 3.68
Earnings attributable to IDACORP, Inc. - diluted (in dollars per share)	$ 2.02	$ 1.78	$ 3.95	$ 3.68

COMMITMENTS_ Level 4 (Details)

COMMITMENTS: Level 4 (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2020USD ($)	Sep. 30, 2020USD ($)
Idaho Power Company
Guarantor Obligations
IERCo ownership interest in BCC	33.00%	33.00%
IERCo guarantee of BCC reclamation obligation	$ 58.3	$ 58.3
Long-term Commitment (Excluding Unconditional Purchase Obligation) [Abstract]
Life of Contract		20 years
Increase of Long-term Purchase Obligations, PURPA	28	$ 28
Bridger Coal Company
Guarantor Obligations
IERCo guarantee of BCC reclamation obligation	175	175
Guarantor Obligations Total Reclamation Trust Fund	$ 157.5	157.5
Distribution from Reclamation Trust Fund		$ 3.3

BENEFIT PLANS_ Level 4 (Details

BENEFIT PLANS: Level 4 (Details) - USD ($) $ in Thousands	3 Months Ended				9 Months Ended
	Sep. 30, 2020		Sep. 30, 2019		Sep. 30, 2020		Sep. 30, 2019
Pension Plan
Defined Benefit Plan Disclosure
Service cost	$ 10,747		$ 8,516		$ 32,240		$ 25,546
Interest cost	10,004		10,578		30,010		31,734
Expected return on plan assets	(14,060)		(12,156)		(42,179)		(36,467)
Amortization of prior service cost	1		1		4		4
Amortization of net loss	4,331		3,391		12,994		10,173
Net periodic benefit cost	11,023		10,330		33,069		30,990
Regulatory deferral of net periodic benefit cost	(10,511)	[1]	(9,845)	[1]	(31,532)	[2]	(29,534)	[2]
IPUC Authorized recovered pension cost	4,288	[1]	4,288	[1]	12,865	[2]	12,865	[2]
Net periodic benefit cost recognized for financial reporting	4,800	[1],[3]	4,773	[1],[3]	14,402	[2],[4]	14,321	[2],[4]
Defined Benefit Plan, Contributions by Employer					40,000
Senior Management Security Plan
Defined Benefit Plan Disclosure
Service cost	54		(46)		160		(136)
Interest cost	1,087		1,143		3,262		3,432
Expected return on plan assets	0		0		0		0
Amortization of prior service cost	73		24		218		72
Amortization of net loss	933		634		2,800		1,900
Net periodic benefit cost	2,147		1,755		6,440		5,268
Net periodic benefit cost recognized for financial reporting	2,147	[3]	1,755	[3]	6,440	[4]	5,268	[4]
Postretirement Benefits Plan
Defined Benefit Plan Disclosure
Service cost	258		213		772		640
Interest cost	623		748		1,870		2,242
Expected return on plan assets	(601)		(555)		(1,803)		(1,665)
Amortization of prior service cost	11		11		35		35
Amortization of net loss	0		0		0		0
Net periodic benefit cost	291		417		874		1,252
Net periodic benefit cost recognized for financial reporting	291		417		874		1,252
Retirement Plan Total
Defined Benefit Plan Disclosure
Service cost	11,059		8,683		33,172		26,050
Interest cost	11,714		12,469		35,142		37,408
Expected return on plan assets	(14,661)		(12,711)		(43,982)		(38,132)
Amortization of prior service cost	85		36		257		111
Amortization of net loss	5,264		4,025		15,794		12,073
Net periodic benefit cost	13,461		12,502		40,383		37,510
Regulatory deferral of net periodic benefit cost	(10,511)	[1]	(9,845)	[1]	(31,532)	[2]	(29,534)	[2]
IPUC Authorized recovered pension cost	4,288	[1]	4,288	[1]	12,865	[2]	12,865	[2]
Net periodic benefit cost recognized for financial reporting	7,238	[1],[3]	6,945	[1],[3]	21,716	[2],[4]	20,841	[2],[4]
Net Periodic Benefit cost recognize in Other operations and maintenance	4,300		4,200		12,800		12,600
Net Periodic Benefit cost recognized in other expense, net	$ 3,000		$ 2,700		$ 8,900		$ 8,200
[1]	Net periodic benefit costs for the pension plan are recognized for financial reporting based upon the authorization of each regulatory jurisdiction in which Idaho Power operates. Under IPUC order, the Idaho portion of net periodic benefit cost is recorded as a regulatory asset and is recognized in the income statement as those costs are recovered through rates.
[2]	Net periodic benefit costs for the pension plan are recognized for financial reporting based upon the authorization of each regulatory jurisdiction in which Idaho Power operates. Under IPUC order, the Idaho portion of net periodic benefit cost is recorded as a regulatory asset and is recognized in the income statement as those costs are recovered through rates.
[3]	Of total net periodic benefit cost recognized for financial reporting, $4.3 million and $4.2 million, respectively, were recognized in "Other operations and maintenance" and $3.0 million and $2.7 million, respectively, were recognized in "Other expense, net" on the condensed consolidated statements of income of the companies for the three months ended September 30, 2020 and 2019.
[4]	Of total net periodic benefit cost recognized for financial reporting, $12.8 million and $12.6 million, respectively, were recognized in "Other operations and maintenance" and $8.9 million and $8.2 million, respectively, were recognized in "Other expense, net" on the condensed consolidated statements of income of the companies for the nine months ended September 30, 2020 and 2019.

