IDACORP (IDA) 10-Q30 Oct 142014 Q3 Quarterly reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information (DEI) Document (USD $)	3 Months Ended		9 Months Ended			9 Months Ended	0 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Sep. 30, 2014	Jan. 01, 2012
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Idaho Power Company	Settlement Stipulation - Investment Tax Credits and Idaho Sharing Mechanism
Document Information	'	'	'	'	'	'	'
Fair Value, Assets, Level 1 to Level 2 Transfers, Amount	$0	'	$0	'	$0	'	'
Maximum leverage ratio requirement	'	'	'	'	'	0.65	'
Period of Current ADITC Stipulation	'	'	'	'	'	'	'3 years
Amount outstanding on credit facility	'	'	'	'	'	$0	'
Dividends Declared Per Share of Common Stock	$0.43	$0.38	$1.29	$1.14	'	'	'
Document Type	'	'	'10-Q	'	'	'	'
Amendment Flag	'	'	'false	'	'	'	'
Document Period End Date	'	'	30-Sep-14	'	'	'	'
Document Fiscal Year Focus	'	'	'2014	'	'	'	'
Document Fiscal Period Focus	'	'	'Q3	'	'	'	'
Trading Symbol	'	'	'IDA	'	'	'	'
Entity Registrant Name	'	'	'IDACORP INC.	'	'	'Idaho Power Company	'
Entity Central Index Key	'	'	'0001057877	'	'	'0000049648	'
Current Fiscal Year End Date	'	'	'--12-31	'	'	'	'
Entity Filer Category	'	'	'Large Accelerated Filer	'	'	'Non-accelerated Filer	'
Entity Common Stock, Shares Outstanding	50,268,748	'	50,268,748	'	'	39,150,812	'
Entity Tax Identification Number	'	'	'820505802	'	'	'820130980	'

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Income Statement (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Operating Revenues:	'	'	'	'
General business	$347,838	$349,428	$874,817	$846,079
Off-system sales	15,449	11,169	56,390	31,597
Other revenues	17,424	19,707	58,479	69,853
Total electric utility revenues	380,711	380,304	989,686	947,529
Other	1,490	803	3,017	2,455
Total operating revenues	382,201	381,107	992,703	949,984
Operating Expenses:	'	'	'	'
Purchased power	75,058	74,088	181,291	166,097
Fuel expense	67,088	64,858	156,859	155,901
Power cost adjustment expense (deferral)	-668	-6,960	23,496	-34,969
Other operations and maintenance	84,236	84,471	252,208	247,409
Energy efficiency programs	5,537	6,077	17,881	30,279
Depreciation	33,476	32,538	99,304	96,680
Taxes other than income taxes	8,340	7,017	24,685	23,243
Total electric utility expenses	273,067	262,089	755,724	684,640
Other	3,412	3,459	10,869	10,945
Total operating expenses	276,479	265,548	766,593	695,585
Operating Income	105,722	115,559	226,110	254,399
Other Income (Expense):	'	'	'	'
Allowance for equity funds used during construction	4,645	3,734	13,182	10,876
Earnings of unconsolidated equity-method investments	6,414	6,261	8,908	9,402
Other (expense) income, net	1,193	1,567	4,733	3,982
Interest Expense:	'	'	'	'
Interest on long-term debt	20,141	20,887	60,423	61,349
Other interest	1,908	1,812	5,714	5,296
Allowance for borrowed funds used during construction	-2,178	-1,904	-6,287	-5,711
Total interest expense, net	19,871	20,795	59,850	60,934
Income Before Income Taxes	98,103	106,326	193,083	217,725
Income Tax Expense	10,869	33,222	33,968	62,941
Net Income	87,234	73,104	159,115	154,784
Adjustment for (income) loss attributable to noncontrolling interests	-345	15	-283	31
Net Income Attributable to IDACORP, Inc.	86,889	73,119	158,832	154,815
Weighted Average Common Shares Outstanding - Basic (000bs)	50,129	50,056	50,131	50,051
Weighted Average Common Shares Outstanding - Diluted (000bs)	50,220	50,153	50,184	50,109
Earnings Per Share of Common Stock:	'	'	'	'
Earnings Attributable to IDACORP, Inc. - Basic (in dollars per share)	$1.73	$1.46	$3.17	$3.09
Earnings Attributable to IDACORP, Inc. - Diluted (in dollars per share)	$1.73	$1.46	$3.16	$3.09
Dividends Declared Per Share of Common Stock	$0.43	$0.38	$1.29	$1.14
Idaho Power Company	'	'	'	'
Operating Revenues:	'	'	'	'
General business	347,838	349,428	874,817	846,079
Off-system sales	15,449	11,169	56,390	31,597
Other revenues	17,424	19,707	58,479	69,853
Total electric utility revenues	380,711	380,304	989,686	947,529
Operating Expenses:	'	'	'	'
Purchased power	75,058	74,088	181,291	166,097
Fuel expense	67,088	64,858	156,859	155,901
Power cost adjustment expense (deferral)	-668	-6,960	23,496	-34,969
Other operations and maintenance	84,236	84,471	252,208	247,409
Energy efficiency programs	5,537	6,077	17,881	30,279
Depreciation	33,476	32,538	99,304	96,680
Taxes other than income taxes	8,340	7,017	24,685	23,243
Total electric utility expenses	273,067	262,089	755,724	684,640
Operating Income	107,644	118,215	233,962	262,889
Other Income (Expense):	'	'	'	'
Allowance for equity funds used during construction	4,645	3,734	13,182	10,876
Earnings of unconsolidated equity-method investments	5,180	5,102	7,148	7,358
Other (expense) income, net	-1,538	-1,077	-3,556	-4,450
Total other income	8,287	7,759	16,774	13,784
Interest Expense:	'	'	'	'
Interest on long-term debt	20,141	20,887	60,423	61,349
Other interest	1,859	1,724	5,547	5,009
Allowance for borrowed funds used during construction	-2,178	-1,904	-6,287	-5,711
Total interest expense, net	19,822	20,707	59,683	60,647
Income Before Income Taxes	96,109	105,267	191,053	216,026
Income Tax Expense	11,509	34,965	35,899	66,695
Net Income	$84,600	$70,302	$155,154	$149,331

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Comprehensive Income (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Net Income	$87,234	$73,104	$159,115	$154,784
Other Comprehensive Income:	'	'	'	'
Net unrealized holding gains arising during the period, net of tax	0	843	0	2,283
Unfunded pension liability adjustment (net of tax)	432	464	1,296	1,394
Total Comprehensive Income	87,666	74,411	160,411	158,461
Comprehensive (income) loss attributable to noncontrolling interests	-345	15	-283	31
Comprehensive Income Attributable to IDACORP, Inc.	87,321	74,426	160,128	158,492
Idaho Power Company	'	'	'	'
Net Income	84,600	70,302	155,154	149,331
Other Comprehensive Income:	'	'	'	'
Net unrealized holding gains arising during the period, net of tax	0	843	0	2,283
Unfunded pension liability adjustment (net of tax)	432	464	1,296	1,394
Total Comprehensive Income	$85,032	$71,609	$156,450	$153,008

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Comprehensive Income (Parenthetical) (Parentheticals) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, Tax	$0	$541	$0	$1,466
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Tax	277	298	832	894
Idaho Power Company	'	'	'	'
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, Tax	0	541	0	1,466
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Tax	$277	$298	$832	$894

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets Statement (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Current Assets:	'	'
Cash and cash equivalents	$111,038	$78,162
Receivables:	'	'
Customer	93,272	97,873
Other	16,808	15,274
Taxes receivable	0	156
Accrued unbilled revenues	55,273	63,507
Materials and supplies (at average cost)	56,023	53,643
Fuel stock (at average cost)	44,733	41,546
Prepayments	12,954	15,338
Deferred income taxes	32,638	46,874
Current regulatory assets	50,995	61,837
Other	1,472	2,401
Total current assets	475,206	476,611
Investments	155,028	159,072
Property, Plant and Equipment:	'	'
Utility plant in service	5,194,535	5,080,402
Accumulated provision for depreciation	-1,823,870	-1,766,680
Utility plant in service - net	3,370,665	3,313,722
Construction work in progress	383,667	327,000
Utility plant held for future use	7,090	7,090
Other property, net of accumulated depreciation	17,332	17,229
Property, plant and equipment - net	3,778,754	3,665,041
Other Assets:	'	'
American Falls and Milner water rights	13,958	15,803
Company-owned life insurance	23,774	22,037
Regulatory assets	1,003,099	978,234
Long-term receivables	6,041	4,811
Other	42,417	42,954
Total other assets	1,089,289	1,063,839
Total	5,498,277	5,364,563
Current Liabilities:	'	'
Current maturities of long-term debt	1,064	1,064
Notes payable	31,800	54,750
Accounts payable	82,901	91,519
Taxes accrued	26,232	13,302
Interest accrued	24,885	22,764
Accrued compensation	40,101	38,510
Current regulatory liabilities	7,588	10,684
Other	25,132	17,779
Total current liabilities	239,703	250,372
Other Liabilities:	'	'
Deferred income taxes	1,030,076	969,593
Regulatory liabilities	385,055	375,873
Pension and other postretirement benefits	230,385	244,627
Other	45,292	54,100
Total other liabilities	1,690,808	1,644,193
Long-Term Debt	1,614,377	1,615,258
Commitments and Contingencies	'	'
Equity:	'	'
Common stock	843,163	839,750
Retained earnings	1,121,390	1,027,461
Accumulated other comprehensive loss	-15,257	-16,553
Treasury stock	-280	-8
Total IDACORP, Inc. shareholdersb equity	1,949,016	1,850,650
Noncontrolling interests	4,373	4,090
Total equity	1,953,389	1,854,740
Total	5,498,277	5,364,563
Idaho Power Company	'	'
Current Assets:	'	'
Cash and cash equivalents	102,900	66,535
Receivables:	'	'
Customer	93,272	97,873
Other	16,674	14,290
Accrued unbilled revenues	55,273	63,507
Materials and supplies (at average cost)	56,023	53,643
Fuel stock (at average cost)	44,733	41,546
Prepayments	12,840	15,204
Deferred income taxes	0	12,386
Current regulatory assets	50,995	61,837
Other	1,473	2,401
Total current assets	434,183	429,222
Investments	130,437	131,520
Property, Plant and Equipment:	'	'
Utility plant in service	5,194,535	5,080,402
Accumulated provision for depreciation	-1,823,870	-1,766,680
Utility plant in service - net	3,370,665	3,313,722
Construction work in progress	383,667	327,000
Utility plant held for future use	7,090	7,090
Property, plant and equipment - net	3,761,422	3,647,812
Other Assets:	'	'
American Falls and Milner water rights	13,958	15,803
Company-owned life insurance	23,774	22,037
Regulatory assets	1,003,099	978,234
Other	42,590	41,783
Total other assets	1,083,421	1,057,857
Total	5,409,463	5,266,411
Current Liabilities:	'	'
Current maturities of long-term debt	1,064	1,064
Accounts payable	82,170	90,529
Accounts payable to affiliates	1,791	1,158
Taxes accrued	25,006	14,031
Interest accrued	24,885	22,764
Accrued compensation	39,926	38,297
Current regulatory liabilities	7,588	10,684
Other	25,275	17,095
Total current liabilities	207,705	195,622
Other Liabilities:	'	'
Deferred income taxes	1,112,463	1,058,734
Regulatory liabilities	385,055	375,873
Pension and other postretirement benefits	230,385	244,627
Other	43,953	52,265
Total other liabilities	1,771,856	1,731,499
Long-Term Debt	1,614,377	1,615,258
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	1,022,744	932,547
Accumulated other comprehensive loss	-15,257	-16,553
Total equity	1,815,525	1,724,032
Total capitalization	3,429,902	3,339,290
Total	$5,409,463	$5,266,411

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (Parentheticals) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Allowance for Doubtful Accounts Receivable, Current	$2,229	$2,349
Allowance for Doubtful Other Receivables, Current	158	153
Allowance for Doubtful Accounts Receivable, Noncurrent	885	885
Common Stock, No Par Value	'	'
Common Stock, Shares Authorized	120,000,000	120,000,000
Common Stock, Shares, Issued	50,307,512	50,233,463
Treasury Stock, Shares	38,764	718
Idaho Power Company	'	'
Allowance for Doubtful Accounts Receivable, Current	2,229	2,349
Allowance for Doubtful Other Receivables, Current	$158	$153
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	39,150,812

