UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

~~(Mark One)~~



X☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
	EXCHANGE ACT OF 1934
	For the quarterly period ended		June 30, ~~2018~~2019
	OR
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
	EXCHANGE ACT OF 1934
	For the transition period from __________ to __________
		Exact name of registrants as specified		I.R.S. Employer
Commission File		in their charters, address of principal		Identification
Number		executive offices, zip code and telephone number		Number
1-14465		IDACORP, Inc.		82-0505802
1-3198		Idaho Power Company		82-0130980



1221 W. Idaho Street
Boise, ~~Idaho 83702-5627~~		Idaho		83702-5627
	(208)		388-2200



	State of Incorporation:	Idaho
	~~None~~
None
Former name, former address and former fiscal year, if changed since last report.

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.

IDACORP, Inc.: Yes X No __ Idaho Power Company: Yes X No __

Indicate by check mark whether the registrants have submitted electronically ~~and posted on their corporate Web sites, if any,~~ every Interactive Data File required to be submitted ~~and posted~~ pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrants were required to submit ~~and post~~ such files).

IDACORP, Inc.: Yes X No __ Idaho Power Company: Yes X No __

Indicate by check mark whether the registrants are large accelerated filers, accelerated filers, non-accelerated filers, smaller reporting companies, or emerging growth companies. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange ~~Act (check one):~~Act:

IDACORP, Inc.:

Large accelerated filer X Accelerated filer __ Non-accelerated filer __ ~~(Do not check if a smaller reporting company)~~

Smaller reporting company __☐

Emerging growth company __☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange

Act. __

Idaho Power Company:

Large accelerated filer __ Accelerated filer __ Non-accelerated ~~filer~~ Filer X ~~(Do not check if a smaller reporting company)~~

Smaller reporting company __☐

Emerging growth company __☐

Act. __

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Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act).

IDACORP, Inc.: Yes __☐ No X Idaho Power Company: Yes __☐ No X

Securities registered pursuant to Section 12(b) of the Securities Exchange Act of 1934:



Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock	IDA	New York Stock Exchange

Number of shares of common stock outstanding as of July ~~27, 2018:~~26, 2019:

IDACORP, Inc.: ~~50,392,903~~50,397,121

Idaho Power Company: 39,150,812, all held by IDACORP, Inc.

This combined Form 10-Q represents separate filings by IDACORP, Inc. and Idaho Power Company. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Idaho Power Company makes no representations as to the information relating to IDACORP, Inc.’s other operations.

Idaho Power Company meets the conditions set forth in General Instruction (H)(1)(a) and (b) of Form 10-Q and is therefore filing this report on Form 10-Q with the reduced disclosure format.

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TABLE OF CONTENTS
				Page
Commonly Used Terms				4
Cautionary Note Regarding Forward-Looking Statements				5

Part I. Financial Information

	Item 1. Financial Statements (unaudited)
		IDACORP, Inc.:
			Condensed Consolidated Statements of Income	7
			Condensed Consolidated Statements of Comprehensive Income	8
			Condensed Consolidated Balance Sheets	9
			Condensed Consolidated Statements of Cash Flows	11
			Condensed Consolidated Statements of Equity	12
		Idaho Power Company:
			Condensed Consolidated Statements of Income	13
			Condensed Consolidated Statements of Comprehensive Income	14
			Condensed Consolidated Balance Sheets	15
			Condensed Consolidated Statements of Cash Flows	17
		Notes to Condensed Consolidated Financial Statements		18
		Reports of Independent Registered Public Accounting Firm		3732
	Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations			3934
	Item 3. Quantitative and Qualitative Disclosures About Market Risk			6455
	Item 4. Controls and Procedures			6656

Part II. Other Information

	Item 1. Legal Proceedings			6757
	Item 1A. Risk Factors			6757
	Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			6757
	Item 3. Defaults Upon Senior Securities			6757
	Item 4. Mine Safety Disclosures			6757
	Item 5. Other Information			6757
	Item 6. Exhibits			6858

Signatures				6959

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COMMONLY USED TERMS

The following select abbreviations, terms, or acronyms are commonly used or found in multiple locations in this report:

