IDACORP (IDA) 10-Q 1 May 14 2014 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information (DEI) Document	3 Months Ended
	Mar. 31, 2014	Apr. 25, 2014
Document Information	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	31-Mar-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q1	'
Trading Symbol	'IDA	'
Entity Registrant Name	'IDACORP INC.	'
Entity Central Index Key	'0001057877	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	50,305,042
Entity Tax Identification Number	'820505802	'
Idaho Power Company	'	'
Document Information	'	'
Entity Registrant Name	'Idaho Power Company	'
Entity Central Index Key	'0000049648	'
Entity Filer Category	'Non-accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	39,150,812
Entity Tax Identification Number	'820130980	'

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Income Statement (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Operating Revenues:	'	'
General business	$244,832	$232,219
Off-system sales	29,210	15,900
Other revenues	18,278	16,249
Total electric utility revenues	292,320	264,368
Other Revenue, Net	399	560
Total operating revenues	292,719	264,928
Operating Expenses:	'	'
Purchased power	43,796	42,857
Fuel expense	55,327	49,166
Power cost adjustment	15,023	-14,711
Other operations and maintenance	80,521	79,785
Energy efficiency programs	4,724	4,470
Depreciation	32,875	31,910
Taxes other than income taxes	8,105	8,172
Total electric utility expenses	240,371	201,649
Other	3,770	3,846
Total operating expenses	244,141	205,495
Operating Income	48,578	59,433
Other Income (Expense):	'	'
Allowance for equity funds used during construction	4,079	3,615
Earnings (Losses) of Unconsolidated Equity-Method Investments	983	2,700
Other (expense) income, net	2,288	826
Interest Expense:	'	'
Interest on long-term debt	20,141	19,669
Other interest	1,859	1,752
Allowance for borrowed funds used during construction	-1,964	-1,931
Total interest expense, net	20,036	19,490
Income Before Income Taxes	35,892	47,084
Income Tax Expense (Benefit)	8,707	12,043
Net Income	27,185	35,041
Adjustment for (income) loss attributable to noncontrolling interests	219	153
Net Income Attributable to IDACORP, Inc.	27,404	35,194
Weighted Average Common Shares Outstanding - Basic (000’s)	50,131	50,039
Weighted Average Common Shares Outstanding - Diluted (000’s)	50,175	50,064
Earnings Per Share of Common Stock:	'	'
Earnings Attributable to IDACORP, Inc. - Basic (in dollars per share)	$0.55	$0.70
Earnings Attributable to IDACORP, Inc. - Diluted (in dollars per share)	$0.55	$0.70
Dividends Declared Per Share of Common Stock	$0.43	$0.38
Idaho Power Company	'	'
Operating Revenues:	'	'
General business	244,832	232,219
Off-system sales	29,210	15,900
Other revenues	18,278	16,249
Total electric utility revenues	292,320	264,368
Operating Expenses:	'	'
Purchased power	43,796	42,857
Fuel expense	55,327	49,166
Power cost adjustment	15,023	-14,711
Other operations and maintenance	80,521	79,785
Energy efficiency programs	4,724	4,470
Depreciation	32,875	31,910
Taxes other than income taxes	8,105	8,172
Total electric utility expenses	240,371	201,649
Operating Income	51,949	62,719
Other Income (Expense):	'	'
Allowance for equity funds used during construction	4,079	3,615
Earnings (Losses) of Unconsolidated Equity-Method Investments	1,246	2,634
Other (expense) income, net	-428	-2,158
Total other income	4,897	4,091
Interest Expense:	'	'
Interest on long-term debt	20,141	19,669
Other interest	1,798	1,648
Allowance for borrowed funds used during construction	-1,964	-1,931
Total interest expense, net	19,975	19,386
Income Before Income Taxes	36,871	47,424
Income Tax Expense (Benefit)	8,971	13,378
Net Income	$27,900	$34,046

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Comprehensive Income (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Net Income	$27,185	$35,041
Other Comprehensive Income:	'	'
Net unrealized holding gains (losses) arising during the period, net of tax	0	1,181
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	432	465
Total Comprehensive Income	27,617	36,687
Comprehensive (income) loss attributable to noncontrolling interests	219	153
Comprehensive Income Attributable to IDACORP, Inc.	27,836	36,840
Idaho Power Company	'	'
Net Income	27,900	34,046
Other Comprehensive Income:	'	'
Net unrealized holding gains (losses) arising during the period, net of tax	0	1,181
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	432	465
Total Comprehensive Income	$28,332	$35,692

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Comprehensive Income (Parenthetical) (Parentheticals) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, Tax	$0	$758
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Tax	278	298
Idaho Power Company	'	'
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, Tax	0	758
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Tax	$278	$298

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets Statement (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current Assets:	'	'
Cash and cash equivalents	$88,265	$78,162
Receivables:	'	'
Customer	98,431	97,873
Other	16,641	15,274
Taxes receivable	0	156
Accrued unbilled revenues	46,937	63,507
Materials and supplies (at average cost)	55,328	53,643
Fuel stock (at average cost)	35,177	41,546
Prepayments	14,790	15,338
Deferred income taxes	32,868	46,874
Current regulatory assets	102,836	61,837
Other	2,439	2,401
Total current assets	493,712	476,611
Investments	157,502	159,072
Property, Plant and Equipment:	'	'
Utility plant in service	5,100,204	5,080,402
Accumulated provision for depreciation	-1,783,443	-1,766,680
Utility plant in service - net	3,316,761	3,313,722
Construction work in progress	351,566	327,000
Utility plant held for future use	7,097	7,090
Other property, net of accumulated depreciation	17,437	17,229
Property, plant and equipment - net	3,692,861	3,665,041
Other Assets:	'	'
American Falls and Milner water rights	14,479	15,803
Company-owned life insurance	19,494	22,037
Regulatory assets	934,966	978,234
Long-term receivables	6,133	4,811
Other	42,245	42,954
Total other assets	1,017,317	1,063,839
Total	5,361,392	5,364,563
Current Liabilities:	'	'
Current maturities of long-term debt	1,064	1,064
Notes payable	47,300	54,750
Accounts payable	72,085	91,519
Taxes accrued	38,051	13,302
Interest accrued	24,944	22,764
Accrued compensation	27,796	38,510
Current regulatory liabilities	13,551	10,684
Other	22,054	17,779
Total current liabilities	246,845	250,372
Other Liabilities:	'	'
Deferred income taxes	957,777	969,593
Regulatory liabilities	381,754	375,873
Pension and other postretirement benefits	249,537	244,627
Other	49,797	54,100
Total other liabilities	1,638,865	1,644,193
Long-Term Debt	1,614,256	1,615,258
Commitments and Contingencies	'	'
Equity:	'	'
Common stock	840,472	839,750
Retained earnings	1,033,225	1,027,461
Accumulated other comprehensive loss	-16,121	-16,553
Treasury stock	-21	-8
Total IDACORP, Inc. shareholders’ equity	1,857,555	1,850,650
Noncontrolling interests	3,871	4,090
Total equity	1,861,426	1,854,740
Total	5,361,392	5,364,563
Idaho Power Company	'	'
Current Assets:	'	'
Cash and cash equivalents	84,570	66,535
Receivables:	'	'
Customer	98,431	97,873
Other	16,499	14,290
Accrued unbilled revenues	46,937	63,507
Materials and supplies (at average cost)	55,328	53,643
Fuel stock (at average cost)	35,177	41,546
Prepayments	14,651	15,204
Deferred income taxes	0	12,386
Current regulatory assets	102,836	61,837
Other	2,439	2,401
Total current assets	456,868	429,222
Investments	131,695	131,520
Property, Plant and Equipment:	'	'
Utility plant in service	5,100,204	5,080,402
Accumulated provision for depreciation	-1,783,443	-1,766,680
Utility plant in service - net	3,316,761	3,313,722
Construction work in progress	351,566	327,000
Utility plant held for future use	7,097	7,090
Property, plant and equipment - net	3,675,424	3,647,812
Other Assets:	'	'
American Falls and Milner water rights	14,479	15,803
Company-owned life insurance	19,494	22,037
Regulatory assets	934,966	978,234
Other	42,432	41,783
Total other assets	1,011,371	1,057,857
Total	5,275,358	5,266,411
Current Liabilities:	'	'
Current maturities of long-term debt	1,064	1,064
Accounts payable	71,330	90,529
Accounts payable to affiliates	688	1,158
Taxes accrued	40,615	14,031
Interest accrued	24,944	22,764
Accrued compensation	27,670	38,297
Current regulatory liabilities	13,551	10,684
Other	23,187	17,095
Total current liabilities	203,049	195,622
Other Liabilities:	'	'
Deferred income taxes	1,047,584	1,058,734
Regulatory liabilities	381,754	375,873
Pension and other postretirement benefits	249,537	244,627
Other	48,508	52,265
Total other liabilities	1,727,383	1,731,499
Long-Term Debt	1,614,256	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	938,753	932,547
Accumulated other comprehensive loss	-16,121	-16,553
Total equity	1,730,670	1,724,032
Total capitalization	3,344,926	3,339,290
Total	$5,275,358	$5,266,411