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements of Cash Flows (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Operating Activities:	'	'
Net Income	$159,115	$154,784
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	102,366	99,534
Deferred income taxes and investment tax credits	25,355	46,891
Changes in regulatory assets and liabilities	36,595	-20,765
Pension and Postretirement Benefit Plan Expense	20,927	22,026
Contributions to pension and postretirement benefit plans	-32,533	-32,573
Earnings of unconsolidated equity-method investments	-8,908	-9,402
Distributions from unconsolidated equity-method investments	5,820	14,218
Allowance for equity funds used during construction	-13,182	-10,876
Other non-cash adjustments to net income, net	4,417	2,308
Change in:	'	'
Accounts Receivable	4,372	-38,553
Accounts payable and other accrued liabilities	-3,359	-4,505
Taxes accrued/receivable	14,066	24,621
Other current assets	2,089	4,749
Other current liabilities	7,258	5,253
Other assets	-2,970	-1,253
Other liabilities	-5,601	-8,811
Net cash provided by operating activities	315,827	247,646
Investing Activities:	'	'
Additions to property, plant and equipment	-200,928	-165,550
Proceeds from the sale of emission allowances and RECs	2,923	498
Distributions from affordable housing investments	1,048	1,697
Other	4,335	3,366
Net cash used in investing activities	-192,622	-159,989
Financing Activities:	'	'
Issuance of long-term debt	0	150,000
Retirement of long-term debt	-1,064	-1,064
Dividends on common stock	-64,958	-57,323
Net change in short-term borrowings	-22,950	-16,700
Issuance of common stock	160	255
Acquisition of treasury stock	-2,737	-2,124
Other	1,220	-358
Net cash (used in) provided by financing activities	-90,329	72,686
Net increase in cash and cash equivalents	32,876	160,343
Cash and cash equivalents at beginning of the period	78,162	26,527
Cash and cash equivalents at end of the period	111,038	186,870
Supplemental Disclosure of Cash Flow Information:	'	'
Income taxes	4,686	60
Interest (net of amount capitalized)	55,743	54,907
Non-cash investing activities:	'	'
Additions to property, plant and equipment in accounts payable	19,375	22,480
Idaho Power Company	'	'
Operating Activities:	'	'
Net Income	155,154	149,331
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	101,925	99,035
Deferred income taxes and investment tax credits	14,087	44,772
Changes in regulatory assets and liabilities	36,595	-20,765
Pension and Postretirement Benefit Plan Expense	20,903	21,988
Contributions to pension and postretirement benefit plans	-32,509	-32,535
Earnings of unconsolidated equity-method investments	-7,148	-7,358
Distributions from unconsolidated equity-method investments	4,970	12,543
Allowance for equity funds used during construction	-13,182	-10,876
Other non-cash adjustments to net income, net	1,188	457
Change in:	'	'
Accounts Receivable	3,818	-40,465
Accounts payable and other accrued liabilities	-3,336	-4,372
Taxes accrued/receivable	12,160	21,769
Other current assets	2,069	4,744
Other current liabilities	7,288	5,185
Other assets	-2,970	-1,253
Other liabilities	-5,106	-8,509
Net cash provided by operating activities	295,906	233,691
Investing Activities:	'	'
Additions to property, plant and equipment	-200,778	-165,550
Proceeds from the sale of emission allowances and RECs	2,923	498
Other	4,335	3,371
Net cash used in investing activities	-193,520	-161,681
Financing Activities:	'	'
Issuance of long-term debt	0	150,000
Retirement of long-term debt	-1,064	-1,064
Dividends on common stock	-64,957	-57,313
Other	0	-2,112
Net cash (used in) provided by financing activities	-66,021	89,511
Net increase in cash and cash equivalents	36,365	161,521
Cash and cash equivalents at beginning of the period	66,535	17,251
Cash and cash equivalents at end of the period	102,900	178,772
Supplemental Disclosure of Cash Flow Information:	'	'
Income taxes	19,793	8,760
Interest (net of amount capitalized)	55,576	54,619
Non-cash investing activities:	'	'
Additions to property, plant and equipment in accounts payable	$19,375	$22,480

Condensed_Consolidated_Stateme4

Condensed Consolidated Statements of Equity (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Common Stock [Abstract]	'	'
Balance at beginning of period	$839,750	$834,922
Common stock issued	160	255
Other common stock changes	3,253	3,398
Balance at end of period	843,163	838,575
Retained Earnings	'	'
Balance at beginning of period	1,027,461	923,981
Net Income Attributable to IDACORP, Inc.	158,832	154,815
Common stock dividends	-64,903	-57,292
Balance at end of period	1,121,390	1,021,504
Accumulated Other Comprehensive (Loss) Income	'	'
AOCI - Beginning Balance	-16,553	-17,116
Unrealized gain on securities (net of tax)	0	2,283
Unfunded pension liability adjustment (net of tax)	1,296	1,394
AOCI - Ending Balance	-15,257	-13,439
Treasury Stock	'	'
Balance at beginning of period	-8	-21
Issued	2,465	2,132
Acquired	-2,737	-2,124
Balance at end of period	-280	-13
Total IDACORP, Inc. shareholdersb equity at end of period	1,949,016	1,846,627
Noncontrolling Interests	'	'
Balance at beginning of period	4,090	4,213
Net (loss) income attributable to noncontrolling interests	283	-31
Balance at end of period	4,373	4,182
Total equity at end of period	$1,953,389	$1,850,809

Condensed_Consolidated_Stateme5

Condensed Consolidated Statements of Equity (Parenthetical) (Parentheticals) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Dividends Declared Per Share of Common Stock	$0.43	$0.38	$1.29	$1.14

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:	9 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:	Sep. 30, 2014
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 Federal Energy Regulatory Commission (FERC) and the state regulatory commissions of Idaho and Oregon. 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 owned in part by Idaho Power.

	IDACORP’s other wholly-owned subsidiaries include IDACORP Financial Services, Inc. (IFS), an investor in affordable housing and other real estate investments; Ida-West Energy Company (Ida-West), an operator of small hydroelectric generation projects that satisfy the requirements of the Public Utility Regulatory Policies Act of 1978 (PURPA); and IDACORP Energy Services Co. (IESCo), which is the former limited partner of, and current successor by merger to, IDACORP Energy L.P. (IE), a marketer of energy commodities that wound down operations in 2003.

	Regulation of Utility Operations

	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 as regulatory assets or regulatory liabilities on the balance sheet and recorded on the income statement when recovered or returned through rates. Additionally, regulators can impose regulatory liabilities upon a regulated company for amounts previously collected from customers that are expected to be refunded. The effects of applying these regulatory accounting principles to Idaho Power's operations are discussed in more detail in Note 3.

	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, 2014, consolidated results of operations for the three and nine months ended September 30, 2014 and 2013, and consolidated cash flows for the nine months ended September 30, 2014 and 2013. These adjustments are of a normal and recurring nature. These financial statements do not contain the complete detail or footnote disclosure 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, 2013. 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 (GAAP). These estimates and assumptions include those related to rate regulation, retirement benefits, contingencies, litigation, 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.

	Change in Method of Accounting for Investments in Qualified Affordable Housing Projects

	On January 15, 2014, the Financial Accounting Standards Board issued Accounting Standards Update (ASU) No. 2014-01, Investments-Equity Method and Joint Ventures (Topic 323): Accounting for Investments in Qualified Affordable Housing Projects. This ASU permits an accounting policy election to account for investments in qualified affordable housing projects using the proportional amortization method. For its consolidated financial statements as of and for the year ended December 31, 2013, IDACORP elected early adoption of ASU 2014-01 and changed its accounting for its equity-method investments in qualified affordable housing projects to the proportional amortization method. All prior periods were adjusted to reflect the new method. The standard also requires the recognition of the net investment performance in the financial statements as a component of income tax expense. The new method was elected because IDACORP believes the proportional amortization method more fairly represents the economics of and provides users with a better understanding of the returns from such investments than the equity method of amortization.

INCOME_TAXES

INCOME TAXES:	9 Months Ended
	Sep. 30, 2014
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 (in thousands of dollars):


		IDACORP						Idaho Power
		2014			2013			2014			2013
	Nine months ended September 30,
	Income tax at statutory rates (federal and state)	$	75,385		$	85,143		$	74,702		$	84,466

	Capitalized repairs deduction(1)	(19,061		)	(16,129		)	(19,061		)	(16,129		)
	Accounting method changes	(11,075		)	4,583			(11,075		)	4,583

	Affordable housing tax credits	(3,792		)	(4,152		)	—			—

	Affordable housing investment amortization, net of statutory taxes	2,041			739			—			—

	Other(2)	(9,530		)	(7,243		)	(8,667		)	(6,225		)
	Income tax expense	$	33,968		$	62,941		$	35,899		$	66,695

	Effective tax rate	17.6		%	28.9		%	18.8		%	30.9		%
	(1) The "Capitalized repairs deduction" is one of Idaho Power's most significant regulatory flow-through tax adjustments.
	(2) "Other" is primarily comprised of the net tax effect of Idaho Power's remaining regulatory flow-through tax adjustments, which are each listed in the rate reconciliation table in Note 2 to the consolidated financial statements included in IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, 2013.

	The reductions in income tax expense for the nine months ended September 30, 2014 as compared with the same period in 2013 were primarily due to lower Idaho Power pre-tax earnings in 2014, and the accounting method changes to Idaho Power’s capitalized repairs tax method that are discussed below. Net regulatory flow-through tax adjustments at Idaho Power were higher for the nine months ended September 30, 2014, primarily due to a greater capitalized repair deduction estimate for 2014.

	Accounting Method Changes

	In the third quarter of 2014 Idaho Power, in coordination with the U.S. Internal Revenue Service (IRS) through IDACORP’s Compliance Assurance Program (CAP) examination process, implemented aspects of the final tangible property regulations and other technical interpretations of these rules into its existing capitalized repairs tax accounting method for generation, transmission and distribution assets. These technical interpretations were received from the IRS in 2014. As a result of the modifications, an $11.1 million net tax benefit related to the 2013 capitalized repairs deduction was recorded in the third quarter of 2014. Idaho Power finalized these changes with the filing of IDACORP’s 2013 consolidated federal income tax return in September 2014. The IRS approved the repairs method modifications prior to the filing of the return as part of IDACORP’s 2013 CAP examination. Idaho Power’s 2014 capitalized repairs deduction estimate incorporates the modifications made to the accounting method.

	In the third quarter of 2013, the U.S. Treasury Department and IRS issued final regulations addressing the deduction or capitalization of expenditures related to tangible property. In connection with the issuance of the regulations, Idaho Power assessed and estimated the impact of a method change associated with the electric generation property portion of the capitalized repairs tax method it adopted in fiscal year 2010. The change is pursuant to Revenue Procedure 2013-24 and would bring Idaho Power's existing method into alignment with the Revenue Procedure's safe harbor unit-of-property definitions for electric generation property. Based upon this assessment, Idaho Power recorded $4.6 million of income tax expense related to the cumulative method change adjustment for years prior to 2013. Continued refinement of Idaho Power's initial estimate of the method change impact could result in additional future income tax expense or benefit. Idaho Power expects the method change will be finalized with the filing of IDACORP's 2014 consolidated federal income tax return in September 2015.

	The amount of the capitalized repairs annual tax deduction will vary depending on a number of factors, but most directly by the amount and type of Idaho Power's annual capital additions. The reversal of this temporary difference from prior years will offset a portion of the ongoing annual benefit. Idaho Power’s prescribed regulatory accounting treatment requires immediate income recognition for temporary tax differences of this type, commonly referred to as "flow-through." A net regulatory asset is established to reflect Idaho Power’s ability to recover the net increased income tax expense when such temporary differences reverse.

REGULATORY_MATTERS

REGULATORY MATTERS:	9 Months Ended
	Sep. 30, 2014
Public Utilities, Rate Matters [Abstract]	'
Regulatory Matters	'
	REGULATORY MATTERS

	Included below is a summary of Idaho Power's most recent general rate changes, as well as other recent or pending notable regulatory matters and proceedings.