2018 Annual Report	-	IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, 2018
ADITC	-	Accumulated Deferred Investment Tax Credits
AFUDC	-	Allowance for Funds Used During Construction
AOCI	-	Accumulated Other Comprehensive Income
ASU	-	Accounting Standards Update
BCC	-	Bridger Coal Company, a joint venture of IERCo
BLM	-	U.S. Bureau of Land Management
CWA	-	Clean Water Act
FASB	-	Financial Accounting Standards Board
FCA	-	Fixed Cost Adjustment
FERC	-	Federal Energy Regulatory Commission
FPA	-	Federal Power Act
HCC	-	Hells Canyon Complex
IDACORP	-	IDACORP, Inc., an Idaho corporation
Idaho Power	-	Idaho Power Company, an Idaho corporation
Idaho ROE	-	Idaho-jurisdiction return on year-end equity
Ida-West	-	Ida-West Energy, a subsidiary of IDACORP, Inc.
IERCo	-	Idaho Energy Resources Co., a subsidiary of Idaho Power Company
IFS	-	IDACORP Financial Services, a subsidiary of IDACORP, Inc.
IPUC	-	Idaho Public Utilities Commission
IRP	-	Integrated Resource Plan
MD&A	-	Management’s Discussion and Analysis of Financial Condition and Results of Operations
MW	-	Megawatt
MWh	-	Megawatt-hour
O&M	-	Operations and Maintenance
OATT	-	Open Access Transmission Tariff
OPUC	-	Public Utility Commission of Oregon
PCA	-	~~Idaho~~Idaho-Jurisdiction Power Cost Adjustment
PURPA	-	Public Utility Regulatory Policies Act of 1978
SEC	-	U.S. Securities and Exchange Commission
SMSP	-	Security Plan for Senior Management Employees
Valmy Plant	-	North Valmy coal-fired power plant
Western EIM	-	Energy imbalance market implemented in the western United States
WPSC	-	Wyoming Public Service Commission

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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

In addition to the historical information contained in this report, this report contains (and oral communications made by IDACORP, Inc. (IDACORP) and Idaho Power Company (Idaho Power) may contain) statements that relate to future events and expectations, such as statements regarding projected or future financial performance, cash flows, capital expenditures, dividends, capital structure or ratios, strategic goals, challenges, objectives, and plans for future operations. Such statements constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Any statements that express, or involve discussions as to, expectations, beliefs, plans, objectives, assumptions, or future events, or performance, often, but not always, through the use of words or phrases such as "anticipates," "believes," "continues," "could," "estimates," "expects," "guidance," "intends," "potential," "plans," "predicts," "projects," "may result," "may continue," or similar expressions, are not statements of historical facts and may be forward-looking. Forward-looking statements are not guarantees of future performance and involve estimates, assumptions, risks, and uncertainties. Actual results, performance, or outcomes may differ materially from the results discussed in the statements. In addition to any assumptions and other factors and matters referred to specifically in connection with such forward-looking statements, factors that could cause actual results or outcomes to differ materially from those contained in forward-looking statements include those factors set forth in this report, IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, ~~2017,~~2018, particularly Part I, Item 1A - "Risk Factors" and Part II, Item 7 - "Management’s Discussion and Analysis of Financial Condition and Results of Operations" of that report, subsequent reports filed by IDACORP and Idaho Power with the U.S. Securities and Exchange Commission, and the following important factors:

the effect of decisions by the Idaho and Oregon public utilities commissions and the Federal Energy Regulatory Commission ~~which~~that impact Idaho Power's ability to recover costs and earn a return on investment;

the expense and risks associated with capital expenditures for utility infrastructure, and the timing and availability of cost recovery for such expenditures through customer rates, including the potential for the write-down or write-off of ~~assets~~expenditures if not deemed prudent by regulators;

changes in residential, commercial, and industrial growth and demographic patterns within Idaho Power's service area, the loss or change in the business of significant customers, or the addition of new customers, and their associated impacts on loads and load growth, and the availability of regulatory mechanisms that allow for timely cost recovery through customer rates in the event of those changes;

the impacts of economic conditions, including inflation, interest rates, regulatory authorized ~~regulatory~~ returns on equity, supply costs, population growth or decline in Idaho Power's service area, changes in customer demand for electricity, revenue from sales of excess power, ~~financial soundness~~credit quality of counterparties and suppliers, and the collection of receivables;