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (Parentheticals) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified
Allowance for Doubtful Accounts Receivable, Current	$2,518	$2,349
Allowance for Doubtful Other Receivables, Current	161	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	2,470	718
Idaho Power Company	'	'
Allowance for Doubtful Accounts Receivable, Current	2,518	2,349
Allowance for Doubtful Other Receivables, Current	$161	$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 $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Operating Activities:	'	'
Net Income	$27,185	$35,041
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	33,888	33,195
Deferred income taxes and investment tax credits	-9,928	11,410
Changes in regulatory assets and liabilities	21,479	-13,681
Pension and Other Postretirement Benefit Expense	6,998	7,673
Contributions to pension and postretirement benefit plans	-1,349	-1,322
(Earnings) losses of unconsolidated equity-method investments	-983	-2,700
Distributions from unconsolidated equity-method investments	594	7,631
Allowance for equity funds used during construction	-4,079	-3,615
Other non-cash adjustments to net income, net	771	419
Change in:	'	'
Accounts Receivable	-2,842	-15,158
Accounts payable and other accrued liabilities	-27,097	-32,519
Taxes accrued/receivable	25,811	7,840
Other current assets	21,686	21,577
Other current liabilities	7,531	4,993
Other assets	1,748	-1,089
Other liabilities	-4,475	-5,716
Net cash provided by operating activities	96,938	53,979
Investing Activities:	'	'
Additions to property, plant and equipment	-59,192	-51,976
Proceeds from Sale of Intangible Assets	1,274	0
Distributions from affordable housing investments	795	1,448
Other	1,836	1,837
Net cash used in investing activities	-55,287	-48,691
Financing Activities:	'	'
Retirement of long-term debt	-1,064	-1,064
Dividends on common stock	-21,879	-19,303
Net change in short-term borrowings	-7,450	14,050
Issuance of common stock	160	255
Acquisition of treasury stock	-2,464	-2,121
Other	1,149	828
Net cash used in financing activities	-31,548	-7,355
Net increase (decrease) in cash and cash equivalents	10,103	-2,067
Cash and cash equivalents at beginning of the period	78,162	26,527
Cash and cash equivalents at end of the period	88,265	24,460
Supplemental Disclosure of Cash Flow Information:	'	'
Income taxes	20	0
Interest (net of amount capitalized)	17,223	17,014
Non-cash investing activities:	'	'
Additions to property, plant and equipment in accounts payable	19,846	17,646
Idaho Power Company	'	'
Operating Activities:	'	'
Net Income	27,900	34,046
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	33,745	33,047
Deferred income taxes and investment tax credits	-10,489	11,753
Changes in regulatory assets and liabilities	21,479	-13,681
Pension and Other Postretirement Benefit Expense	6,991	7,673
Contributions to pension and postretirement benefit plans	-1,341	-1,322
(Earnings) losses of unconsolidated equity-method investments	-1,246	-2,634
Distributions from unconsolidated equity-method investments	594	6,856
Allowance for equity funds used during construction	-4,079	-3,615
Other non-cash adjustments to net income, net	71	-226
Change in:	'	'
Accounts Receivable	-4,470	-17,671
Accounts payable and other accrued liabilities	-27,075	-32,389
Taxes accrued/receivable	27,694	11,321
Other current assets	21,691	21,610
Other current liabilities	7,588	4,988
Other assets	1,747	-1,089
Other liabilities	-3,928	-5,346
Net cash provided by operating activities	96,872	53,321
Investing Activities:	'	'
Additions to property, plant and equipment	-59,190	-51,976
Proceeds from Sale of Intangible Assets	1,274	0
Other	1,837	1,837
Net cash used in investing activities	-56,079	-50,139
Financing Activities:	'	'
Retirement of long-term debt	-1,064	-1,064
Dividends on common stock	-21,694	-19,113
Net change in short-term borrowings	0	16,600
Other	0	-14
Net cash used in financing activities	-22,758	-3,591
Net increase (decrease) in cash and cash equivalents	18,035	-409
Cash and cash equivalents at beginning of the period	66,535	17,251
Cash and cash equivalents at end of the period	84,570	16,842
Supplemental Disclosure of Cash Flow Information:	'	'
Income taxes	-1,040	-2,491
Interest (net of amount capitalized)	17,162	16,910
Non-cash investing activities:	'	'
Additions to property, plant and equipment in accounts payable	$19,846	$17,646