	Idaho and Oregon General Rate Cases and Base Rate Adjustments

	Effective January 1, 2012, Idaho Power implemented new Idaho base rates resulting from its receipt of an order from the Idaho Public Utilities Commission (IPUC) approving a settlement stipulation that provided for a 7.86 percent authorized rate of return on an Idaho-jurisdiction rate base of approximately $2.36 billion. The settlement stipulation resulted in a $34.0 million overall increase in Idaho Power's annual Idaho-jurisdictional base rate revenues. Neither the IPUC's order nor the settlement stipulation specified an authorized rate of return on equity.

	Effective March 1, 2012, Idaho Power implemented new Oregon base rates resulting from its receipt of an order from the Public Utility Commission of Oregon (OPUC) approving a settlement stipulation that provided for a $1.8 million base rate revenue increase, a return on equity of 9.9 percent, and an overall rate of return of 7.757 percent in the Oregon jurisdiction.

	Idaho and Oregon base rates were subsequently adjusted again in 2012, in connection with Idaho Power's completion of the Langley Gulch power plant. On June 29, 2012, the IPUC issued an order approving a $58.1 million increase in annual Idaho-jurisdiction base rate revenues, effective July 1, 2012, for inclusion of the investment and associated costs of the plant in rates. The order also provided for a $335.9 million increase in Idaho rate base. On September 20, 2012, the OPUC issued an order approving a $3.0 million increase in annual Oregon jurisdiction base rate revenues, effective October 1, 2012, for inclusion of the investment and associated costs of the plant in Oregon rates.

	See "Idaho Power Cost Adjustment Mechanism; Update to Base-Level Net Power Supply Expense" below in this Note 3 for a description of Idaho Power's authorization from the IPUC to move a portion of its power supply expenses into Idaho base rates, effective June 1, 2014.

	Idaho Settlement Stipulation — Investment Tax Credits and Sharing Mechanism

	On December 27, 2011, the IPUC issued an order, separate from the then-pending Idaho general rate case proceeding, approving a settlement stipulation that provides as follows:


	•	If Idaho Power's actual Idaho-jurisdiction return on year-end equity (Idaho ROE) for 2012, 2013, or 2014 is less than 9.5 percent, then Idaho Power may amortize additional accumulated deferred investment tax credits (ADITC) to help achieve a minimum 9.5 percent Idaho ROE in the applicable year. Idaho Power may amortize additional ADITC in an aggregate amount up to $45 million over the three-year period.

	•	If Idaho Power's actual Idaho ROE for 2012, 2013, or 2014 exceeds 10.0 percent, the amount of Idaho Power's Idaho-jurisdiction earnings exceeding a 10.0 percent and up to and including a 10.5 percent Idaho ROE for the applicable year would be shared equally between Idaho Power and its Idaho customers in the form of a rate reduction to become effective at the time of the subsequent year's power cost adjustment (PCA).

	•	If Idaho Power's actual Idaho ROE for 2012, 2013, or 2014 exceeds 10.5 percent, the amount of Idaho Power's Idaho-jurisdiction earnings exceeding a 10.5 percent Idaho ROE for the applicable year would be allocated 75 percent to Idaho Power's Idaho customers through a reduction to the pension regulatory asset balancing account and 25 percent to Idaho Power.

	The settlement stipulation also provides that the Idaho ROE thresholds (9.5 percent, 10.0 percent, and 10.5 percent) will be automatically adjusted prospectively in the event the IPUC approves a change to Idaho Power's authorized return on equity as part of a general rate case proceeding seeking a rate change effective prior to January 1, 2015.

	Idaho Power's actual Idaho ROE in 2012 and 2013 triggered the sharing mechanism of the December 2011 settlement stipulation for both years. Based on its estimate of full year 2014 Idaho ROE, in the third quarter of 2014 Idaho Power recorded a $4.9 million provision against current revenue for sharing of earnings with customers for 2014.

	In October 2014, the IPUC issued an order approving an extension, with modifications, of the terms of the December 2011 Idaho settlement stipulation for the period from 2015 to 2019, or until the terms are otherwise modified or terminated by order of the IPUC. The provisions of the new settlement stipulation are as follows:


	•	If Idaho Power's annual Idaho ROE in any year is less than 9.5 percent, then Idaho Power may amortize up to $25 million of additional ADITC to help achieve a 9.5 percent Idaho ROE for that year, and may amortize up to a total of $45 million of additional ADITC (less any amount of additional ADITC amortized in 2014 under the December 2011 settlement stipulation).

	•	If Idaho Power's annual Idaho ROE in any year exceeds 10.0 percent, the amount of earnings exceeding a 10.0 percent Idaho ROE and up to and including a 10.5 percent Idaho ROE will be allocated 75 percent to Idaho Power's Idaho customers as a rate reduction to be effective at the time of the subsequent year's power cost adjustment and 25 percent to Idaho Power.

	•	If Idaho Power's annual Idaho ROE in any year exceeds 10.5 percent, the amount of earnings exceeding a 10.5 percent Idaho ROE will be allocated 50 percent to Idaho Power's Idaho customers as a rate reduction to be effective at the time of the subsequent year's power cost adjustment, 25 percent to Idaho Power's Idaho customers in the form of a reduction to the pension regulatory asset balancing account (to reduce the amount to be collected in the future from Idaho customers), and 25 percent to Idaho Power.

	•	If the full $45 million of additional ADITC contemplated by the settlement stipulation has been amortized (including any additional ADITCs amortized in 2014) the sharing provisions would terminate.

	•	In the event the IPUC approves a change to Idaho Power's Idaho-jurisdictional allowed return on equity as part of a general rate case proceeding seeking a rate change effective prior to January 1, 2020, the Idaho ROE thresholds (9.5 percent, 10.0 percent, and 10.5 percent) will be adjusted prospectively, under the same methodology used for the December 2011 settlement stipulation.

	Idaho Power Cost Adjustment Mechanism; Update to Base-Level Net Power Supply Expense

	In both its Idaho and Oregon jurisdictions, Idaho Power's PCA mechanisms address the volatility of power supply costs and provide for annual adjustments to the rates charged to its retail customers. The PCA mechanisms compare Idaho Power's actual and forecast net power supply costs (primarily fuel and purchased power less off-system sales) against net power supply costs currently being recovered in retail rates. Under the PCA mechanisms, certain differences between actual net power supply costs incurred by Idaho Power and the costs included in retail rates are recorded as a deferred charge or credit on the balance sheets for future recovery or refund through retail rates. The power supply costs deferred primarily result from changes in wholesale market prices and transaction volumes, fuel prices, changes in contracted power purchase prices and volumes (including PURPA power purchases), and the levels of Idaho Power's own hydroelectric and thermal generation.

	On November 1, 2013, Idaho Power filed an application with the IPUC requesting an increase of approximately $106 million in the normalized or "base level" net power supply expense on a total-system basis to be used to update base rates and in the determination of the PCA rate that would become effective June 1, 2014. Idaho Power's request was intended to remove the Idaho-jurisdictional portion of those expenses from collection via the Idaho PCA mechanism and instead collect that portion through base rates. On March 21, 2014, the IPUC issued an order approving Idaho Power's application, with the change in collection methodology effective June 1, 2014.

	On May 30, 2014, the IPUC issued an order approving Idaho Power's April 15, 2014 application requesting an $11.1 million net increase in Idaho PCA rates, effective for the 2014-2015 PCA collection period from June 1, 2014 to May 31, 2015. The $11.1 million PCA rate increase was net of Idaho Power's $20.0 million of surplus Idaho energy efficiency rider funds. The PCA rate increase was also net of $7.6 million of customer revenue sharing for the year 2013 under the December 2011 settlement stipulation described above. Previously, in May 2013 the IPUC issued an order authorizing a $140.4 million increase in PCA rates (net of 2012 revenue sharing), effective for the 2013-2014 PCA collection period from June 1, 2013 to May 31, 2014.

	Annual Idaho Fixed Cost Adjustment Filing

	The fixed cost adjustment (FCA) is designed to remove 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. The FCA is adjusted each year to recover or refund the difference between the amount of fixed costs authorized in Idaho Power's most recent general rate case and the amount of fixed costs recovered by Idaho Power based upon weather-normalized energy sales. On May 30, 2014, the IPUC issued an order approving Idaho Power's March 14, 2014 application requesting a $6.0 million increase in the FCA recovery from $8.9 million to $14.9 million, effective for the period from June 1, 2014 to May 31, 2015. Previously, on May 22, 2013, the IPUC issued an order authorizing a decrease in FCA collection from $10.3 million to $8.9 million, effective for the period from June 1, 2013 to May 31, 2014.

	IPUC Review of Annual Rate Adjustment Mechanisms

	On July 1, 2014, the IPUC opened a docket pursuant to which Idaho Power, the IPUC Staff, and other interested parties would further evaluate Idaho Power's application of the true-up component of the PCA mechanism and whether a deferral balance adjustment is appropriate. The docket arose from the IPUC's May 2014 PCA order, which noted that the IPUC Staff believed that Idaho Power's application of the true-up component introduces a line-loss bias that inflated the true-up revenue it must collect by $14.2 million. The IPUC's docket was closed via an order issued by the IPUC on August 6, 2014, with no retroactive change to the PCA mechanism. Idaho Power has subsequently met with interested parties to explore approaches to increasing the accuracy of the actual cost recovery under the PCA mechanism, and discussions are ongoing.

	Also on July 1, 2014, the IPUC opened a docket to allow Idaho Power, the IPUC Staff, and other interested parties to further evaluate the IPUC Staff's concerns regarding the application of the FCA mechanism (including weather-normalization, customer count methodology, rate adjustment cap, and cross-subsidization issues) and whether the FCA is effectively removing Idaho Power's disincentive to aggressively pursue energy efficiency programs. Proceedings in the FCA docket, which remains open, could result in significant changes to the FCA.

NOTES_PAYABLE

NOTES PAYABLE:	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Notes Payable	'
	NOTES PAYABLE

	Credit Facilities

	IDACORP and Idaho Power have in place credit facilities that may be used for general corporate purposes and commercial paper backup. The terms and conditions of those credit facilities have not changed compared to the descriptions included in IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, 2013.

	At September 30, 2014, no loans were outstanding under either IDACORP's or Idaho Power's facilities. At September 30, 2014, Idaho Power had regulatory authority to incur up to $450 million in principal amount of short-term indebtedness at any one time outstanding. Balances (in thousands of dollars) and interest rates of IDACORP’s and Idaho Power's short-term borrowings were as follows at September 30, 2014 and December 31, 2013:


		September 30, 2014									December 31, 2013
		Idaho Power			IDACORP			Total			Idaho Power			IDACORP			Total
	Commercial paper outstanding	$	—		$	31,800		$	31,800		$	—		$	54,750		$	54,750

	Weighted-average annual interest rate	—		%	0.31		%	0.31		%	—		%	0.34		%	0.34		%

COMMON_STOCK

COMMON STOCK:	9 Months Ended
COMMON STOCK:	Sep. 30, 2014
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, 2014, IDACORP issued 74,049 shares of common stock pursuant to the IDACORP, Inc. 2000 Long-Term Incentive and Compensation Plan. Effective July 1, 2012, IDACORP instructed the plan administrators of the IDACORP, Inc. Dividend Reinvestment and Stock Purchase Plan and Idaho Power Company Employee Savings Plan to use market purchases of IDACORP common stock, as opposed to original issuance of common stock from IDACORP, to acquire shares of IDACORP common stock for the plans. However, IDACORP may determine at any time to resume original issuances of common stock under those plans.

	IDACORP enters into sales agency agreements as a means of selling its common stock from time to time pursuant to a continuous equity program. On July 12, 2013, IDACORP entered into its current Sales Agency Agreement with BNY Mellon Capital Markets, LLC (BNYMCM). IDACORP may offer and sell up to 3 million shares of its common stock from time to time in at-the-market offerings through BNYMCM as IDACORP's agent. IDACORP has no obligation to issue any minimum number of shares under the Sales Agency Agreement. As of the date of this report, no shares of IDACORP common stock have been issued under the current Sales Agency Agreement.

	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, 2014, the leverage ratios for IDACORP and Idaho Power were 46 percent and 47 percent, respectively. Based on these restrictions, IDACORP’s and Idaho Power’s dividends were limited to $1.1 billion and $942 million, respectively, at September 30, 2014. 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 the company from any material subsidiary. At September 30, 2014, IDACORP and Idaho Power were in compliance with the financial covenants.