unseasonable or severe weather conditions, wildfires, ~~drought,~~droughts, and other natural phenomena and natural disasters, including conditions and events associated with climate change, which affect customer demand, ~~hydroelectric~~hydropower generation levels, repair costs, liability for damage caused by utility property, including from wildfires, and the availability and cost of fuel for generation plants or purchased power to serve customers;

advancement of self-generation, orenergy storage, grid-connected devices, and energy efficiency technologies that ~~reduce~~may affect Idaho Power's sale or delivery of electric ~~power;~~power or introduce new cyber security risks;

changes in tax laws or related regulations or new interpretations of applicable laws by federal, state, or local taxing jurisdictions, the availability of tax credits, and the tax rates payable by IDACORP shareholders on common stock dividends;

adoption of, changes in, and costs of compliance with laws, regulations, and policies relating to the environment, natural resources, and threatened and endangered species, and the ability to recover ~~resulting~~associated increased costs through rates;

variable hydrological conditions ~~and/or~~and over-appropriation of surface and groundwater in the Snake River Basin, which may impact the amount of power generated by Idaho Power's ~~hydroelectric~~hydropower facilities;

the ability to acquire fuel, power, and transmission capacity under reasonable terms, particularly in the event of unanticipated power demands, lack of physical availability, transportation constraints, or a credit downgrade;

accidents, fires (either ataffecting or caused by Idaho ~~Power's~~Power facilities or infrastructure), explosions, and mechanical breakdowns that may occur while operating and maintaining Idaho ~~Power's~~Power assets, which can cause unplanned outages, reduce generating output, damage the companies’ assets, operations, or reputation, subject the companies to third-party claims for property damage, personal injury, or loss of life, or result in the imposition of civil, criminal, and regulatory fines and ~~penalties;~~penalties for which the companies may have inadequate insurance coverage;

the increased purchased power costs and operational challenges associated with purchasing and integrating intermittent renewable energy sources into Idaho Power's resource portfolio;

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disruptions or outages of Idaho Power's generation or transmission systems or of any interconnected transmission ~~system that~~systems may constrain resources or cause Idaho Power to incur repair costs or purchase replacement power at increased costs;

the ability to obtain debt and equity financing or refinance existing debt when necessary and on favorable terms, which can be affected by factors such as credit ratings, volatility or disruptions in the financial markets, interest rate fluctuations, decisions by the Idaho or Oregon public utility commissions, and the companies' past or projected financial performance;

reductions in credit ratings, which could adversely impact access to ~~capital~~debt and equity markets, increase borrowing costs, and ~~would~~ require the posting of additional collateral to counterparties pursuant to credit and contractual arrangements;

the ability to enter into financial and physical commodity hedges with creditworthy counterparties to manage price and commodity risk, and the failure of any such risk management and hedging strategies to work as intended;

changes in actuarial assumptions, changes in interest rates, and the return on plan assets for pension and other post-retirement plans, which can affect future pension and other postretirement plan funding obligations, costs, and ~~liabilities;~~liabilities and the companies' cash flows;

the ability to continue to pay dividends based on financial performance and in light of contractual covenants and restrictions and regulatory limitations;

employee workforce factors, including the operational and financial costs of unionization or the attempt to unionize all or part of the companies' workforce, the impact of an aging workforce and retirements, the cost and ability to attract and retain skilled workers, and the ability to adjust the labor cost structure when necessary;

failure to comply with state and federal laws, regulations, and orders, including new interpretations and enforcement initiatives by regulatory and oversight bodies, which may result in penalties and fines and increase the cost of compliance, the nature and extent of investigations and audits, and the cost of remediation;

the inability to obtain or cost of obtaining and complying with required governmental permits and approvals, licenses, rights-of-way, and siting for transmission and generation projects and ~~hydroelectric~~hydropower facilities;

the cost and outcome of litigation, dispute resolution, and regulatory proceedings, and the ability to recover those costs or the costs of resulting operational changes through insurance or rates, or from third parties;

the ~~failure of information systems or the~~companies' failure to secure data ~~failure~~or to comply with privacy laws or regulations, security breaches, or the ~~direct~~disruption or ~~indirect effect on~~damage to the companies' business, operations, or reputation resulting from cyber-attacks or related litigation or penalties, terrorist incidents or the threat of terrorist incidents, or other malicious acts, and acts of war;

unusual or unanticipated changes in normal business operations, including unusual maintenance or repairs, or the failure to successfully implement new technology solutions; and

adoption of or changes in accounting policies and principles, changes in accounting estimates, and new U.S. Securities and Exchange Commission or New York Stock Exchange requirements, or new interpretations of existing requirements.