Condensed_Consolidated_Stateme4

Condensed Consolidated Statements of Equity (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Common Stock [Abstract]	'	'
Balance at beginning of period	$839,750	$834,922
Common stock issued	160	255
Other common stock changes	562	241
Balance at end of period	840,472	835,418
Retained Earnings	'	'
Balance at beginning of period	1,027,461	923,981
Net Income Attributable to IDACORP, Inc.	27,404	35,194
Common stock dividends	-21,640	-19,092
Balance at end of period	1,033,225	940,083
Accumulated Other Comprehensive (Loss) Income	'	'
AOCI - Beginning Balance	-16,553	-17,116
Net unrealized losses (gains)	0	1,181
Unfunded pension liability adjustment (net of tax)	432	465
AOCI - Ending Balance	-16,121	-15,470
Treasury Stock	'	'
Balance at beginning of period	-8	-21
Issued	2,451	2,126
Acquired	-2,464	-2,121
Balance at end of period	-21	-16
Total IDACORP, Inc. shareholders’ equity at end of period	1,857,555	1,760,015
Noncontrolling Interests	'	'
Balance at beginning of period	4,090	4,213
Net (loss) income attributable to noncontrolling interests	-219	-153
Balance at end of period	3,871	4,060
Total equity at end of period	$1,861,426	$1,764,075

Condensed_Consolidated_Stateme5

Condensed Consolidated Statements of Equity (Parenthetical) (Parentheticals) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Dividends Declared Per Share of Common Stock	$0.43	$0.38

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:	3 Months Ended
	Mar. 31, 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 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 March 31, 2014, consolidated results of operations for the three months ended March 31, 2014 and 2013, and consolidated cash flows for the three months ended March 31, 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.  As a result, 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 thus changed its accounting for its equity-method investments in qualified affordable housing projects to the proportional amortization method. All prior periods were properly 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 (benefit). 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:	3 Months Ended
	Mar. 31, 2014
Income Taxes [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, or method changes. Discrete events are recorded in the interim period in which they occur. 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 three months ended March 31 (in thousands of dollars):
		IDACORP						Idaho Power
		2014			2013			2014			2013
	Three months ended March 31,
	Income tax at statutory rates (federal and state)	$	14,119		$	18,470		$	14,417		$	18,543
	Additional accumulated deferred investment tax credit amortization	(950		)	—			(950		)	—
	Affordable housing tax credits	(1,268		)	(1,384		)	—			—
	Affordable housing investment amortization, net of statutory taxes	704			(101		)	—			—
	Other(1)	(3,898		)	(4,942		)	(4,496		)	(5,165		)
	Income tax expense	$	8,707		$	12,043		$	8,971		$	13,378
	Effective tax rate	24.1		%	25.5		%	24.3		%	28.2		%
	(1) "Other" is primarily comprised of Idaho Power's regulatory flow-through tax adjustments, which are 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.
	Based on its estimate of 2014 return on year-end equity in the Idaho jurisdiction (Idaho ROE), Idaho Power recorded $950 thousand of additional accumulated deferred investment tax credit (ADITC) amortization in the first quarter of 2014, as compared to no amortization for the three months ended March 31, 2013. See Note 3 for a discussion of Idaho Power's regulatory authority for use of additional ADITC amortization.

REGULATORY_MATTERS

REGULATORY MATTERS:	3 Months Ended
	Mar. 31, 2014
Regulatory Matters Disclosures [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 as a result of 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 as a result of 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; Modification to Net Power Supply Expense Collection Method" 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.
	Settlement Stipulation — Investment Tax Credits and Idaho 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 ROE for 2012, 2013, or 2014 is less than 9.5 percent, then Idaho Power may amortize additional ADITC to help achieve a minimum 9.5 percent Idaho ROE in the applicable year. Idaho Power would be permitted to 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); and
	•	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 as a reduction to the pension regulatory asset 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.
	Based on Idaho Power's Idaho ROE in 2012 and 2013, Idaho Power triggered the sharing mechanism of the December 2011 settlement stipulation for both years. The amounts Idaho Power recorded for revenue sharing were as follows (in millions):
			2013		2012
	Additional pension expense funded through sharing		$	16.5	$	14.6
	Provision against current revenue as a result of sharing		7.6		7.2
	Total		$	24.1	$	21.8
	In the first quarter of 2014, Idaho Power recorded $950 thousand in additional ADITC amortization for that period based on its estimate of Idaho ROE for full-year 2014 of less than 9.5 percent (absent amortization of additional ADITC).
	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 will become effective June 1, 2014. Idaho Power's filing 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 April 15, 2014, Idaho Power filed an application with the IPUC 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 requested $11.1 million PCA rate increase is net of Idaho Power's proposal in the application to use a total of $20.0 million of surplus Idaho energy efficiency rider funds to offset what would otherwise be a larger PCA rate adjustment request. The proposed PCA rate increase is also net of $7.6 million of customer revenue sharing for 2013 under the December 2011 settlement stipulation described above. An order from the IPUC is pending. 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 March 14, 2014, Idaho Power filed an application with the IPUC 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. An order from the IPUC is pending. 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.

NOTES_PAYABLE

NOTES PAYABLE:	3 Months Ended
	Mar. 31, 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 March 31, 2014, no loans were outstanding under either IDACORP's or Idaho Power's facilities.  At March 31, 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 March 31, 2014 and December 31, 2013:
		March 31, 2014									December 31, 2013
		Idaho Power			IDACORP			Total			Idaho Power			IDACORP			Total
	Commercial paper outstanding	$	—		$	47,300		$	47,300		$	—		$	54,750		$	54,750
	Weighted-average annual interest rate	—		%	0.31		%	0.31		%	—		%	0.34		%	0.34		%

COMMON_STOCK

COMMON STOCK:	3 Months Ended
	Mar. 31, 2014
Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]	'
Common Stock	'
	COMMON STOCK
	IDACORP Common Stock
	During the three months ended March 31, 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 March 31, 2014, the leverage ratios for IDACORP and Idaho Power were 47 percent and 48 percent, respectively.  Based on these restrictions, IDACORP’s and Idaho Power’s dividends were limited to $962 million and $860 million, respectively, at March 31, 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 March 31, 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 March 31, 2014, Idaho Power's common equity capital was 52 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:	3 Months Ended
	Mar. 31, 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 months ended March 31, 2014 and 2013 (in thousands, except for per share amounts).
		Three months ended March 31,
		2014		2013
	Numerator:
	Net income attributable to IDACORP, Inc.	$	27,404	$	35,194
	Denominator:
	Weighted-average common shares outstanding - basic	50,131		50,039
	Effect of dilutive securities:
	Options	1		4
	Restricted stock	43		21
	Weighted-average common shares outstanding - diluted	50,175		50,064
	Basic earnings per share	$	0.55	$	0.7
	Diluted earnings per share	$	0.55	$	0.7