	Idaho Power’s Revised Policy and 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, 2014, Idaho Power's common equity capital was 53 percent of its total adjusted capital. Further, Idaho Power must obtain approval of the OPUC before it could 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 prohibits the payment of dividends from "capital accounts." The term "capital account" is undefined in the Federal Power Act 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, 2014
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, 2014 and 2013 (in thousands, except for per share amounts).


		Three months ended				Nine months ended
		September 30,				September 30,
		2014		2013		2014		2013
	Numerator:

	Net income attributable to IDACORP, Inc.	$	86,889	$	73,119	$	158,832	$	154,815

	Denominator:

	Weighted-average common shares outstanding - basic	50,129		50,056		50,131		50,051

	Effect of dilutive securities	91		97		53		58

	Weighted-average common shares outstanding - diluted	50,220		50,153		50,184		50,109

	Basic earnings per share	$	1.73	$	1.46	$	3.17	$	3.09

	Diluted earnings per share	$	1.73	$	1.46	$	3.16	$	3.09

COMMITMENTS

COMMITMENTS:	9 Months Ended
COMMITMENTS:	Sep. 30, 2014
Disclosure Text Block Supplement [Abstract]	'
Commitments	'
	COMMITMENTS

	Purchase Obligations

	IDACORP's and Idaho Power's purchase obligations did not change materially, outside of the ordinary course of business, during the nine months ended September 30, 2014, other than the addition of thirteen power purchase agreements with solar, wind, and other alternative energy developers for projects with a combined nameplate capacity of approximately 176 MW. Payments pursuant to these agreements are expected to total $659 million from 2014 to 2038. Three of these power purchase agreements remain subject to IPUC approval, with a combined nameplate capacity of approximately 120 MW and expected payments of $449 million over the period from 2016 to 2037.

	Guarantees

	Idaho Power has agreed to guarantee a portion of the performance 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 $70 million at September 30, 2014, representing IERCo's one-third share of BCC's total reclamation obligation. BCC has a reclamation trust fund set aside specifically for the purpose of paying these reclamation costs. At September 30, 2014, the value of the reclamation trust fund was $66 million. During the nine months ended September 30, 2014, the reclamation trust fund distributed approximately $10 million 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 add a per-ton surcharge to coal sales, all of which are made to the Jim Bridger plant. Starting in 2010, BCC began applying a nominal surcharge to coal sales in order to maintain adequate reserves in the reclamation trust fund. 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.

	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, 2014, management believes 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
CONTINGENCIES:	Sep. 30, 2014
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, including the items described in this Note 8. Some of these claims, controversies, disputes, and other contingent matters 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. In such cases, there may be a possible exposure to loss in excess of any amounts accrued. IDACORP and Idaho Power monitor those matters for developments that could affect the likelihood of a loss and the accrued amount, if any, and adjust the amount as appropriate. 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. For matters that affect Idaho Power’s operations, Idaho Power intends to seek, to the extent permissible and appropriate, recovery through the ratemaking process of costs incurred.

	Western Energy Proceedings

	High prices for electricity, energy shortages, and blackouts in California and in western wholesale markets during 2000 and 2001 caused numerous purchasers of electricity in those markets to initiate proceedings seeking refunds or other forms of relief and the FERC to initiate its own investigations. Some of these proceedings remain pending before the FERC or are on appeal to the United States Court of Appeals for the Ninth Circuit. Idaho Power and IESCo (as successor to IDACORP Energy L.P.) believe that settlement releases they have obtained will restrict potential claims that might result from the disposition of pending proceedings and predict that these matters will not have a material adverse effect on IDACORP's or Idaho Power's results of operations or financial condition. However, the settlements and associated FERC orders have not fully eliminated the potential for so-called "ripple claims," which involve potential claims for refunds from an upstream seller of power based on a finding that its downstream buyer was liable for refunds as a seller of power during the relevant period. The FERC has characterized these ripple claims as "speculative." The FERC has refused to dismiss Idaho Power and IESCo from the proceedings in the Pacific Northwest. In orders respecting two separately filed settlements, the FERC has refused to approve a provision that provided for waivers of all claims in those proceedings, despite only limited objections from two market participants, one of whom removed its objections in the later-filed settlement. Petitions for review filed by Idaho Power and IESCo of the first of the FERC's decisions refusing to approve the waiver provision of the settlements have been briefed to the Ninth Circuit Court of Appeals and remain pending before that court. On August 5, 2014, Idaho Power and IESCo filed a petition for review of the FERC orders rejecting ripple claim waivers in the Ninth Circuit, which stayed the new proceedings until February 2015.

	Based on its evaluation of the merits of ripple claims and the inability to estimate the potential exposure should the claims ultimately have any merit, particularly in light of Idaho Power and IESCo being both purchasers and sellers in the energy market during the relevant period, Idaho Power and IESCo have no amount accrued relating to the proceedings. To the extent the availability of any ripple claims materializes, Idaho Power and IESCo intend to continue to vigorously defend their positions in the proceedings.

	Snake River Basin Adjudication

	Idaho Power holds water rights, acquired under applicable state law, for its hydroelectric projects. In addition, Idaho Power holds water rights for domestic, irrigation, commercial, and other necessary purposes related to project lands and other holdings within the states of Idaho and Oregon. Idaho Power's water rights for power generation are, to varying degrees, subordinated to future upstream appropriations for irrigation and other authorized consumptive uses. Over time, increased irrigation development and other consumptive uses within the Snake River watershed led to a reduction in flows of the Snake River. In the late 1970s and early 1980s these reduced flows resulted in a conflict between the exercise of Idaho Power's water rights at certain hydroelectric projects on the Snake River and upstream consumptive diversions. The Swan Falls Agreement, signed by Idaho Power and the State of Idaho on October 25, 1984, resolved the conflict and provided a level of protection for Idaho Power's hydropower water rights at specified projects on the Snake River through the establishment of minimum stream flows and an administrative process governing future development of water rights that may affect those minimum stream flows. In 1987, Congress enacted legislation directing the FERC to issue an order approving the Swan Falls settlement together with a finding that the agreement was neither inconsistent with the terms and conditions of Idaho Power's project licenses nor the Federal Power Act. The FERC entered an order implementing the legislation in March 1988.

	The Swan Falls Agreement provided that the resolution and recognition of Idaho Power's water rights together with the State Water Plan provided a sound comprehensive plan for management of the Snake River watershed. The Swan Falls Agreement also recognized, however, that in order to effectively manage the waters of the Snake River basin, a general adjudication to determine the nature, extent, and priority of the rights of all water uses in the basin was necessary. Consistent with that recognition, in 1987 the State of Idaho initiated the Snake River Basin Adjudication (SRBA), and pursuant to the commencement order issued by the SRBA court that same year, all claimants to water rights within the basin were required to file water rights claims in the SRBA. Idaho Power filed claims to its water rights and has been actively participating in the SRBA since its commencement. Questions concerning the effect of the Swan Falls Agreement on Idaho Power's water rights claims, including the nature and extent of the subordination of Idaho Power's rights to upstream uses, resulted in the filing of litigation in the SRBA in 2007 between Idaho Power and the State of Idaho. This litigation was resolved by the Framework Reaffirming the Swan Falls Settlement (Framework) signed by Idaho Power and the State of Idaho on March 25, 2009. In that Framework, the parties acknowledged that the effective management of Idaho's water resources remains critical to the public interest of the State of Idaho by sustaining economic growth, maintaining reasonable electric rates, protecting and preserving existing water rights, and protecting water quality and environmental values. The Framework further provided that the State of Idaho and Idaho Power would cooperate in exploring approaches to resolve issues of mutual concern relating to the management of Idaho's water resources. Idaho Power continues to work with the State of Idaho and other interested parties on these issues.

	Idaho Power’s claims for water rights have now been adjudicated in the SRBA and partial decrees for those water rights have been entered by the court. In July 2011, the SRBA Court entered an Order Designating Basin-Wide Issue 16, In Re: Form and Content of Final Unified Decree, and advised the parties to the SRBA of the need to file notices of intent to participate in the basin-wide issue and of the court’s intent to establish a schedule for closing the taking of water right claims in the SRBA. Idaho Power participated in Basin-Wide Issue 16 and in June 2012 the court issued a memorandum decision and order. By subsequent orders, the court closed claims taking in all of the basins in the SRBA. The court issued a final unified decree in the SRBA in August 2014, substantially concluding the SRBA.

	Separately, Idaho Power continues to work with the State of Idaho and other interested stakeholders on issues relating to the management of the Eastern Snake Plain Aquifer (ESPA), a large underground aquifer in southeastern Idaho that is hydrologically connected to the Snake River. House Concurrent Resolution No. 28, adopted by the Idaho Legislature in 2007, directed the Idaho Water Resource Board to pursue the development of a comprehensive management plan for the ESPA, to include measures that would enhance aquifer levels, springs, and river flows on the eastern Snake River plain to the benefit of both agricultural development and hydropower generation. In May 2007, the Idaho Water Resource Board appointed an advisory committee, charged with the responsibility of developing a management plan for the ESPA. Idaho Power was a member of that committee. In January 2009, the Idaho Water Resource Board, based on the committee's recommendations, adopted a Comprehensive Aquifer Management Plan (CAMP) for the ESPA. The Idaho Legislature approved the CAMP that same year. Idaho Power is a member of the CAMP Implementation Committee and continues to work with the Idaho Water Resource Board, other stakeholders, and the Idaho Legislature in exploring opportunities for implementation of the CAMP management plan.

	Other Proceedings

	IDACORP and Idaho Power are parties to legal claims and legal and regulatory actions and proceedings in the ordinary course of business that are in addition to those discussed above and, as noted above, records an accrual for associated loss contingencies when they are probable and reasonably estimable. As of the date of this report the companies believe that resolution of those matters will not have a material adverse effect on their respective consolidated financial statements. Idaho Power is also actively monitoring various pending environmental regulations that may have a significant impact on its future operations, including the U.S. Environmental Protection Agency's recently issued proposed rule for CO2 emission reductions from existing utility generating plants under Section 111(d) of the Clean Air Act. Given uncertainties regarding the outcome, timing, and compliance plans for these environmental matters, Idaho Power is unable to estimate the financial impact of these regulations but does believe that future capital investment for infrastructure and modifications to its electric generating facilities to comply with these regulations could be significant.

BENEFIT_PLANS

BENEFIT PLANS:	9 Months Ended
	Sep. 30, 2014
General Discussion of Pension and Other Postretirement Benefits [Abstract]	'
Benefit Plans	'
	BENEFIT PLANS

	Idaho Power has two defined benefit pension plans - a noncontributory defined benefit pension plan (pension plan) and nonqualified defined benefit plans for certain senior management employees called the Security Plan for Senior Management Employees I and II (SMSP). 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, 2014 and 2013 (in thousands of dollars).


		Pension Plan						SMSP				Postretirement
												Benefits
		2014			2013			2014		2013		2014			2013
	Service cost	$	6,323		$	7,839		$	411	$	544	$	252		$	328

	Interest cost	8,853			7,958			964		816		711			659

	Expected return on plan assets	(10,561		)	(9,053		)	—		—		(648		)	(582		)

	Amortization of prior service cost	86			86			55		53		45			(57		)

	Amortization of net loss	978			4,280			654		709		—			25

	Net periodic benefit cost	5,679			11,110			2,084		2,122		360			373

	Adjustments due to the effects of regulation(1)	(1,140		)	(6,274		)	—		—		—			—

	Net periodic benefit cost recognized for financial reporting(1)	$	4,539		$	4,836		$	2,084	$	2,122	$	360		$	373

	(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, income statement recognition of pension plan costs is deferred until costs are recovered through rates.

	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, 2014 and 2013 (in thousands of dollars).


		Pension Plan						SMSP				Postretirement
												Benefits
		2014			2013			2014		2013		2014			2013
	Service cost	$	18,969		$	23,517		$	1,234	$	1,634	$	758		$	986

	Interest cost	26,561			23,873			2,892		2,444		2,131			1,975

	Expected return on plan assets	(31,717		)	(26,816		)	—		—		(1,946		)	(1,746		)

	Amortization of prior service cost	260			260			165		159		137			(172		)

	Amortization of net loss	2,933			12,839			1,963		2,129		—			74

	Net periodic benefit cost	17,006			33,673			6,254		6,366		1,080			1,117

	Adjustments due to the effects of regulation(1)	(3,437		)	(19,168		)	—		—		—			—

	Net periodic benefit cost recognized for financial reporting(1)	$	13,569		$	14,505		$	6,254	$	6,366	$	1,080		$	1,117

	(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, income statement recognition of pension plan costs is deferred until costs are recovered through rates.