Any forward-looking statement speaks only as of the date on which such statement is made. New factors emerge from time to time and it is not possible for management to predict all such factors, nor can it assess the impact of any such factor on the business or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forward-looking statement. IDACORP and Idaho Power disclaim any obligation to update publicly any forward-looking information, whether in response to new information, future events, or otherwise, except as required by applicable law.

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PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

IDACORP, Inc.

Condensed Consolidated Statements of Income

(unaudited)


	Three months ended June 30,						Six months ended June 30,						Three months ended June 30,						Six months ended June 30,
	2018			2017			2018			2017			2019			2018			2019			2018
	(in thousands, except per share amounts)												(in thousands, except per share amounts)
Operating Revenues:
Electric utility revenues	$	338,699		$	331,768		$	648,160		$	633,732		$	315,774		$	338,699		$	665,546		$	648,160
Other	1,253			1,238			1,898			1,818			1,121			1,253			1,668			1,898
Total operating revenues	339,952			333,006			650,058			635,550			316,895			339,952			667,214			650,058

Operating Expenses:
Electric utility:
Purchased power	62,980			61,506			124,908			110,622			58,063			62,980			120,894			124,908
Fuel expense	21,515			20,416			49,250			56,668			20,826			21,515			72,696			49,250
Power cost adjustment	19,963			16,742			45,501			40,229			16,122			19,963			42,347			45,501
Other operations and maintenance	92,314			86,729			178,512			173,720			87,007			92,314			175,913			178,512
Energy efficiency programs	8,802			10,515			16,399			16,843			11,458			8,802			21,570			16,399
Depreciation	41,348			45,240			81,416			82,002			41,172			41,348			83,406			81,416
Taxes other than income taxes	9,118			8,843			18,395			17,521			9,377			9,118			18,237			18,395
Total electric utility expenses	256,040			249,991			514,381			497,605			244,025			256,040			535,063			514,381
Other	1,077			1,108			2,253			2,411			1,090			1,077			2,252			2,253
Total operating expenses	257,117			251,099			516,634			500,016			245,115			257,117			537,315			516,634

Operating Income	82,835			81,907			133,424			135,534			71,780			82,835			129,899			133,424

Allowance for Equity Funds Used During Construction	5,985			5,611			12,018			10,843			6,699			5,985			13,054			12,018

Earnings of Equity-Method Investments	1,537			592			5,552			2,037
Earnings of Unconsolidated Equity-Method Investments													2,997			1,537			5,379			5,552

Other Income (Expense), Net	309			(426		)	(150		)	(841		)	1,060			309			3,173			(150		)

Interest Expense:
Interest on long-term debt	21,412			20,300			42,099			40,597			21,156			21,412			42,310			42,099
Other interest	2,162			2,756			5,121			5,471			3,685			2,162			7,138			5,121
Allowance for borrowed funds used during construction	(2,606		)	(2,408		)	(5,078		)	(4,720		)	(2,733		)	(2,606		)	(5,324		)	(5,078		)
Total interest expense, net	20,968			20,648			42,142			41,348			22,108			20,968			44,124			42,142

Income Before Income Taxes	69,698			67,036			108,702			106,225			60,428			69,698			107,381			108,702

Income Tax Expense	7,105			16,940			9,998			23,124			7,028			7,105			11,344			9,998