COMMITMENTS

COMMITMENTS:	3 Months Ended
	Mar. 31, 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 three months ended March 31, 2014, other than the addition of five power purchase agreements with solar and other alternative energy developers for projects with a combined nameplate capacity of approximately 43 MW. Payments pursuant to these agreements are expected to total $164 million from 2014 to 2036.
	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 $74 million at March 31, 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 March 31, 2014, the value of the reclamation trust fund was $65 million. During the three months ended March 31, 2014, the reclamation trust fund distributed approximately $5 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 March 31, 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:	3 Months Ended
	Mar. 31, 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 and in orders respecting two separately filed settlements 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. Idaho Power and IESCo petitioned the D.C. Circuit for review of the first of the FERC's decisions refusing to approve the waiver provision of the settlements, on the basis that the FERC failed to apply its established precedents and rules. The petition for review was transferred to the Ninth Circuit Court of Appeals in June 2013 and remains pending before that court. The second settlement remains before the FERC on rehearing.
	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 is expected to issue a final unified decree in the SRBA in the fall of 2014. Assuming entry of the final decree, the SRBA will be concluded.
	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. 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:	3 Months Ended
	Mar. 31, 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 March 31, 2014 and 2013 (in thousands of dollars).
		Pension Plan						SMSP				Postretirement
												Benefits
		2014			2013			2014		2013		2014			2013
	Service cost	$	6,584		$	7,812		$	411	$	545	$	276		$	413
	Interest cost	8,871			7,936			964		814		716			743
	Expected return on plan assets	(10,321		)	(8,698		)	—		—		(656		)	(595		)
	Amortization of prior service cost	87			87			55		53		46			(25		)
	Amortization of net loss	1,008			4,252			655		710		—			169
	Net periodic benefit cost	6,229			11,389			2,085		2,122		382			705
	Adjustments due to the effects of regulation(1)	(1,705		)	(6,543		)	—		—		—			—
	Net periodic benefit cost recognized for financial reporting(1)	$	4,524		$	4,846		$	2,085	$	2,122	$	382		$	705
	(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 three months ended March 31, 2014, Idaho Power made no contributions to its defined benefit pension plan. In April 2014, Idaho Power made a $6.5 million contribution to the pension plan. Idaho Power's minimum required contributions to the pension plan are estimated to be $1.4 million in 2014, though Idaho Power plans to contribute at least $20 million to the pension plan during 2014.
	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:

3 Months Ended

Mar. 31, 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 table below summarizes investments in equity securities by IDACORP and Idaho Power as of March 31, 2014 and December 31, 2013 (in thousands of dollars).

March 31, 2014

December 31, 2013

Gross

Gross

Fair

Gross

Gross

Fair

Unrealized

Unrealized

Value

Unrealized

Unrealized

Value

Gain

Loss

Gain

Loss

Available-for-sale securities

$

—

$

—

$

40,358

$

—

$

—

$

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 March 31, 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 three months ended March 31, 2014 or 2013.

DERIVATIVE_FINANCIAL_INSTRUMEN

DERIVATIVE FINANCIAL INSTRUMENTS:	3 Months Ended
	Mar. 31, 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.
	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 March 31, 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
	March 31, 2014
	Current:
	Financial swaps	Other current assets	$	2,413		$	(328	)	$	2,085	$	328	$	(328	)		$	—
	Financial swaps	Other current liabilities	766			(766		)	—		3,293		(1,739		)	(1)	1,554
	Forward contracts	Other current assets	297			—			297		—		—				—
	Forward contracts	Other current liabilities	—			—			—		233		—				233
	Long-term:
	Financial swaps	Other assets	244			—			244		—		—				—
	Forward contracts	Other assets	127			—			127		—		—				—
	Total		$	3,847		$	(1,094	)	$	2,753	$	3,854	$	(2,067	)		$	1,787
	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 $1.0 million and $1.1 million of collateral receivable for the periods ending March 31, 2014 and December 31, 2013, respectively.
	The table below presents the gains and losses on derivatives not designated as hedging instruments for the three months ended March 31, 2014 and 2013 (in thousands of dollars).
		Location of Realized Gain/(Loss) on Derivatives Recognized in Income	Gain/(Loss) on Derivatives Recognized in Income(1)
			2014			2013
	Financial swaps	Off-system sales	$	(6,794	)	$	1,472
	Financial swaps	Purchased power	1,016			(14		)
	Financial swaps	Fuel expense	3,617			1,116
	Financial swaps	Other operations and maintenance	15			11
	Forward contracts	Off-system sales	43
	Forward contracts	Purchased power	(41		)
	Forward contracts	Fuel expense	40			68
	(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.
	The table below presents the volumes of derivative commodity forward contracts and swaps outstanding at March 31, 2014 and 2013 (in thousands of units).
			March 31,
	Commodity	Units	2014		2013
	Electricity purchases	MWh	576		95
	Electricity sales	MWh	492		785
	Natural gas purchases	MMBtu	9,987		10,216
	Natural gas sales	MMBtu	666		425
	Diesel purchases	Gallons	675		626
	Credit Risk
	At March 31, 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 March 31, 2014, was $3.5 million.  Idaho Power posted $1.0 million cash collateral related to this amount.  If the credit-risk-related contingent features underlying these agreements were triggered on March 31, 2014, Idaho Power would have been required to post an additional $0.8 million of cash collateral to its counterparties.

FAIR_VALUE_MEASUREMENTS

FAIR VALUE MEASUREMENTS:	3 Months Ended
	Mar. 31, 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 months ended March 31, 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 March 31, 2014 and December 31, 2013 (in thousands of dollars).
		31-Mar-14								December 31, 2013
		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	Assets:
	Derivatives	$	2,329	$	424	$	—	$	2,753	$	1,437	$	235	$	—	$	1,672
	Money market funds	100		—		—		100		100		—		—		100
	Trading securities:  Equity securities	162		—		—		162		1,153		—		—		1,153
	Available-for-sale securities:  Equity securities	40,358		—		—		40,358		41,119		—		—		41,119
	Liabilities:
	Derivatives	$	1,554	$	233	$	—	$	1,787	$	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 March 31, 2014 and December 31, 2013, using available market information and appropriate valuation methodologies.
		March 31, 2014				December 31, 2013
		Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
		(thousands of dollars)
	IDACORP
	Assets:
	Notes receivable(1)	$	3,472	$	3,472	$	3,472	$	3,472
	Liabilities:
	Long-term debt(1)	1,615,319		1,715,770		1,616,322		1,600,248
	Idaho Power
	Liabilities:
	Long-term debt(1)	$	1,615,319	$	1,715,770	$	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. Cash and cash equivalents, deposits, customer and other receivables, notes payable, accounts payable, interest accrued, and taxes accrued are reported at their carrying value as these are a reasonable estimate of their fair value.  The estimated fair values for long-term debt are based upon quoted market prices of similar issues or the same issues in an inactive market. The estimated fair values for notes receivable are based upon discounted cash flow analysis.