	During the nine months ended September 30, 2014, Idaho Power made $30.0 million of contributions to its defined benefit pension plan.

	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.

INVESTMENTS_IN_DEBT_AND_EQUITY

INVESTMENTS IN DEBT AND EQUITY SECURITIES:

9 Months Ended

Sep. 30, 2014

Investments [Abstract]

Investments in Debt and Equity Securities

INVESTMENTS IN EQUITY SECURITIES

Investments in securities classified as available-for-sale securities are reported at fair value, using either specific identification or average cost to determine the cost for computing gains or losses. Any unrealized gains or losses on available-for-sale securities are included in other comprehensive income. The following table summarizes investments in equity securities by IDACORP and Idaho Power as of September 30, 2014 and December 31, 2013 (in thousands of dollars).

September 30, 2014

December 31, 2013

Gross

Fair

Gross

Fair

Unrealized

Value

Unrealized

Value

Gain

Loss

Gain

Loss

Available-for-sale securities

—

37,606

—

41,119

At the end of each reporting period, IDACORP and Idaho Power analyze securities in loss positions to determine whether they have experienced a decline in market value that is considered other-than-temporary. At September 30, 2014 and at December 31, 2013, there were no indicators of other-than-temporary impairment related to IDACORP's and Idaho Power's investments.

There were no sales of available-for-sale securities during the nine months ended September 30, 2014 or 2013.

DERIVATIVE_FINANCIAL_INSTRUMEN

DERIVATIVE FINANCIAL INSTRUMENTS:	9 Months Ended
	Sep. 30, 2014
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 below.

	The table below presents the gains and losses on derivatives not designated as hedging instruments for the three and nine months ended September 30, 2014 and 2013 (in thousands of dollars).


					Gain/(Loss) on Derivatives Recognized in Income(1)
			Location of Realized Gain/(Loss) on Derivatives Recognized in Income		Three months ended								Nine months ended
					September 30,								September 30,
					2014				2013				2014				2013
	Financial swaps		Off-system sales		$	517			$	(98	)		$	(6,026	)		$	224

	Financial swaps		Purchased power		(2,265		)		496				(785		)		510

	Financial swaps		Fuel expense		239				(705		)		3,907				444

	Financial swaps		Other operations and maintenance		(34		)		12				(44		)		27

	Forward contracts		Off-system sales		112				135				164				135

	Forward contracts		Purchased power		(113		)		(138		)		(163		)		(138		)
	Forward contracts		Fuel expense		53				52				101				131

	(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 off-system sales 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 for additional information concerning the determination of fair value for Idaho Power’s assets and liabilities from price risk management activities.


	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, 2014 and December 31, 2013 (in thousands of dollars).


					Asset Derivatives												Liability Derivatives
			Balance Sheet Location		Gross Fair Value				Amounts Offset				Net Assets				Gross Fair Value				Amounts Offset				Net Liabilities

	September 30, 2014
	Current:

	Financial swaps		Other current assets		$	1,418			$	(154	)		$	1,264			$	154			$	(154	)		$	—

	Financial swaps		Other current liabilities		—				—				—				689				—				689

	Forward contracts		Other current assets		176				—				176				—				—				—

	Forward contracts		Other current liabilities		—				—				—				115				—				115

	Long-term:

	Forward contracts		Other assets		63				—				63				—				—				—

	Total				$	1,657			$	(154	)		$	1,503			$	958			$	(154	)		$	804

	December 31, 2013
	Current:

	Financial swaps		Other current assets		$	1,451			$	(175	)		$	1,276			$	175			$	(175	)		$	—

Financial swaps		Other current liabilities		373				(373		)		—				1,975				(1,429		)	(1)	546

Forward contracts		Other current assets		109				—				109				—				—				—

Forward contracts		Other current liabilities		—				—				—				26				—				26

Long-term:

Financial swaps		Other assets		189				(28		)		161				28				(28		)		—

Forward contracts		Other assets		126				—				126				—				—				—

Total				$	2,248			$	(576	)		$	1,672			$	2,204			$	(1,632	)		$	572

(1) Current liability derivative amounts offset include $1.1 million of collateral receivable for the period ended December 31, 2013.

The table below presents the volumes of derivative commodity forward contracts and swaps outstanding at September 30, 2014 and 2013 (in thousands of units).


				September 30,
Commodity		Units		2014		2013
Electricity purchases		MWh		227		382
Electricity sales		MWh		391		1,064
Natural gas purchases		MMBtu		5,455		11,929
Natural gas sales		MMBtu		1,137		1,153
Diesel purchases		Gallons		222		1,113

Credit Risk

At September 30, 2014, 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 contracts are commonly under Western Systems Power Pool agreements, physical gas contracts are usually under North American Energy Standards Board contracts, and financial transactions are usually under International Swaps and Derivatives Association, Inc. 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 of Idaho Power's 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, 2014, was $0.7 million. Idaho Power posted $0.1 million of cash collateral related to this amount. If the credit-risk-related contingent features underlying these agreements were triggered on September 30, 2014, Idaho Power would have been required to post an additional $6.2 million of cash collateral to its counterparties.

FAIR_VALUE_MEASUREMENTS

FAIR VALUE MEASUREMENTS:	9 Months Ended
	Sep. 30, 2014
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring 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 has 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 three and nine months ended September 30, 2014 or the year ended December 31, 2013.

	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, 2014 and December 31, 2013 (in thousands of dollars).


		30-Sep-14								December 31, 2013
		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	Assets:

	Derivatives	$	995	$	508	$	—	$	1,503	$	1,437	$	235	$	—	$	1,672

	Money market funds	100		—		—		100		100		—		—		100

	Trading securities: Equity securities	139		—		—		139		1,153		—		—		1,153

	Available-for-sale securities: Equity securities	37,606		—		—		37,606		41,119		—		—		41,119

	Liabilities:
	Derivatives	$	78	$	726	$	—	$	804	$	546	$	26	$	—	$	572


	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 derivative valuations are performed using New York Mercantile Exchange (NYMEX) and ICE pricing, adjusted for location basis, which are also quoted under NYMEX and ICE pricing. Trading securities consist of employee-directed investments held in a Rabbi Trust and are related to an executive deferred compensation plan. Available-for-sale securities are related to the SMSP and are held in a Rabbi Trust and are actively traded money market and equity funds with quoted prices in active markets.

	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, 2014 and December 31, 2013, using available market information and appropriate valuation methodologies (in thousands of dollars).


		September 30, 2014				December 31, 2013
		Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
	IDACORP

	Assets:

	Notes receivable(1)	$	3,472	$	3,472	$	3,472	$	3,472

	Liabilities:

	Long-term debt(1)	1,615,441		1,672,271		1,616,322		1,600,248

	Idaho Power

	Liabilities:

	Long-term debt(1)	$	1,615,441	$	1,672,271	$	1,616,322	$	1,600,248


(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.

Notes receivable are related to Ida-West and are valued based on unobservable inputs, including discounted cash flows, which are partially based on forecasted hydroelectric 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, 2014
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 and historic rehabilitation projects, Ida-West’s joint venture investments in small hydroelectric generation projects, the remaining activities of IESCo, 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 of dollars).


		Utility		All		Eliminations			Consolidated
		Operations		Other					Total
	Three months ended September 30, 2014:
	Revenues	$	380,711	$	1,490	$	—		$	382,201

	Net income attributable to IDACORP, Inc.	84,600		2,289		—			86,889

	Total assets as of September 30, 2014	5,408,736		102,904		(13,363		)	5,498,277

	Three months ended September 30, 2013:
	Revenues	$	380,304	$	803	$	—		$	381,107

	Net income attributable to IDACORP, Inc.	70,302		2,817		—			73,119

	Nine months ended September 30, 2014:
	Revenues	$	989,686	$	3,017	$	—		$	992,703

	Net income attributable to IDACORP, Inc.	155,154		3,678		—			158,832

	Nine months ended September 30, 2013:
	Revenues	$	947,529	$	2,455	$	—		$	949,984

	Net income attributable to IDACORP, Inc.	149,331		5,484		—			154,815

CHANGES_IN_ACCUMULATED_OTHER_C

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME: CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME:	9 Months Ended
	Sep. 30, 2014
Statement of Comprehensive Income [Abstract]	'
Changes in Accumulated Other Comprehensive Income [Text Block]	'
	CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME

	Comprehensive income includes net income, unrealized holding gains and losses on available-for-sale marketable securities, and amounts related to the SMSP.

	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, 2014 and 2013 (in thousands of dollars). Items in parentheses indicate increases to net income.


			Amount Reclassified from AOCI
	Details About AOCI		Three months ended								Nine months ended
			September 30,								September 30,
			2014				2013				2014			2013
	Amortization of defined benefit pension items(1)
	Prior service cost		$	55			$	53			$	165		$	159

	Net loss		654				709				1,963			2,129

	Total before tax		709				762				2,128			2,288

	Tax benefit(2)		(277		)		(298		)		(832		)	(894		)
	Net of tax		432				464				1,296			1,394

	Total reclassification for the period		$	432			$	464			$	1,296		$	1,394

	(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 income statements in other expense, net.
	(2) The tax benefit is included in income tax expense in the condensed consolidated income statements of both IDACORP and Idaho Power.

	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, 2014 and 2013 (in thousands of dollars). Items in parentheses indicate reductions to AOCI.


			Unrealized Gains and Losses on Available-for-Sale Securities				Defined Benefit Pension Items				Total
	Three months ended September 30, 2014:
	Balance at beginning of period		$	—			$	(15,689	)		$	(15,689	)

	Other comprehensive income before reclassifications		—				—				—

	Amounts reclassified out of AOCI		—				432				432

	Net current-period other comprehensive income		—				432				432

	Balance at end of period		$	—			$	(15,257	)		$	(15,257	)

	Nine months ended September 30, 2014:
	Balance at beginning of period		$	—			$	(16,553	)		$	(16,553	)

	Other comprehensive income before reclassifications		—				—				—

	Amounts reclassified out of AOCI		—				1,296				1,296

	Net current-period other comprehensive income		—				1,296				1,296

	Balance at end of period		$	—			$	(15,257	)		$	(15,257	)

	Three months ended September 30, 2013:
	Balance at beginning of period		$	5,576			$	(20,322	)		$	(14,746	)

	Other comprehensive income before reclassifications		843				—				843

	Amounts reclassified out of AOCI		—				464				464

	Net current-period other comprehensive income		843				464				1,307

	Balance at end of period		$	6,419			$	(19,858	)		$	(13,439	)

Nine months ended September 30, 2013:
Balance at beginning of period		$	4,136			$	(21,252	)		$	(17,116	)

Other comprehensive income before reclassifications		2,283				—				2,283

Amounts reclassified out of AOCI		—				1,394				1,394

Net current-period other comprehensive income		2,283				1,394				3,677

Balance at end of period		$	6,419			$	(19,858	)		$	(13,439	)

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES: Organization, Consolidation, Presentation, and Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2014
Accounting Policies [Abstract]	'
Nature of Operations	'
	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 Federal Energy Regulatory Commission (FERC) and the state regulatory commissions of Idaho and Oregon. 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 owned in part by Idaho Power.