Net Income	62,593			50,096			98,704			83,101			53,400			62,593			96,037			98,704
Adjustment for income attributable to noncontrolling interests	(305		)	(265		)	(274		)	(168		)
Income attributable to noncontrolling interests													(244		)	(305		)	(195		)	(274		)
Net Income Attributable to IDACORP, Inc.	$	62,288		$	49,831		$	98,430		$	82,933		$	53,156		$	62,288		$	95,842		$	98,430
Weighted Average Common Shares Outstanding - Basic	50,435			50,363			50,430			50,361			50,499			50,435			50,504			50,430
Weighted Average Common Shares Outstanding - Diluted	50,481			50,407			50,472			50,402			50,507			50,481			50,512			50,472
Earnings Per Share of Common Stock:
Earnings Attributable to IDACORP, Inc. - Basic	$	1.24		$	0.99		$	1.95		$	1.65		$	1.05		$	1.24		$	1.90		$	1.95
Earnings Attributable to IDACORP, Inc. - Diluted	$	1.23		$	0.99		$	1.95		$	1.65		$	1.05		$	1.23		$	1.90		$	1.95
Dividends Declared Per Share of Common Stock	$	0.59		$	0.55		$	1.18		$	1.10

The accompanying notes are an integral part of these statements.

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IDACORP, Inc.

Condensed Consolidated Statements of Comprehensive Income

(unaudited)


	Three months ended June 30,						Six months ended June 30,						Three months ended June 30,						Six months ended June 30,
	2018			2017			2018			2017			2019			2018			2019			2018
	(in thousands)												(in thousands)

Net Income	$	62,593		$	50,096		$	98,704		$	83,101		$	53,400		$	62,593		$	96,037		$	98,704
Other Comprehensive Income:
Unfunded pension liability adjustment, net of tax of $250, $302, $500, and $604	722			470			1,443			941
Unfunded pension liability adjustment, net of tax of $169, $250, $338, and $500, respectively													488			722			976			1,443
Total Comprehensive Income	63,315			50,566			100,147			84,042			53,888			63,315			97,013			100,147
Comprehensive income attributable to noncontrolling interests	(305		)	(265		)	(274		)	(168		)
Income attributable to noncontrolling interests													(244		)	(305		)	(195		)	(274		)
Comprehensive Income Attributable to IDACORP, Inc.	$	63,010		$	50,301		$	99,873		$	83,874		$	53,644		$	63,010		$	96,818		$	99,873

The accompanying notes are an integral part of these statements.

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IDACORP, Inc.

Condensed Consolidated Balance Sheets

(unaudited)


	June 30, 2018			December 31, 2017			June 30, 2019			December 31, 2018
	(in thousands)						(in thousands)
Assets

Current Assets:
Cash and cash equivalents	$	183,141		$	76,649		$	239,664		$	267,492
Receivables:
Customer (net of allowance of $1,913 and $2,013, respectively)	87,975			75,249
Other (net of allowance of $205 and $180, respectively)	5,284			30,438
Taxes receivable	2,929			8,147
Customer (net of allowance of $1,456 and $1,725, respectively)							83,646			77,178
Other (net of allowance of $290 and $264, respectively)							13,535			7,476
Income taxes receivable							—			4,356
Accrued unbilled revenues	79,818			75,120			73,226			69,318
Materials and supplies (at average cost)	60,229			55,745			58,441			54,987
Fuel stock (at average cost)	66,389			56,638			55,973			47,979
Prepayments	14,852			16,984			17,023			16,492
Current regulatory assets	37,977			48,613			53,660			48,707
Other	757			18			4,285			3,655
Total current assets	539,351			443,601			599,453			597,640
Investments	106,558			115,698			94,503			101,178
Property, Plant and Equipment:
Utility plant in service	6,005,176			5,906,162			6,197,160			6,103,856
Accumulated provision for depreciation	(2,162,143		)	(2,098,274		)	(2,269,628		)	(2,210,781		)
Utility plant in service - net	3,843,033			3,807,888			3,927,532			3,893,075
Construction work in progress	465,413			452,424			501,550			480,259
Utility plant held for future use	4,727			8,075			4,689			4,751
Other property, net of accumulated depreciation	17,908			15,488			17,425			17,650
Property, plant and equipment - net	4,331,081			4,283,875			4,451,196			4,395,735
Other Assets:
Company-owned life insurance	60,537			59,323			59,726			59,852
Regulatory assets	1,106,110			1,083,483			1,195,079			1,165,467
Other	62,480			59,425			60,896			62,882
Total other assets	1,229,127			1,202,231			1,315,701			1,288,201
Total	$	6,206,117		$	6,045,405		$	6,460,853		$	6,382,754

The accompanying notes are an integral part of these statements.

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IDACORP, Inc.