SEGMENT_INFORMATION

SEGMENT INFORMATION:	3 Months Ended
	Mar. 31, 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 March 31, 2014:
	Revenues	$	292,320	$	399		$	—		$	292,719
	Net income (loss) attributable to IDACORP, Inc.	27,900		(496		)	—			27,404
	Total assets as of March 31, 2014	5,273,793		101,070			(13,471		)	5,361,392
	Three months ended March 31, 2013:
	Revenues	$	264,368	$	560		$	—		$	264,928
	Net income attributable to IDACORP, Inc.	34,046		1,148			—			35,194

CHANGES_IN_ACCUMULATED_OTHER_C

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME: CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME:	3 Months Ended
	Mar. 31, 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 changes in components of accumulated other comprehensive income (AOCI), net of tax, during the three months ended March 31, 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 March 31, 2014:
	Balance at beginning of period	$	—		$	(16,553	)	$	(16,553	)
	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	$	—		$	(16,121	)	$	(16,121	)
	Three months ended March 31, 2013:
	Balance at beginning of period	$	4,136		$	(21,252	)	$	(17,116	)
	Other comprehensive income before reclassifications	1,181			—			1,181
	Amounts reclassified out of AOCI	—			465			465
	Net current-period other comprehensive income	1,181			465			1,646
	Balance at end of period	$	5,317		$	(20,787	)	$	(15,470	)
	The table below presents amounts reclassified out of components of AOCI and the income statement location of those amounts reclassified during the three months ended March 31, 2014 and 2013 (in thousands of dollars). Items in parentheses indicate increases to net income.
	Details About AOCI	Amount Reclassified from AOCI
		2014			2013
	Amortization of defined benefit pension items(1)
	Prior service cost	$	55		$	53
	Net loss	655			710
	Total before tax	710			763
	Tax benefit(2)	(278		)	(298		)
	Net of tax	432			465
	Total reclassification for the period	$	432		$	465
	(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.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES: Organization, Consolidation, Presentation, and Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 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 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.  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.
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 March 31, 2014, consolidated results of operations for the three months ended March 31, 2014 and 2013, and consolidated cash flows for the three months ended March 31, 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	'
	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.  As a result, 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 thus changed its accounting for its equity-method investments in qualified affordable housing projects to the proportional amortization method. All prior periods were properly 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 (benefit). 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	'
	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, or method changes. Discrete events are recorded in the interim period in which they occur. 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	'
	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). These types of transactions are excluded from the offsetting presented in the derivative fair value and offsetting table below.
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. There were no transfers between levels or material changes in valuation techniques or inputs during the three months ended March 31, 2014 or the year ended December 31, 2013.
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)	3 Months Ended
	Mar. 31, 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 three months ended March 31 (in thousands of dollars):
		IDACORP						Idaho Power
		2014			2013			2014			2013
	Three months ended March 31,
	Income tax at statutory rates (federal and state)	$	14,119		$	18,470		$	14,417		$	18,543
	Additional accumulated deferred investment tax credit amortization	(950		)	—			(950		)	—
	Affordable housing tax credits	(1,268		)	(1,384		)	—			—
	Affordable housing investment amortization, net of statutory taxes	704			(101		)	—			—
	Other(1)	(3,898		)	(4,942		)	(4,496		)	(5,165		)
	Income tax expense	$	8,707		$	12,043		$	8,971		$	13,378
	Effective tax rate	24.1		%	25.5		%	24.3		%	28.2		%
	(1) "Other" is primarily comprised of Idaho Power's regulatory flow-through tax adjustments, which are 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_3_Tab

REGULATORY MATTERS: Level 3 (Tables)	3 Months Ended
	Mar. 31, 2014
Regulatory Matters Disclosures [Abstract]	'
Idaho Sharing Mechanism [Table Text Block]	'
	The amounts Idaho Power recorded for revenue sharing were as follows (in millions):
		2013		2012
	Additional pension expense funded through sharing	$	16.5	$	14.6
	Provision against current revenue as a result of sharing	7.6		7.2
	Total	$	24.1	$	21.8

NOTES_PAYABLE_Level_3_Tables

NOTES PAYABLE: Level 3 (Tables)	3 Months Ended
	Mar. 31, 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 March 31, 2014 and December 31, 2013:
		March 31, 2014									December 31, 2013
		Idaho Power			IDACORP			Total			Idaho Power			IDACORP			Total
	Commercial paper outstanding	$	—		$	47,300		$	47,300		$	—		$	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)	3 Months Ended
	Mar. 31, 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 months ended March 31, 2014 and 2013 (in thousands, except for per share amounts).
		Three months ended March 31,
		2014		2013
	Numerator:
	Net income attributable to IDACORP, Inc.	$	27,404	$	35,194
	Denominator:
	Weighted-average common shares outstanding - basic	50,131		50,039
	Effect of dilutive securities:
	Options	1		4
	Restricted stock	43		21
	Weighted-average common shares outstanding - diluted	50,175		50,064
	Basic earnings per share	$	0.55	$	0.7
	Diluted earnings per share	$	0.55	$	0.7

BENEFIT_PLANS_Level_3_Tables

BENEFIT PLANS: Level 3 (Tables)	3 Months Ended
	Mar. 31, 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 March 31, 2014 and 2013 (in thousands of dollars).
		Pension Plan						SMSP				Postretirement
												Benefits
		2014			2013			2014		2013		2014			2013
	Service cost	$	6,584		$	7,812		$	411	$	545	$	276		$	413
	Interest cost	8,871			7,936			964		814		716			743
	Expected return on plan assets	(10,321		)	(8,698		)	—		—		(656		)	(595		)
	Amortization of prior service cost	87			87			55		53		46			(25		)
	Amortization of net loss	1,008			4,252			655		710		—			169
	Net periodic benefit cost	6,229			11,389			2,085		2,122		382			705
	Adjustments due to the effects of regulation(1)	(1,705		)	(6,543		)	—		—		—			—
	Net periodic benefit cost recognized for financial reporting(1)	$	4,524		$	4,846		$	2,085	$	2,122	$	382		$	705
	(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)

3 Months Ended

Mar. 31, 2014

Investments, Debt and Equity Securities [Abstract]

'

Available-for-sale Securities [Table Text Block]

'

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

March 31, 2014

December 31, 2013

Gross

Gross

Fair

Gross

Gross

Fair

Unrealized

Unrealized

Value

Unrealized

Unrealized

Value

Gain

Loss

Gain

Loss

Available-for-sale securities

$

—

$

—

$

40,358

$

—

$

—

$

41,119

DERIVATIVE_FINANCIAL_INSTRUMEN1

DERIVATIVE FINANCIAL INSTRUMENTS: Level 3 (Tables)	3 Months Ended
	Mar. 31, 2014
Derivative Financial Instruments [Abstract]	'
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 March 31, 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
	March 31, 2014
	Current:
	Financial swaps	Other current assets	$	2,413		$	(328	)	$	2,085	$	328	$	(328	)		$	—
	Financial swaps	Other current liabilities	766			(766		)	—		3,293		(1,739		)	(1)	1,554
	Forward contracts	Other current assets	297			—			297		—		—				—
	Forward contracts	Other current liabilities	—			—			—		233		—				233
	Long-term:
	Financial swaps	Other assets	244			—			244		—		—				—
	Forward contracts	Other assets	127			—			127		—		—				—
	Total		$	3,847		$	(1,094	)	$	2,753	$	3,854	$	(2,067	)		$	1,787
	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 $1.0 million and $1.1 million of collateral receivable for the periods ending March 31, 2014 and December 31, 2013, respectively.
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 months ended March 31, 2014 and 2013 (in thousands of dollars).
		Location of Realized Gain/(Loss) on Derivatives Recognized in Income	Gain/(Loss) on Derivatives Recognized in Income(1)
			2014			2013
	Financial swaps	Off-system sales	$	(6,794	)	$	1,472
	Financial swaps	Purchased power	1,016			(14		)
	Financial swaps	Fuel expense	3,617			1,116
	Financial swaps	Other operations and maintenance	15			11
	Forward contracts	Off-system sales	43
	Forward contracts	Purchased power	(41		)
	Forward contracts	Fuel expense	40			68
	(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 [Table Text Block]	'
	The table below presents the volumes of derivative commodity forward contracts and swaps outstanding at March 31, 2014 and 2013 (in thousands of units).
			March 31,
	Commodity	Units	2014		2013
	Electricity purchases	MWh	576		95
	Electricity sales	MWh	492		785
	Natural gas purchases	MMBtu	9,987		10,216
	Natural gas sales	MMBtu	666		425
	Diesel purchases	Gallons	675		626