	IDACORP’s other wholly-owned subsidiaries include IDACORP Financial Services, Inc. (IFS), an investor in affordable housing and other real estate investments; Ida-West Energy Company (Ida-West), an operator of small hydroelectric generation projects that satisfy the requirements of the Public Utility Regulatory Policies Act of 1978 (PURPA); and IDACORP Energy Services Co. (IESCo), which is the former limited partner of, and current successor by merger to, IDACORP Energy L.P. (IE), a marketer of energy commodities that wound down operations in 2003.
Regulatory Assets and Liabilities, Recognition Criteria	'IDACORP's and Idaho Power's financial statements reflect the effects of the different ratemaking principles followed by the jurisdictions regulating Idaho Power.B 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.B In these instances, the amounts are deferred as regulatory assets or regulatory liabilities on the balance sheet and recorded on the income statement when recovered or returned through rates.B Additionally, regulators can impose regulatory liabilities upon a regulated company for amounts previously collected from customers that are expected to be refunded.
Comparability of Prior Year Financial Data	'
Comparability of Prior Year Financial Data	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, 2014, consolidated results of operations for the three and nine months ended September 30, 2014 and 2013, and consolidated cash flows for the nine months ended September 30, 2014 and 2013. These adjustments are of a normal and recurring nature. These financial statements do not contain the complete detail or footnote disclosure 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, 2013. 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.
Use of Estimates	'
Use of Estimates	Management makes estimates and assumptions when preparing financial statements in conformity with generally accepted accounting principles (GAAP). These estimates and assumptions include those related to rate regulation, retirement benefits, contingencies, litigation, 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 Accounting Pronouncement and Change in Accounting Principle	'
	On January 15, 2014, the Financial Accounting Standards Board issued Accounting Standards Update (ASU) No. 2014-01, Investments-Equity Method and Joint Ventures (Topic 323): Accounting for Investments in Qualified Affordable Housing Projects. This ASU permits an accounting policy election to account for investments in qualified affordable housing projects using the proportional amortization method. For its consolidated financial statements as of and for the year ended December 31, 2013, IDACORP elected early adoption of ASU 2014-01 and changed its accounting for its equity-method investments in qualified affordable housing projects to the proportional amortization method. All prior periods were adjusted to reflect the new method. The standard also requires the recognition of the net investment performance in the financial statements as a component of income tax expense. The new method was elected because IDACORP believes the proportional amortization method more fairly represents the economics of and provides users with a better understanding of the returns from such investments than the equity method of amortization.
Income Tax, Policy	'
Income Tax, Policy	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.
Available-for-sale Securities	'
Available-for-sale Securities	Investments in securities classified as available-for-sale securities are reported at fair value, using either specific identification or average cost to determine the cost for computing gains or losses. Any unrealized gains or losses on available-for-sale securities are included in other comprehensive income.
Derivatives not designated as hedges	'
	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).
Reporting of derivative activity	'
Reporting of derivative activity	Settlement gains and losses on electricity swap contracts are recorded on the income statement in off-system sales 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.
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 has 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.
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 and historic rehabilitation projects, Ida-West’s joint venture investments in small hydroelectric generation projects, the remaining activities of IESCo, and IDACORP’s holding company expenses.

INCOME_TAXES_Level_3_Tables

INCOME TAXES: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2014
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 (in thousands of dollars):


		IDACORP						Idaho Power
		2014			2013			2014			2013
	Nine months ended September 30,
	Income tax at statutory rates (federal and state)	$	75,385		$	85,143		$	74,702		$	84,466

	Capitalized repairs deduction(1)	(19,061		)	(16,129		)	(19,061		)	(16,129		)
	Accounting method changes	(11,075		)	4,583			(11,075		)	4,583

	Affordable housing tax credits	(3,792		)	(4,152		)	—			—

	Affordable housing investment amortization, net of statutory taxes	2,041			739			—			—

	Other(2)	(9,530		)	(7,243		)	(8,667		)	(6,225		)
	Income tax expense	$	33,968		$	62,941		$	35,899		$	66,695

	Effective tax rate	17.6		%	28.9		%	18.8		%	30.9		%
	(1) The "Capitalized repairs deduction" is one of Idaho Power's most significant regulatory flow-through tax adjustments.
	(2) "Other" is primarily comprised of the net tax effect of Idaho Power's remaining regulatory flow-through tax adjustments, which are each listed in the rate reconciliation table in Note 2 to the consolidated financial statements included in IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, 2013.

NOTES_PAYABLE_Level_3_Tables

NOTES PAYABLE: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2014
Shedule of short term debt [Abstract]	'
Schedule of Short-term Debt	'
	Balances (in thousands of dollars) and interest rates of IDACORP’s and Idaho Power's short-term borrowings were as follows at September 30, 2014 and December 31, 2013:


		September 30, 2014									December 31, 2013
		Idaho Power			IDACORP			Total			Idaho Power			IDACORP			Total
	Commercial paper outstanding	$	—		$	31,800		$	31,800		$	—		$	54,750		$	54,750

	Weighted-average annual interest rate	—		%	0.31		%	0.31		%	—		%	0.34		%	0.34		%

EARNINGS_PER_SHARE_Level_3_Tab

EARNINGS PER SHARE: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2014
Earnings Per Share, Basic and Diluted [Abstract]	'
Schedule of Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Table Text Block]	'
	The table below presents the computation of IDACORP’s basic and diluted earnings per share for the three and nine months ended September 30, 2014 and 2013 (in thousands, except for per share amounts).


		Three months ended				Nine months ended
		September 30,				September 30,
		2014		2013		2014		2013
	Numerator:

	Net income attributable to IDACORP, Inc.	$	86,889	$	73,119	$	158,832	$	154,815

	Denominator:

	Weighted-average common shares outstanding - basic	50,129		50,056		50,131		50,051

	Effect of dilutive securities	91		97		53		58

	Weighted-average common shares outstanding - diluted	50,220		50,153		50,184		50,109

	Basic earnings per share	$	1.73	$	1.46	$	3.17	$	3.09

	Diluted earnings per share	$	1.73	$	1.46	$	3.16	$	3.09

BENEFIT_PLANS_Level_3_Tables

BENEFIT PLANS: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2014
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]	'
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, 2014 and 2013 (in thousands of dollars).


		Pension Plan						SMSP				Postretirement
												Benefits
		2014			2013			2014		2013		2014			2013
	Service cost	$	6,323		$	7,839		$	411	$	544	$	252		$	328

	Interest cost	8,853			7,958			964		816		711			659

	Expected return on plan assets	(10,561		)	(9,053		)	—		—		(648		)	(582		)

	Amortization of prior service cost	86			86			55		53		45			(57		)

	Amortization of net loss	978			4,280			654		709		—			25

	Net periodic benefit cost	5,679			11,110			2,084		2,122		360			373

	Adjustments due to the effects of regulation(1)	(1,140		)	(6,274		)	—		—		—			—

	Net periodic benefit cost recognized for financial reporting(1)	$	4,539		$	4,836		$	2,084	$	2,122	$	360		$	373

	(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, income statement recognition of pension plan costs is deferred until costs are recovered through rates.

	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, 2014 and 2013 (in thousands of dollars).


		Pension Plan						SMSP				Postretirement
												Benefits
		2014			2013			2014		2013		2014			2013
	Service cost	$	18,969		$	23,517		$	1,234	$	1,634	$	758		$	986

	Interest cost	26,561			23,873			2,892		2,444		2,131			1,975

	Expected return on plan assets	(31,717		)	(26,816		)	—		—		(1,946		)	(1,746		)

	Amortization of prior service cost	260			260			165		159		137			(172		)

	Amortization of net loss	2,933			12,839			1,963		2,129		—			74

	Net periodic benefit cost	17,006			33,673			6,254		6,366		1,080			1,117

	Adjustments due to the effects of regulation(1)	(3,437		)	(19,168		)	—		—		—			—

	Net periodic benefit cost recognized for financial reporting(1)	$	13,569		$	14,505		$	6,254	$	6,366	$	1,080		$	1,117

	(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, income statement recognition of pension plan costs is deferred until costs are recovered through rates.

INVESTMENTS_IN_DEBT_AND_EQUITY1

INVESTMENTS IN DEBT AND EQUITY SECURITIES: Level 3 (Tables)

9 Months Ended

Sep. 30, 2014

Investments, Debt and Equity Securities [Abstract]

Available-for-sale Securities [Table Text Block]

The following table summarizes investments in equity securities by IDACORP and Idaho Power as of September 30, 2014 and December 31, 2013 (in thousands of dollars).

September 30, 2014

December 31, 2013

Gross

Fair

Gross

Fair

Unrealized

Value

Unrealized

Value

Gain

Loss

Gain

Loss

Available-for-sale securities

—

37,606

—

41,119

DERIVATIVE_FINANCIAL_INSTRUMEN1

DERIVATIVE FINANCIAL INSTRUMENTS: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2014
Summary of Derivative Instruments [Abstract]	'
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block]	'
	The table below presents the gains and losses on derivatives not designated as hedging instruments for the three and nine months ended September 30, 2014 and 2013 (in thousands of dollars).


			Gain/(Loss) on Derivatives Recognized in Income(1)
		Location of Realized Gain/(Loss) on Derivatives Recognized in Income	Three months ended						Nine months ended
			September 30,						September 30,
			2014			2013			2014			2013
	Financial swaps	Off-system sales	$	517		$	(98	)	$	(6,026	)	$	224

	Financial swaps	Purchased power	(2,265		)	496			(785		)	510

	Financial swaps	Fuel expense	239			(705		)	3,907			444

	Financial swaps	Other operations and maintenance	(34		)	12			(44		)	27

	Forward contracts	Off-system sales	112			135			164			135

	Forward contracts	Purchased power	(113		)	(138		)	(163		)	(138		)
	Forward contracts	Fuel expense	53			52			101			131

	(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 [Table Text Block]	'
	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, 2014 and December 31, 2013 (in thousands of dollars).


			Asset Derivatives									Liability Derivatives
		Balance Sheet Location	Gross Fair Value			Amounts Offset			Net Assets			Gross Fair Value			Amounts Offset				Net Liabilities

	September 30, 2014
	Current:

	Financial swaps	Other current assets	$	1,418		$	(154	)	$	1,264		$	154		$	(154	)		$	—

	Financial swaps	Other current liabilities	—			—			—			689			—				689

	Forward contracts	Other current assets	176			—			176			—			—				—

	Forward contracts	Other current liabilities	—			—			—			115			—				115

	Long-term:

	Forward contracts	Other assets	63			—			63			—			—				—

	Total		$	1,657		$	(154	)	$	1,503		$	958		$	(154	)		$	804

	December 31, 2013
	Current:

	Financial swaps	Other current assets	$	1,451		$	(175	)	$	1,276		$	175		$	(175	)		$	—

	Financial swaps	Other current liabilities	373			(373		)	—			1,975			(1,429		)	(1)	546

	Forward contracts	Other current assets	109			—			109			—			—				—

	Forward contracts	Other current liabilities	—			—			—			26			—				26

	Long-term:

	Financial swaps	Other assets	189			(28		)	161			28			(28		)		—

	Forward contracts	Other assets	126			—			126			—			—				—

	Total		$	2,248		$	(576	)	$	1,672		$	2,204		$	(1,632	)		$	572

	(1) Current liability derivative amounts offset include $1.1 million of collateral receivable for the period ended December 31, 2013.
Schedule of Derivative Instruments [Table Text Block]	'
	The table below presents the volumes of derivative commodity forward contracts and swaps outstanding at September 30, 2014 and 2013 (in thousands of units).


			September 30,
	Commodity	Units	2014		2013
	Electricity purchases	MWh	227		382
	Electricity sales	MWh	391		1,064
	Natural gas purchases	MMBtu	5,455		11,929
	Natural gas sales	MMBtu	1,137		1,153
	Diesel purchases	Gallons	222		1,113

FAIR_VALUE_MEASUREMENTS_Level_

FAIR VALUE MEASUREMENTS: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2014
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, 2014 and December 31, 2013 (in thousands of dollars).


		30-Sep-14								December 31, 2013
		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	Assets:

	Derivatives	$	995	$	508	$	—	$	1,503	$	1,437	$	235	$	—	$	1,672

	Money market funds	100		—		—		100		100		—		—		100

	Trading securities: Equity securities	139		—		—		139		1,153		—		—		1,153

	Available-for-sale securities: Equity securities	37,606		—		—		37,606		41,119		—		—		41,119

	Liabilities:
	Derivatives	$	78	$	726	$	—	$	804	$	546	$	26	$	—	$	572

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, 2014 and December 31, 2013, using available market information and appropriate valuation methodologies (in thousands of dollars).


		September 30, 2014				December 31, 2013
		Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
	IDACORP

	Assets:

	Notes receivable(1)	$	3,472	$	3,472	$	3,472	$	3,472

	Liabilities:

	Long-term debt(1)	1,615,441		1,672,271		1,616,322		1,600,248

	Idaho Power

	Liabilities:

	Long-term debt(1)	$	1,615,441	$	1,672,271	$	1,616,322	$	1,600,248


	(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.