Derivative Instruments Fair Val

Derivative Instruments Fair Value and Offsets Table (Details) - USD ($) $ in Thousands	Sep. 30, 2020		Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 3,387		$ 2,576
Derivative Asset, Fair Value, Gross Liability	(846)		(2,171)
Derivative Asset, Fair Value, Amount Offset Against Collateral	2,541		405
Derivative Liability, Fair Value, Gross Liability	264		3,017
Derivative Liability, Fair Value, Gross Asset	(94)		(2,171)
Derivative Liability, Fair Value, Amount Offset Against Collateral	170		846
Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative, Collateral, Obligation to Return Cash	800
Financial Swaps | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	3,270		2,426
Derivative Asset, Fair Value, Gross Liability	(817)	[1]	(2,034)
Derivative Asset, Fair Value, Amount Offset Against Collateral	2,453		392
Derivative Liability, Fair Value, Gross Liability	65		2,034
Derivative Liability, Fair Value, Gross Asset	(65)		(2,034)
Derivative Liability, Fair Value, Amount Offset Against Collateral	0		0
Financial Swaps | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	6		134
Derivative Asset, Fair Value, Gross Liability	(6)		(134)
Derivative Asset, Fair Value, Amount Offset Against Collateral	0		0
Derivative Liability, Fair Value, Gross Liability	152		924
Derivative Liability, Fair Value, Gross Asset	(6)		(134)
Derivative Liability, Fair Value, Amount Offset Against Collateral	146		790
Financial Swaps | Other Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	111
Derivative Asset, Fair Value, Gross Liability	(23)
Derivative Asset, Fair Value, Amount Offset Against Collateral	88
Derivative Liability, Fair Value, Gross Liability	23
Derivative Liability, Fair Value, Gross Asset	(23)
Derivative Liability, Fair Value, Amount Offset Against Collateral	0
Financial Swaps | Other Liabilities
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset			3
Derivative Asset, Fair Value, Gross Liability			(3)
Derivative Asset, Fair Value, Amount Offset Against Collateral			0
Derivative Liability, Fair Value, Gross Liability			27
Derivative Liability, Fair Value, Gross Asset			(3)
Derivative Liability, Fair Value, Amount Offset Against Collateral			24
Forward contracts | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset			13
Derivative Asset, Fair Value, Gross Liability			0
Derivative Asset, Fair Value, Amount Offset Against Collateral			13
Derivative Liability, Fair Value, Gross Liability			0
Derivative Liability, Fair Value, Gross Asset			0
Derivative Liability, Fair Value, Amount Offset Against Collateral			0
Forward contracts | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Derivative Asset, Fair Value, Gross Liability	0		0
Derivative Asset, Fair Value, Amount Offset Against Collateral	0		0
Derivative Liability, Fair Value, Gross Liability	24		32
Derivative Liability, Fair Value, Gross Asset	0		0
Derivative Liability, Fair Value, Amount Offset Against Collateral	$ 24		$ 32
[1]	Current asset derivative amounts offset include $0.8 million of collateral payable for the period ended September 30, 2020.

Derivative Instruments Gains (L

Derivative Instruments Gains (Loss) on Derivatives Recognized in Income (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Financial Swaps | Operating revenues
Derivative Instruments, Gain (Loss)
Derivative, Gain on Derivative	[1]	$ 1,039	$ 3,693	$ 2,173	$ 904
Financial Swaps | Purchased power
Derivative Instruments, Gain (Loss)
Derivative, Loss on Derivative	[1]	(2,264)	(2,981)	(3,579)	(2,294)
Financial Swaps | Operating Expense
Derivative Instruments, Gain (Loss)
Derivative, Loss on Derivative	[1]	(1,115)	(815)	(4,032)
Derivative, Gain on Derivative	[1]				11,587
Forward contracts | Operating revenues
Derivative Instruments, Gain (Loss)
Derivative, Gain on Derivative	[1]	229	106	349	170
Forward contracts | Purchased power
Derivative Instruments, Gain (Loss)
Derivative, Loss on Derivative	[1]	(198)	(106)	(313)	(170)
Forward contracts | Operating Expense
Derivative Instruments, Gain (Loss)
Derivative, Loss on Derivative	[1]	$ (6)		$ (25)
Derivative, Gain on Derivative	[1]		$ 191		$ 607
[1]	Excludes unrealized gains or losses on derivatives, which are recorded on the balance sheet as regulatory assets or regulatory liabilities.