FAIR_VALUE_MEASUREMENTS_Level_

FAIR VALUE MEASUREMENTS: Level 3 (Tables)	3 Months Ended
	Mar. 31, 2014
Fair value measurements [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 March 31, 2014 and December 31, 2013 (in thousands of dollars).
		31-Mar-14								December 31, 2013
		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	Assets:
	Derivatives	$	2,329	$	424	$	—	$	2,753	$	1,437	$	235	$	—	$	1,672
	Money market funds	100		—		—		100		100		—		—		100
	Trading securities:  Equity securities	162		—		—		162		1,153		—		—		1,153
	Available-for-sale securities:  Equity securities	40,358		—		—		40,358		41,119		—		—		41,119
	Liabilities:
	Derivatives	$	1,554	$	233	$	—	$	1,787	$	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 March 31, 2014 and December 31, 2013, using available market information and appropriate valuation methodologies.
		March 31, 2014				December 31, 2013
		Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
		(thousands of dollars)
	IDACORP
	Assets:
	Notes receivable(1)	$	3,472	$	3,472	$	3,472	$	3,472
	Liabilities:
	Long-term debt(1)	1,615,319		1,715,770		1,616,322		1,600,248
	Idaho Power
	Liabilities:
	Long-term debt(1)	$	1,615,319	$	1,715,770	$	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)	3 Months Ended
	Mar. 31, 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 March 31, 2014:
	Revenues	$	292,320	$	399		$	—		$	292,719
	Net income (loss) attributable to IDACORP, Inc.	27,900		(496		)	—			27,404
	Total assets as of March 31, 2014	5,273,793		101,070			(13,471		)	5,361,392
	Three months ended March 31, 2013:
	Revenues	$	264,368	$	560		$	—		$	264,928
	Net income attributable to IDACORP, Inc.	34,046		1,148			—			35,194

CHANGES_IN_ACCUMULATED_OTHER_C1

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME: Level 3 (Tables)	3 Months Ended
	Mar. 31, 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 months ended March 31, 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 March 31, 2014:
	Balance at beginning of period	$	—		$	(16,553	)	$	(16,553	)
	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	$	—		$	(16,121	)	$	(16,121	)
	Three months ended March 31, 2013:
	Balance at beginning of period	$	4,136		$	(21,252	)	$	(17,116	)
	Other comprehensive income before reclassifications	1,181			—			1,181
	Amounts reclassified out of AOCI	—			465			465
	Net current-period other comprehensive income	1,181			465			1,646
	Balance at end of period	$	5,317		$	(20,787	)	$	(15,470	)
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 months ended March 31, 2014 and 2013 (in thousands of dollars). Items in parentheses indicate increases to net income.
	Details About AOCI	Amount Reclassified from AOCI
		2014			2013
	Amortization of defined benefit pension items(1)
	Prior service cost	$	55		$	53
	Net loss	655			710
	Total before tax	710			763
	Tax benefit(2)	(278		)	(298		)
	Net of tax	432			465
	Total reclassification for the period	$	432		$	465
	(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
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Income Tax Expense [Line Items]	'	'
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount	$14,119	$18,470
Effective Income Tax Rate Reconciliation, Tax Credit, Investment, Amount	-950	0
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Amount	-1,268	-1,384
Effective Income Tax Rate Reconciliation, Affordable Housing Investment Amortization	704	-101
Effective Income Tax Rate Reconciliation, Other Adjustments, Amount	-3,898	-4,942
Income Tax Expense (Benefit)	8,707	12,043
Effective tax rate	24.10%	25.50%
Idaho Power Company	'	'
Income Tax Expense [Line Items]	'	'
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount	14,417	18,543
Effective Income Tax Rate Reconciliation, Tax Credit, Investment, Amount	-950	0
Effective Income Tax Rate Reconciliation, Other Adjustments, Amount	-4,496	-5,165
Income Tax Expense (Benefit)	$8,971	$13,378
Effective tax rate	24.30%	28.20%

REGULATORY_MATTERS_Level_4_Det

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

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 27, 2011

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 14, 2014

Jun. 01, 2013

Jun. 01, 2012

Dec. 31, 2012

Jan. 02, 2012

Dec. 31, 2012

Jun. 29, 2012

Dec. 31, 2012

Mar. 01, 2012

Dec. 31, 2012

Settlement Stipulation - Investment Tax Credits and Idaho Sharing Mechanism

Settlement Stipulation - Investment Tax Credits and Idaho Sharing Mechanism

Settlement Stipulation - Investment Tax Credits and Idaho Sharing Mechanism

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

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

Annual Idaho Fixed Cost Adjustment Filing

Annual Idaho Fixed Cost Adjustment Filing

Annual Idaho Fixed Cost Adjustment Filing

Annual Idaho Fixed Cost Adjustment Filing

IDAHO

IDAHO

IDAHO

IDAHO

OREGON

OREGON

OREGON

Idaho and Oregon General Rate Cases and Base Rate Adjustments

Idaho and Oregon General Rate Cases and Base Rate Adjustments

Cost Recovery for Langley Gulch Power Plant

Cost Recovery for Langley Gulch Power Plant

Idaho and Oregon General Rate Cases and Base Rate Adjustments

Idaho and Oregon General Rate Cases and Base Rate Adjustments

Cost Recovery for Langley Gulch Power Plant

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

'

'

'

'

'

106,000,000

140,400,000

'

'

'

'

34,000,000

'

58,100,000

'

1,800,000

'

3,000,000

Public Utilities, Requested Rate Increase (Decrease), Amount

'

'

'

'

'

11,100,000

'

6,000,000

'

'

'

'

'

'

'

'

'

'

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%

'

'

'

'

'

'

'

'

'

'

'

'

'

Additional Pension Amortization As Result Of Idaho Settlement Stipulation

'

'

16,500,000

14,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Liabilities

'

'

7,600,000

7,200,000

'

20,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Increase (Decrease) in Regulatory Assets and Liabilities

-21,479,000

13,681,000

24,100,000

21,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Effective Income Tax Rate Reconciliation, Tax Credit, Investment, Amount

-950,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Annual fixed cost adjustment mechanism deferral

'

'

'

'

'

'

'

'

$14,900,000

$8,900,000

$10,300,000

'

'

'

'

'

'

'