SEGMENT_INFORMATION_Level_3_Ta

SEGMENT INFORMATION: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2014
Segment Information [Abstract]	'
Schedule of Segment Reporting Information, by Segment [Table Text Block]	'
	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 of dollars).


		Utility		All		Eliminations			Consolidated
		Operations		Other					Total
	Three months ended September 30, 2014:
	Revenues	$	380,711	$	1,490	$	—		$	382,201

	Net income attributable to IDACORP, Inc.	84,600		2,289		—			86,889

	Total assets as of September 30, 2014	5,408,736		102,904		(13,363		)	5,498,277

	Three months ended September 30, 2013:
	Revenues	$	380,304	$	803	$	—		$	381,107

	Net income attributable to IDACORP, Inc.	70,302		2,817		—			73,119

	Nine months ended September 30, 2014:
	Revenues	$	989,686	$	3,017	$	—		$	992,703

	Net income attributable to IDACORP, Inc.	155,154		3,678		—			158,832

	Nine months ended September 30, 2013:
	Revenues	$	947,529	$	2,455	$	—		$	949,984

	Net income attributable to IDACORP, Inc.	149,331		5,484		—			154,815

CHANGES_IN_ACCUMULATED_OTHER_C1

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME: Level 3 (Tables)	9 Months Ended
	Sep. 30, 2014
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, 2014 and 2013 (in thousands of dollars). Items in parentheses indicate reductions to AOCI.


		Unrealized Gains and Losses on Available-for-Sale Securities			Defined Benefit Pension Items			Total
	Three months ended September 30, 2014:
	Balance at beginning of period	$	—		$	(15,689	)	$	(15,689	)

	Other comprehensive income before reclassifications	—			—			—

	Amounts reclassified out of AOCI	—			432			432

	Net current-period other comprehensive income	—			432			432

	Balance at end of period	$	—		$	(15,257	)	$	(15,257	)

	Nine months ended September 30, 2014:
	Balance at beginning of period	$	—		$	(16,553	)	$	(16,553	)

	Other comprehensive income before reclassifications	—			—			—

	Amounts reclassified out of AOCI	—			1,296			1,296

	Net current-period other comprehensive income	—			1,296			1,296

	Balance at end of period	$	—		$	(15,257	)	$	(15,257	)

	Three months ended September 30, 2013:
	Balance at beginning of period	$	5,576		$	(20,322	)	$	(14,746	)

	Other comprehensive income before reclassifications	843			—			843

	Amounts reclassified out of AOCI	—			464			464

	Net current-period other comprehensive income	843			464			1,307

	Balance at end of period	$	6,419		$	(19,858	)	$	(13,439	)

	Nine months ended September 30, 2013:
	Balance at beginning of period	$	4,136		$	(21,252	)	$	(17,116	)

	Other comprehensive income before reclassifications	2,283			—			2,283

	Amounts reclassified out of AOCI	—			1,394			1,394

	Net current-period other comprehensive income	2,283			1,394			3,677

	Balance at end of period	$	6,419		$	(19,858	)	$	(13,439	)

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, 2014 and 2013 (in thousands of dollars). Items in parentheses indicate increases to net income.


		Amount Reclassified from AOCI
	Details About AOCI	Three months ended						Nine months ended
		September 30,						September 30,
		2014			2013			2014			2013
	Amortization of defined benefit pension items(1)
	Prior service cost	$	55		$	53		$	165		$	159

	Net loss	654			709			1,963			2,129

	Total before tax	709			762			2,128			2,288

	Tax benefit(2)	(277		)	(298		)	(832		)	(894		)
	Net of tax	432			464			1,296			1,394

	Total reclassification for the period	$	432		$	464		$	1,296		$	1,394

	(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 income statements in other expense, net.
	(2) The tax benefit is included in income tax expense in the condensed consolidated income statements of both IDACORP and Idaho Power.

INCOME_TAXES_Level_4_Details

INCOME TAXES: Level 4 (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013
Income Tax Expense [Line Items]	'	'	'		'
Income tax at statutory rates (federal and state)	'	'	$75,385		$85,143
Capitalized repairs deduction	'	'	-19,061	[1]	-16,129	[1]
Accounting method changes	'	'	-11,075		4,583
Affordable housing tax credits	'	'	-3,792		-4,152
Affordable housing investment amortization, net of statutory taxes	'	'	2,041		739
Other	'	'	-9,530	[2]	-7,243	[2]
Income Tax Expense	10,869	33,222	33,968		62,941
Effective tax rate	'	'	17.60%		28.90%
Idaho Power Company	'	'	'		'
Income Tax Expense [Line Items]	'	'	'		'
Income tax at statutory rates (federal and state)	'	'	74,702		84,466
Capitalized repairs deduction	'	'	-19,061	[1]	-16,129	[1]
Accounting method changes	'	'	-11,075		4,583
Other	'	'	-8,667	[2]	-6,225	[2]
Income Tax Expense	$11,509	$34,965	$35,899		$66,695
Effective tax rate	'	'	18.80%		30.90%

[1]	The "Capitalized repairs deduction" is one of Idaho Power's most significant regulatory flow-through tax adjustments.
[2]	"Other" is primarily comprised of the net tax effect of Idaho Power's remaining regulatory flow-through tax adjustments, which are each listed in the rate reconciliation table in Note 2 to the consolidated financial statements included in IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, 2013.

REGULATORY_MATTERS_Level_4_Det

REGULATORY MATTERS: Level 4 (Details) (USD $)

0 Months Ended

Jan. 01, 2012

Sep. 30, 2014

Dec. 31, 2013

Jan. 01, 2012

Jun. 01, 2014

Jun. 01, 2013

Dec. 31, 2013

Jun. 01, 2014

Jun. 01, 2013

Jun. 01, 2012

Jul. 01, 2014

Jan. 01, 2012

Jul. 01, 2012

Jun. 01, 2014

Mar. 01, 2012

Oct. 01, 2012

Oct. 30, 2014

Settlement Stipulation - Investment Tax Credits and Idaho Sharing Mechanism

Idaho Power Cost Adjustment Mechanism; Update to Base Level Net Power Supply Expense

Annual Idaho Fixed Cost Adjustment Filing

IPUC Review of Rate Adjustment Mechanisms

IDAHO

OREGON

Subsequent Event [Member]

Idaho and Oregon General Rate Cases and Base Rate Adjustments

Cost Recovery for Langley Gulch Power Plant

Idaho Power Cost Adjustment Mechanism; Update to Base Level Net Power Supply Expense

Idaho and Oregon General Rate Cases and Base Rate Adjustments

Cost Recovery for Langley Gulch Power Plant

Settlement Stipulation - Investment Tax Credits and Idaho Sharing Mechanism

Rate Case

Authorized Rate of Return in Rate Case

7.86%

7.76%

Total Retail Rate Base

$2,360,000,000

Approved Rate Increase (Decrease), Amount

11,100,000

140,400,000

6,000,000

34,000,000

58,100,000

106,000,000

1,800,000

3,000,000

Public Utilities, Approved Return on Equity, Percentage

9.90%

Increase (Decrease) in Rate Base

335,900,000

Authorized Return on Equity in Rate Case, Minimum

9.50%

Authorized Return on Equity in Rate Case, Mid-point

10.00%

Authorized Return on Equity in Rate Case, Maximum

10.50%

Investment Tax Credits, Maximum, in Rate Case

45,000,000

Period of Current ADITC Stipulation

'3 years

Percentage to be Shared with Customers

75.00%

Percentage to be Shared with Entity

25.00%

Regulatory Liabilities

4,900,000

7,600,000

20,000,000

Investment Tax Credits Maximum In One Year In Rate Case

25,000,000

Percent To Be Shared With Customers, Power Cost Adjustment

50.00%

Percent To Be Shared With Customers, Pension Balancing

25.00%

Annual fixed cost adjustment mechanism deferral

14,900,000

8,900,000

10,300,000

PCA Rate Review

$14,200,000

NOTES_PAYABLE_Level_4_Details

NOTES PAYABLE: Level 4 (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
Short-term borrowings:	'	'
Commercial paper outstanding	$31,800,000	$54,750,000
Weighted-average annual interest rate	0.31%	0.34%
IDACORP	'	'
Short-term borrowings:	'	'
Commercial paper outstanding	31,800,000	54,750,000
Weighted-average annual interest rate	0.31%	0.34%
Credit facility:	'	'
Amount outstanding on credit facility	0	'
Idaho Power Company	'	'
Short-term borrowings:	'	'
Commercial paper outstanding	0	0
Weighted-average annual interest rate	0.00%	0.00%
Credit facility:	'	'
Amount outstanding on credit facility	0	'
Regulatory authority to incur short-term indebtedness	$450,000,000	'

COMMON_STOCK_Level_4_Details

COMMON STOCK: Level 4 (Details) (USD $)	9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2014
Idaho Power Company	'
Shareholders' equity	'
Maximum leverage ratio requirement	0.65
Ratio of Indebtedness to Net Capital	0.47
Dividend Distribution Restriction Amount	$942
Dividend Distribution Restriction Threshold	0.35
Ratio of total Capital to total capital and long-term debt	0.53
Preferred Stock, Shares Outstanding	0
IDACORP	'
Shareholders' equity	'
Stock Issued During Period, Shares, New Issues	74,049
Maximum leverage ratio requirement	0.65
Ratio of Indebtedness to Net Capital	0.46
Dividend Distribution Restriction Amount	$1,100
IDACORP \| Continuous equity program	'
Shareholders' equity	'
Stock Issued During Period, Shares, New Issues	0
Remaining shares available under sales agency agreement	3,000,000

EARNINGS_PER_SHARE_Level_4_Det

EARNINGS PER SHARE: Level 4 (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Numerator:	'	'	'	'
Net income attributable to IDACORP, Inc.	$86,889	$73,119	$158,832	$154,815
Denominator:	'	'	'	'
Weighted Average Common Shares Outstanding - Basic	50,129	50,056	50,131	50,051
Options	91	97	53	58
Weighted Average Common Shares Outstanding - Diluted	50,220	50,153	50,184	50,109
Earnings Attributable to IDACORP, Inc. - Basic (in dollars per share)	$1.73	$1.46	$3.17	$3.09
Earnings Attributable to IDACORP, Inc. - Diluted (in dollars per share)	$1.73	$1.46	$3.16	$3.09

COMMITMENTS_Level_4_Details

COMMITMENTS: Level 4 (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014
	MWh
Idaho Power Company	'
Guarantor Obligations	'
IERCo ownership interest in BCC	33.00%
IERCo guarantee of BCC reclamation obligation	$70
Long-term Purchase Commitment	'
Nameplate Capacity (in MWs)	176
Estimated purchase obligation	659
Nameplate capacity, subject to approval (in MWs)	120
Estimated purchase obligation, subject to approval	449
Bridger Coal Company	'
Guarantor Obligations	'
Guarantor Obligations Total Reclamation Trust Fund	66
Distribution from Reclamation Trust Fund	$10

CONTINGENCIES_Level_4_Details

CONTINGENCIES: Level 4 (Details) (USD $)	Sep. 30, 2014
Loss Contingencies [Line Items]	'
Loss Contingency, Estimate of Possible Loss	$0

BENEFIT_PLANS_Level_4_Details

BENEFIT PLANS: Level 4 (Details) (USD $)	3 Months Ended				9 Months Ended
BENEFIT PLANS: Level 4 (Details) (USD $)	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Pension Plan	'		'		'		'
Defined Benefit Plan Disclosure	'		'		'		'
Service cost	$6,323,000		$7,839,000		$18,969,000		$23,517,000
Interest cost	8,853,000		7,958,000		26,561,000		23,873,000
Expected return on plan assets	-10,561,000		-9,053,000		-31,717,000		-26,816,000
Amortization of prior service cost	86,000		86,000		260,000		260,000
Amortization of net loss	978,000		4,280,000		2,933,000		12,839,000
Net periodic benefit cost	5,679,000		11,110,000		17,006,000		33,673,000
Adjustments due to the effects of regulation	-1,140,000	[1]	-6,274,000	[1]	-3,437,000	[1]	-19,168,000	[1]
Net periodic benefit cost recognized for financial reporting	4,539,000	[1]	4,836,000	[1]	13,569,000	[1]	14,505,000	[1]
Contributions made to the defined benefit pension plan	'		'		30,000,000		'
Senior Management Security Plan	'		'		'		'
Defined Benefit Plan Disclosure	'		'		'		'
Service cost	411,000		544,000		1,234,000		1,634,000
Interest cost	964,000		816,000		2,892,000		2,444,000
Expected return on plan assets	0		0		0		0
Amortization of prior service cost	55,000		53,000		165,000		159,000
Amortization of net loss	654,000		709,000		1,963,000		2,129,000
Net periodic benefit cost	2,084,000		2,122,000		6,254,000		6,366,000
Net periodic benefit cost recognized for financial reporting	2,084,000		2,122,000		6,254,000		6,366,000
Postretirement Benefits	'		'		'		'
Defined Benefit Plan Disclosure	'		'		'		'
Service cost	252,000		328,000		758,000		986,000
Interest cost	711,000		659,000		2,131,000		1,975,000
Expected return on plan assets	-648,000		-582,000		-1,946,000		-1,746,000
Amortization of prior service cost	45,000		-57,000		137,000		-172,000
Amortization of net loss	0		25,000		0		74,000
Net periodic benefit cost	360,000		373,000		1,080,000		1,117,000
Net periodic benefit cost recognized for financial reporting	$360,000		$373,000		$1,080,000		$1,117,000

[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, income statement recognition of pension plan costs is deferred until costs are recovered through rates.