Derivative Commodities and Disc

Derivative Commodities and Disclosures (Details) MWh in Thousands, MMBTU in Thousands, $ in Millions	Sep. 30, 2020USD ($)MWhMMBTU	Sep. 30, 2019MWhMMBTU
Derivative
Derivatives in a net liability position	$ 0.3
Collateral Already Posted, Aggregate Fair Value	0
Additional Collateral, Aggregate Fair Value	$ 4.6
Electricity (MWh) | Long
Derivative
Derivative, Number of Instruments Held | MWh	113	109
Electricity (MWh) | Short
Derivative
Derivative, Number of Instruments Held | MWh	0	10
Natural Gas (MMBTU) | Long
Derivative
Derivative, Number of Instruments Held | MMBTU	7,930	7,798
Natural Gas (MMBTU) | Short
Derivative
Derivative, Number of Instruments Held | MMBTU	775	0

FAIR VALUE MEASUREMENTS_ Leve_2

FAIR VALUE MEASUREMENTS: Level 4 (Details) - USD ($)		Sep. 30, 2020	Dec. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	[1]	$ 30,682,000	$ 64,173,000
Derivative Assets		2,541,000	405,000
Equity Securities, FV-NI		42,401,000	42,738,000
Derivative Liabilities		170,000	846,000
Fair Value, Assets, Level 1 to Level 2 Transfers, Amount		0	0
Idaho Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds		56,798,000	26,510,000
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	[1]	30,682,000	64,173,000
Derivative Assets		2,541,000	392,000
Equity Securities, FV-NI		42,401,000	42,738,000
Derivative Liabilities		146,000	814,000
Fair Value, Inputs, Level 1 [Member] | Idaho Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds		56,798,000	26,510,000
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	[1]	0	0
Derivative Assets		0	13,000
Equity Securities, FV-NI		0	0
Derivative Liabilities		24,000	32,000
Fair Value, Inputs, Level 2 [Member] | Idaho Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds		0	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	[1]	0	0
Derivative Assets		0	0
Equity Securities, FV-NI		0	0
Derivative Liabilities		0	0
Fair Value, Inputs, Level 3 [Member] | Idaho Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds		$ 0	$ 0
[1]	Holding company only. Does not include amounts held by Idaho Power.

FAIR VALUE MEASUREMENTS_ Fair V

FAIR VALUE MEASUREMENTS: Fair Value, by Balance Sheet Grouping (Details) - USD ($) $ in Thousands		Sep. 30, 2020	Dec. 31, 2019
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Receivable	[1]	$ 3,804	$ 3,804
Long-term debt	[1]	2,000,358	1,836,659
Carrying Amount | Idaho Power Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	[1]	2,000,358	1,836,659
Estimated Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Receivable	[1]	3,804	3,804
Long-term debt	[1]	2,440,622	2,083,931
Estimated Fair Value | Idaho Power Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	[1]	$ 2,440,622	$ 2,083,931
[1]	Notes receivable and long-term debt are categorized as Level 3 and Level 2, respectively, of the fair value hierarchy, as defined earlier in this Note 12 - "Fair Value Measurements."

SEGMENT INFORMATION_ Level 4 (D

SEGMENT INFORMATION: Level 4 (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Segment Reporting Information
Electric utility revenues	$ 424,170	$ 385,028	$ 1,032,324	$ 1,050,574
Total operating revenues	425,261	386,320	1,035,035	1,053,535
Net Income Attributable to IDACORP, Inc.	102,302	90,218	200,419	186,255
Net Income Attributable to IDACORP, Inc.	102,031	89,876	199,910	185,718
Total assets	6,930,159		6,930,159		$ 6,641,201
All Other
Segment Reporting Information
Total operating revenues	1,091	1,292	2,711	2,961
Net Income Attributable to IDACORP, Inc.	1,642	1,897	3,821	4,978
Total assets	247,753		247,753
Eliminations
Segment Reporting Information
Total operating revenues	0	0	0	0
Net Income Attributable to IDACORP, Inc.	0	0	0	0
Total assets	(87,161)		(87,161)
Idaho Power Company
Segment Reporting Information
Electric utility revenues	424,170	385,028	1,032,324	1,050,574
Net Income Attributable to IDACORP, Inc.	100,389	$ 87,979	196,089	$ 180,740
Total assets	$ 6,769,567		$ 6,769,567		$ 6,494,159
IERCo's ownership percentage in Bridger Coal Company	33.00%		33.00%

CHANGES IN IDAHO POWER RETAIN_3

CHANGES IN IDAHO POWER RETAINED EARNINGS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Changes in Retained Earnings [Line Items]
Balance at beginning of period	$ 1,664,468	$ 1,563,399	$ 1,634,525	$ 1,531,543
Net Income	102,302	90,218	200,419	186,255
Dividends to parent			(101,999)	(95,871)
Common stock dividends	(33,960)	(31,933)	(101,896)	(95,919)
Balance at end of period	1,732,539	1,621,342	1,732,539	1,621,342
Idaho Power Company
Changes in Retained Earnings [Line Items]
Balance at beginning of period	1,531,566	1,438,019	1,503,805	1,409,245
Net Income	100,389	87,979	196,089	180,740
Dividends to parent	(33,959)	(31,932)	(101,898)	(95,919)
Balance at end of period	$ 1,597,996	$ 1,494,066	$ 1,597,996	$ 1,494,066