NOTES_PAYABLE_Level_4_Details

NOTES PAYABLE: Level 4 (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
Short-term borrowings:	'	'
Commercial paper outstanding	$47,300,000	$54,750,000
Weighted-average annual interest rate	0.31%	0.34%
IDACORP	'	'
Short-term borrowings:	'	'
Commercial paper outstanding	47,300,000	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 $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2014
Shareholders' equity [Line Items]	'
Maximum leverage ratio requirement	0.65
Idaho Power Company	'
Shareholders' equity [Line Items]	'
Maximum leverage ratio requirement	0.65
Ratio of Indebtedness to Net Capital	0.48
Dividend Distribution Restriction Amount	$860
Dividend Distribution Restriction Threshold	0.35
Ratio of total Capital to total capital and long-term debt	0.52
Preferred Stock, Shares Outstanding	0
IDACORP	'
Shareholders' equity [Line Items]	'
Stock Issued During Period, Shares, New Issues	74,049
Ratio of Indebtedness to Net Capital	0.47
Dividend Distribution Restriction Amount	$962
IDACORP | Continuous equity program	'
Shareholders' equity [Line Items]	'
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
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Numerator:	'	'
Net income attributable to IDACORP, Inc.	$27,404	$35,194
Denominator:	'	'
Weighted Average Common Shares Outstanding - Basic	50,131	50,039
Options	1	4
Restricted Stock	43	21
Weighted Average Common Shares Outstanding - Diluted	50,175	50,064
Earnings Attributable to IDACORP, Inc. - Basic (in dollars per share)	$0.55	$0.70
Earnings Attributable to IDACORP, Inc. - Diluted (in dollars per share)	$0.55	$0.70

COMMITMENTS_Level_4_Details

COMMITMENTS: Level 4 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014
	MWh
Idaho Power Company	'
Guarantor Obligations	'
IERCo ownership interest in BCC	33.00%
IERCo guarantee of BCC reclamation obligation	$74
Long-term Purchase Commitment	'
Nameplate Capacity	43
Estimated purchase obligation	164
Bridger Coal Company	'
Guarantor Obligations	'
Guarantor Obligations Total Reclamation Trust Fund	65
Distribution from Reclamation Trust Fund	$5

BENEFIT_PLANS_Level_4_Details

BENEFIT PLANS: Level 4 (Details) (USD $)	3 Months Ended				0 Months Ended	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013		Apr. 15, 2014	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
	Pension Plan		Pension Plan		Pension Plan	Senior Management Security Plan	Senior Management Security Plan	Postretirement Benefits	Postretirement Benefits
					Subsequent Event
Defined Benefit Plan Disclosure	'		'		'	'	'	'	'
Service cost	$6,584,000		$7,812,000		'	$411,000	$545,000	$276,000	$413,000
Interest cost	8,871,000		7,936,000		'	964,000	814,000	716,000	743,000
Defined Benefit Plan, Expected Return on Plan Assets	-10,321,000		-8,698,000		'	0	0	-656,000	-595,000
Amortization of prior service cost	87,000		87,000		'	55,000	53,000	46,000	-25,000
Amortization of net loss	1,008,000		4,252,000		'	655,000	710,000	0	169,000
Net periodic benefit cost	6,229,000		11,389,000		'	2,085,000	2,122,000	382,000	705,000
Defined Benefit Plan Regulatory Adjustments Deferred	-1,705,000	[1]	-6,543,000	[1]	'	'	'	'	'
Net periodic benefit cost recognized for financial reporting	4,524,000	[1]	4,846,000	[1]	'	2,085,000	2,122,000	382,000	705,000
Contributions made to the defined benefit pension plan	0		'		6,500,000	'	'	'	'
Defined Benefit Plan, Minimum Funding Requirement for Next Fiscal Year	1,000,000		'		'	'	'	'	'
Defined Benefit Plan, Estimated Future Employer Contributions in Current Fiscal Year	$20,000,000		'		'	'	'	'	'
[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 $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 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	40,358,000	'	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 $)	Mar. 31, 2014		Dec. 31, 2013
Derivatives, Fair Value [Line Items]	'		'
Derivative Asset, Fair Value, Gross Asset	$3,847,000		$2,248,000
Derivative Asset, Fair Value, Gross Liability	-1,094,000		-576,000
Derivative Asset, Fair Value, Amount Offset Against Collateral	2,753,000		1,672,000
Derivative Liability, Fair Value, Gross Liability	3,854,000		2,204,000
Derivative Liability, Fair Value, Gross Asset	-2,067,000		-1,632,000
Derivative Liability, Fair Value, Amount Offset Against Collateral	1,787,000		572,000
Derivative Asset, Collateral, Obligation to Return Cash, Offset	1,000,000		1,000,000
Energy Related Derivative [Member] | Other Current Assets [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative Asset, Fair Value, Gross Asset	2,413,000		1,451,000
Derivative Asset, Fair Value, Gross Liability	-328,000		-175,000
Derivative Asset, Fair Value, Amount Offset Against Collateral	2,085,000		1,276,000
Derivative Liability, Fair Value, Gross Liability	328,000		175,000
Derivative Liability, Fair Value, Gross Asset	-328,000		-175,000
Derivative Liability, Fair Value, Amount Offset Against Collateral	0		0
Energy Related Derivative [Member] | Other Current Liabilities [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative Asset, Fair Value, Gross Asset	766,000		373,000
Derivative Asset, Fair Value, Gross Liability	-766,000		-373,000
Derivative Asset, Fair Value, Amount Offset Against Collateral	0		0
Derivative Liability, Fair Value, Gross Liability	3,293,000		1,975,000
Derivative Liability, Fair Value, Gross Asset	-1,739,000	[1]	-1,429,000	[1]
Derivative Liability, Fair Value, Amount Offset Against Collateral	1,554,000		546,000
Energy Related Derivative [Member] | Other Assets [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative Asset, Fair Value, Gross Asset	244,000		189,000
Derivative Asset, Fair Value, Gross Liability	0		-28,000
Derivative Asset, Fair Value, Amount Offset Against Collateral	244,000		161,000
Derivative Liability, Fair Value, Gross Liability	'		28,000
Derivative Liability, Fair Value, Gross Asset	'		-28,000
Derivative Liability, Fair Value, Amount Offset Against Collateral	'		0
Commodity Contract [Member] | Other Current Assets [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative Asset, Fair Value, Gross Asset	297,000		109,000
Derivative Asset, Fair Value, Gross Liability	0		0
Derivative Asset, Fair Value, Amount Offset Against Collateral	297,000		109,000
Commodity Contract [Member] | Other Current Liabilities [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative Liability, Fair Value, Gross Liability	233,000		26,000
Derivative Liability, Fair Value, Gross Asset	0		0
Derivative Liability, Fair Value, Amount Offset Against Collateral	233,000		26,000
Commodity Contract [Member] | Other Assets [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative Asset, Fair Value, Gross Asset	127,000		126,000
Derivative Asset, Fair Value, Gross Liability	0		0
Derivative Asset, Fair Value, Amount Offset Against Collateral	$127,000		$126,000
[1]	Current liability derivative amounts offset include $1.0 million and $1.1 million of collateral receivable for the periods ending March 31, 2014 and December 31, 2013, respectively.