INVESTMENTS_IN_DEBT_AND_EQUITY2

INVESTMENTS IN DEBT AND EQUITY SECURITIES: Level 4 (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Summary of investments in debt and equity securities	'	'	'
Available-for-sale Securities, Gross Unrealized Gain	$0	'	$0
Available-for-sale Securities, Gross Unrealized Loss	0	'	0
Available-for-sale Securities, Fair Value	37,606,000	'	41,119,000
Available-for-sale Securities, Gross Realized Gains (Losses), Sale Proceeds	$0	$0	'

Derivative_Instruments_Fair_Va

Derivative Instruments Fair Value and Offsets Table (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$1,657,000	$2,248,000
Derivative Asset, Fair Value, Gross Liability	-154,000	-576,000
Derivative Asset, Fair Value, Amount Offset Against Collateral	1,503,000	1,672,000
Derivative Liability, Fair Value, Gross Liability	958,000	2,204,000
Derivative Liability, Fair Value, Gross Asset	-154,000	-1,632,000
Derivative Liability, Fair Value, Amount Offset Against Collateral	804,000	572,000
Derivative Asset, Collateral, Obligation to Return Cash, Offset	'	1,100,000
Financial Swaps \| Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	1,418,000	1,451,000
Derivative Asset, Fair Value, Gross Liability	-154,000	-175,000
Derivative Asset, Fair Value, Amount Offset Against Collateral	1,264,000	1,276,000
Derivative Liability, Fair Value, Gross Liability	154,000	175,000
Derivative Liability, Fair Value, Gross Asset	-154,000	-175,000
Financial Swaps \| Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	'	373,000
Derivative Asset, Fair Value, Gross Liability	'	-373,000
Derivative Liability, Fair Value, Gross Liability	689,000	1,975,000
Derivative Liability, Fair Value, Gross Asset	'	-1,429,000	[1]
Derivative Liability, Fair Value, Amount Offset Against Collateral	689,000	546,000
Financial Swaps \| Other Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	'	189,000
Derivative Asset, Fair Value, Gross Liability	'	-28,000
Derivative Asset, Fair Value, Amount Offset Against Collateral	'	161,000
Derivative Liability, Fair Value, Gross Liability	'	28,000
Derivative Liability, Fair Value, Gross Asset	'	-28,000
Forward contracts \| Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	176,000	109,000
Derivative Asset, Fair Value, Amount Offset Against Collateral	176,000	109,000
Forward contracts \| Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	115,000	26,000
Derivative Liability, Fair Value, Amount Offset Against Collateral	115,000	26,000
Forward contracts \| Other Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	63,000	126,000
Derivative Asset, Fair Value, Amount Offset Against Collateral	$63,000	$126,000

[1]	Current liability derivative amounts offset include $1.1 million of collateral receivable for the period ended DecemberB 31, 2013.

Derivative_Instruments_Gains_L

Derivative Instruments Gains (Loss) on Derivatives Recognized in Income (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Financial Swaps \| Off-system sales	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Loss on Derivative	'	($98)	($6,026)	'
Derivative, Gain on Derivative	517	'	'	224
Financial Swaps \| Purchased power	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Loss on Derivative	-2,265	'	-785	'
Derivative, Gain on Derivative	'	496	'	510
Financial Swaps \| Fuel expense	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Loss on Derivative	'	-705	'	'
Derivative, Gain on Derivative	239	'	3,907	444
Financial Swaps \| Other operations and maintenance	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Loss on Derivative	-34	'	-44	'
Derivative, Gain on Derivative	'	12	'	27
Forward contracts \| Off-system sales	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain on Derivative	112	135	164	135
Forward contracts \| Purchased power	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Loss on Derivative	-113	-138	-163	-138
Forward contracts \| Fuel expense	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain on Derivative	$53	$52	$101	$131

Derivative_Commodities_and_Dis

Derivative Commodities and Disclosures (Details) (USD $)	Sep. 30, 2014	Sep. 30, 2013
In Millions, unless otherwise specified	MWh	MWh
Derivative	'	'
Derivatives in a net liability position	0.7	'
Collateral Already Posted, Aggregate Fair Value	0.1	'
Additional Collateral, Aggregate Fair Value	6.2	'
Electricity (MWh) \| Long [Member]	'	'
Derivative	'	'
Derivative, Nonmonetary Notional Amount	227,000	382,000
Electricity (MWh) \| Short [Member]	'	'
Derivative	'	'
Derivative, Nonmonetary Notional Amount	391,000	1,064,000
Natural Gas (MMBTU) \| Long [Member]	'	'
Derivative	'	'
Derivative, Nonmonetary Notional Amount	5,455,000	11,929,000
Natural Gas (MMBTU) \| Short [Member]	'	'
Derivative	'	'
Derivative, Nonmonetary Notional Amount	1,137,000	1,153,000
Diesel Fuel (Gallons) \| Long [Member]	'	'
Derivative	'	'
Derivative, Nonmonetary Notional Amount	222,000	1,113,000

FAIR_VALUE_MEASUREMENTS_Level_1

FAIR VALUE MEASUREMENTS: Level 4 (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair Value, Assets, Level 1 to Level 2 Transfers, Amount	$0	$0
Derivative Asset	1,503,000	1,672,000
Cash and Cash Equivalents, Fair Value Disclosure	100,000	100,000
Trading Securities	139,000	1,153,000
Available-for-sale Securities	37,606,000	41,119,000
Derivative Liability	804,000	572,000
Fair Value, Inputs, Level 1 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative Asset	995,000	1,437,000
Cash and Cash Equivalents, Fair Value Disclosure	100,000	100,000
Trading Securities	139,000	1,153,000
Available-for-sale Securities	37,606,000	41,119,000
Derivative Liability	78,000	546,000
Fair Value, Inputs, Level 2 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative Asset	508,000	235,000
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Trading Securities	0	0
Available-for-sale Securities	0	0
Derivative Liability	726,000	26,000
Fair Value, Inputs, Level 3 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative Asset	0	0
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Trading Securities	0	0
Available-for-sale Securities	0	0
Derivative Liability	$0	$0

FAIR_VALUE_MEASUREMENTS_Fair_V

FAIR VALUE MEASUREMENTS: Fair Value, by Balance Sheet Grouping (Details) (USD $)	Sep. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified	Sep. 30, 2014		Dec. 31, 2013
Reported Value Measurement [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Notes Receivable, Fair Value Disclosure	$3,472	[1]	$3,472	[1]
Loans Payable, Fair Value Disclosure	1,615,441	[1]	1,616,322	[1]
Reported Value Measurement [Member] \| Idaho Power Company	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Loans Payable, Fair Value Disclosure	1,615,441	[1]	1,616,322	[1]
Estimate of Fair Value Measurement [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Notes Receivable, Fair Value Disclosure	3,472	[1]	3,472	[1]
Loans Payable, Fair Value Disclosure	1,672,271	[1]	1,600,248	[1]
Estimate of Fair Value Measurement [Member] \| Idaho Power Company	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Loans Payable, Fair Value Disclosure	$1,672,271	[1]	$1,600,248	[1]

[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.

SEGMENT_INFORMATION_Level_4_De

SEGMENT INFORMATION: Level 4 (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Segment Reporting Information	'	'	'	'	'
Revenues	$382,201	$381,107	$992,703	$949,984	'
Income (loss) attributable to IDACORP, Inc.	87,234	73,104	159,115	154,784	'
Net Income Attributable to IDACORP, Inc.	86,889	73,119	158,832	154,815	'
Total assets	5,498,277	'	5,498,277	'	5,364,563
Idaho Power Company	'	'	'	'	'
Segment Reporting Information	'	'	'	'	'
Revenues	380,711	380,304	989,686	947,529	'
Income (loss) attributable to IDACORP, Inc.	84,600	70,302	155,154	149,331	'
Total assets	5,408,736	'	5,408,736	'	'
All Other	'	'	'	'	'
Segment Reporting Information	'	'	'	'	'
Revenues	1,490	803	3,017	2,455	'
Income (loss) attributable to IDACORP, Inc.	2,289	2,817	3,678	5,484	'
Total assets	102,904	'	102,904	'	'
Eliminations	'	'	'	'	'
Segment Reporting Information	'	'	'	'	'
Revenues	0	0	0	0	'
Income (loss) attributable to IDACORP, Inc.	0	0	0	0	'
Total assets	-13,363	'	-13,363	'	'
Idaho Power Company	'	'	'	'	'
Segment Reporting Information	'	'	'	'	'
IERCo's ownership percentage in Bridger Coal Company	'	'	33.00%	'	'
Income (loss) attributable to IDACORP, Inc.	84,600	70,302	155,154	149,331	'
Total assets	$5,409,463	'	$5,409,463	'	$5,266,411

CHANGES_IN_ACCUMULATED_OTHER_C2

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME: Level 4 (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Reclassification out of Accumulated Other Comprehensive Income	'		'		'		'
Amortization of prior service cost	$55	[1]	$53	[1]	$165	[1]	$159	[1]
Amortization of net loss	654	[1]	709	[1]	1,963	[1]	2,129	[1]
Total reclassification, before tax - pension and postretirement benefits	709		762		2,128		2,288
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	-277	[2]	-298	[2]	-832	[2]	-894	[2]
Total reclassification, net of tax - pension and postretirement benfits	432		464		1,296		1,394
Reclassifications	432		464		1,296		1,394
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]	'		'		'		'
AOCI - Beginning Balance	-15,689		-14,746		-16,553		-17,116
Before Reclassifications	0		843		0		2,283
Reclassifications	432		464		1,296		1,394
Other Comprehensive Income (Loss)	432		1,307		1,296		3,677
AOCI - Ending Balance	-15,257		-13,439		-15,257		-13,439
Accumulated Unrealized Gains and Losses on Available-for-Sale Securities	'		'		'		'
Reclassification out of Accumulated Other Comprehensive Income	'		'		'		'
Reclassifications	0		0		0		0
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]	'		'		'		'
AOCI - Beginning Balance	0		5,576		0		4,136
Before Reclassifications	0		843		0		2,283
Reclassifications	0		0		0		0
Other Comprehensive Income (Loss)	0		843		0		2,283
AOCI - Ending Balance	0		6,419		0		6,419
Accumulated Defined Benefit Pension Items	'		'		'		'
Reclassification out of Accumulated Other Comprehensive Income	'		'		'		'
Reclassifications	432		464		1,296		1,394
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]	'		'		'		'
AOCI - Beginning Balance	-15,689		-20,322		-16,553		-21,252
Before Reclassifications	0		0		0		0
Reclassifications	432		464		1,296		1,394
Other Comprehensive Income (Loss)	432		464		1,296		1,394
AOCI - Ending Balance	($15,257)		($19,858)		($15,257)		($19,858)

[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 income statements in other expense, net.
[2]	The tax benefit is included in income tax expense in the condensed consolidated income statements of both IDACORP and Idaho Power.