Derivative_Instruments_Gains_L

Derivative Instruments Gains (Loss) on Derivatives Recognized in Income (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Energy Related Derivative [Member] | Sales [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Loss on Derivative	($6,794)	'
Derivative, Gain on Derivative	'	1,472
Energy Related Derivative [Member] | Cost of Sales [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Loss on Derivative	'	-14
Derivative, Gain on Derivative	1,016	'
Energy Related Derivative [Member] | Fuel Expense [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Gain on Derivative	3,617	1,116
Energy Related Derivative [Member] | Operating Expense [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Gain on Derivative	15	11
Commodity Contract [Member] | Sales [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Gain on Derivative	43	'
Commodity Contract [Member] | Cost of Sales [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Loss on Derivative	-41	'
Derivative, Gain on Derivative	'	'
Commodity Contract [Member] | Fuel Expense [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Gain on Derivative	$40	$68

Derivative_Commodities_and_Dis

Derivative Commodities and Disclosures (Details) (USD $)	Mar. 31, 2014	Mar. 31, 2013
In Millions, unless otherwise specified	MWh	MWh
Derivative	'	'
Derivatives in a net liability position	3.5	'
Collateral Already Posted, Aggregate Fair Value	1	'
Additional Collateral, Aggregate Fair Value	0.8	'
Electricity | Long [Member]	'	'
Derivative	'	'
Derivative, Nonmonetary Notional Amount	576,000	95,000
Electricity | Short [Member]	'	'
Derivative	'	'
Derivative, Nonmonetary Notional Amount	492,000	785,000
Natural Gas | Long [Member]	'	'
Derivative	'	'
Derivative, Nonmonetary Notional Amount	9,987,000	10,216,000
Natural Gas | Short [Member]	'	'
Derivative	'	'
Derivative, Nonmonetary Notional Amount	666,000	425,000
Diesel Fuel | Long [Member]	'	'
Derivative	'	'
Derivative, Nonmonetary Notional Amount	675,000	626,000

FAIR_VALUE_MEASUREMENTS_Level_1

FAIR VALUE MEASUREMENTS: Level 4 (Details) (USD $)	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013	Dec. 31, 2013
Fair Value Disclosures	'		'	'
Fair Value, All Levels Transfers, Amount	$0		$0	'
Asset derivatives	2,753,000		'	1,672,000
Money market funds	100,000		'	100,000
Trading securities: Equity securities	162,000		'	1,153,000
Available-for-sale securities: Equity securities	40,358,000		'	41,119,000
Liability derivatives	1,787,000		'	572,000
Quoted Prices in Active Markets for Identical Assets (Level 1)	'		'	'
Fair Value Disclosures	'		'	'
Asset derivatives	2,329,000		'	1,437,000
Money market funds	100,000		'	100,000
Trading securities: Equity securities	162,000		'	1,153,000
Available-for-sale securities: Equity securities	40,358,000		'	41,119,000
Liability derivatives	1,554,000		'	546,000
Significant Other Observable Inputs (Level 2)	'		'	'
Fair Value Disclosures	'		'	'
Asset derivatives	424,000		'	235,000
Money market funds	0		'	0
Trading securities: Equity securities	0		'	0
Available-for-sale securities: Equity securities	0		'	0
Liability derivatives	233,000		'	26,000
Significant Unobservable Inputs (Level 3)	'		'	'
Fair Value Disclosures	'		'	'
Asset derivatives	0		'	0
Money market funds	0		'	0
Trading securities: Equity securities	0		'	0
Available-for-sale securities: Equity securities	0		'	0
Liability derivatives	0		'	0
Carrying Amount	'		'	'
Fair Value Disclosures	'		'	'
Notes receivable	3,472,000	[1]	'	3,472,000	[1]
Long-term debt	1,615,319,000	[1]	'	1,616,322,000	[1]
Carrying Amount | Idaho Power Company	'		'	'
Fair Value Disclosures	'		'	'
Long-term debt	1,615,319,000	[1]	'	1,616,322,000	[1]
Estimated Fair Value	'		'	'
Fair Value Disclosures	'		'	'
Notes receivable	3,472,000	[1]	'	3,472,000	[1]
Long-term debt	1,715,770,000	[1]	'	1,600,248,000	[1]
Estimated Fair Value | Idaho Power Company	'		'	'
Fair Value Disclosures	'		'	'
Long-term debt	$1,715,770,000	[1]	'	$1,600,248,000	[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
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Segment Reporting Information	'	'	'
Revenues	$292,719	$264,928	'
Income (loss) attributable to IDACORP, Inc.	27,185	35,041	'
Net Income Attributable to IDACORP, Inc.	27,404	35,194	'
Total assets	5,361,392	'	5,364,563
Idaho Power Company	'	'	'
Segment Reporting Information	'	'	'
Revenues	292,320	264,368	'
Income (loss) attributable to IDACORP, Inc.	27,900	34,046	'
Total assets	5,273,793	'	'
All Other	'	'	'
Segment Reporting Information	'	'	'
Revenues	399	560	'
Income (loss) attributable to IDACORP, Inc.	-496	1,148	'
Total assets	101,070	'	'
Eliminations	'	'	'
Segment Reporting Information	'	'	'
Revenues	0	0	'
Income (loss) attributable to IDACORP, Inc.	0	0	'
Total assets	-13,471	'	'
Idaho Power Company	'	'	'
Segment Reporting Information	'	'	'
IERCo's ownership percentage in Bridger Coal Company	33.00%	'	'
Income (loss) attributable to IDACORP, Inc.	27,900	34,046	'
Total assets	$5,275,358	'	$5,266,411

CHANGES_IN_ACCUMULATED_OTHER_C2

CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME: Level 4 (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Reclassification out of Accumulated Other Comprehensive Income	'		'
Amortization of prior service cost	$55	[1]	$53	[1]
Amortization of net loss	655	[1]	710	[1]
Total reclassification, before tax - pension and postretirement benefits	710	[1]	763	[1]
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent	-278	[2]	-298	[2]
Total reclassification, net of tax - pension and postretirement benfits	432		465
Reclassifications	432		465
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]	'		'
AOCI - Beginning Balance	-16,553		-17,116
Before Reclassifications	0		1,181
Reclassifications	432		465
Other Comprehensive Income (Loss)	432		1,646
AOCI - Ending Balance	-16,121		-15,470
Accumulated Unrealized Gains and Losses on Available-for-Sale Securities	'		'
Reclassification out of Accumulated Other Comprehensive Income	'		'
Reclassifications	0		0
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]	'		'
AOCI - Beginning Balance	0		4,136
Before Reclassifications	0		1,181
Reclassifications	0		0
Other Comprehensive Income (Loss)	0		1,181
AOCI - Ending Balance	0		5,317
Accumulated Defined Benefit Pension Items	'		'
Reclassification out of Accumulated Other Comprehensive Income	'		'
Reclassifications	432		465
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]	'		'
AOCI - Beginning Balance	-16,553		-21,252
Before Reclassifications	0		0
Reclassifications	432		465
Other Comprehensive Income (Loss)	432		465
AOCI - Ending Balance	($16,121)		($20,787)
[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.