Condensed Consolidated Balance Sheets

(unaudited)


	June 30, 2018			December 31, 2017			June 30, 2019			December 31, 2018
	(in thousands)						(in thousands)
Liabilities and Equity

Current Liabilities:
Accounts payable	$	74,804		$	90,277		$	80,651		$	110,824
Taxes accrued	28,807			11,075			31,183			12,009
Interest accrued	23,153			22,379			23,599			23,622
Accrued compensation	40,004			47,018			39,564			55,121
Current regulatory liabilities	30,876			1,404			67,458			25,883
Advances from customers	28,408			18,414			37,401			20,037
Other	11,952			10,182			15,726			11,096
Total current liabilities	238,004			200,749			295,582			258,592
Other Liabilities:
Deferred income taxes	642,013			660,940			689,901			699,878
Regulatory liabilities	720,574			698,044			750,811			738,994
Pension and other postretirement benefits	429,513			438,869			433,725			431,475
Other	43,751			44,566			45,862			43,216
Total other liabilities	1,835,851			1,842,419			1,920,299			1,913,563
Long-Term Debt	1,834,055			1,746,123			1,835,521			1,834,788
Commitments and Contingencies
Equity:
IDACORP, Inc. shareholders’ equity:
Common stock, no par value (120,000 shares authorized; 50,420 shares issued)	859,652			857,207			864,266			863,593
Retained earnings	1,465,009			1,426,528			1,563,399			1,531,543
Accumulated other comprehensive loss	(29,521		)	(30,964		)	(21,868		)	(22,844		)
Treasury stock (27 shares and 28 shares, respectively, at cost)	(1,936		)	(1,386		)
Treasury stock (23 shares and 27 shares, respectively, at cost)							(1,992		)	(1,932		)
Total IDACORP, Inc. shareholders’ equity	2,293,204			2,251,385			2,403,805			2,370,360
Noncontrolling interests	5,003			4,729			5,646			5,451
Total equity	2,298,207			2,256,114			2,409,451			2,375,811
Total	$	6,206,117		$	6,045,405		$	6,460,853		$	6,382,754

The accompanying notes are an integral part of these statements.

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IDACORP, Inc.

Condensed Consolidated Statements of Cash Flows

(unaudited)


	Six months ended June 30,						Six months ended June 30,
	2018			2017			2019			2018
	(in thousands)						(in thousands)
Operating Activities:
Net income	$	98,704		$	83,101		$	96,037		$	98,704
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	83,306			83,912			85,655			83,306
Deferred income taxes and investment tax credits	(9,708		)	6,828			(6,177		)	(9,708		)
Changes in regulatory assets and liabilities	45,691			37,736			31,643			45,691
Pension and postretirement benefit plan expense	14,038			14,513			13,894			14,038
Contributions to pension and postretirement benefit plans	(24,516		)	(3,920		)	(14,633		)	(24,516		)
Earnings of equity-method investments	(5,552		)	(2,037		)	(5,379		)	(5,552		)
Distributions from equity-method investments	11,300			8,100			11,800			11,300
Allowance for equity funds used during construction	(12,018		)	(10,843		)	(13,054		)	(12,018		)
Other non-cash adjustments to net income, net	5,185			3,741			3,923			5,185
Change in:
Accounts receivable	(5,937		)	(5,406		)	(9,333		)	(5,937		)
Accounts payable and other accrued liabilities	(13,010		)	(30,677		)	(44,286		)	(13,010		)
Taxes accrued/receivable	22,950			18,073			23,530			22,950
Other current assets	(16,152		)	(16,951		)	(16,454		)	(16,152		)
Other current liabilities	9,054			6,948			9,350			9,054
Other assets	(5,439		)	(3,692		)	(1,482		)	(5,439		)
Other liabilities	(1,472		)	(430		)	1,039			(1,472		)
Net cash provided by operating activities	196,424			188,996			166,073			196,424
Investing Activities:
Additions to property, plant and equipment	(133,598		)	(146,341		)	(129,860		)	(133,598		)
Payments received from transmission project joint funding partners	20,323			5,787			1,016			20,323
Proceeds from the sale of emission allowances and renewable energy certificates	1,650			1,839			3,702			1,650
Investments in affordable housing							(2,687		)	—
Purchase of equity securities	(228		)	(3,165		)	(470		)	(228		)
Proceeds from the sale of equity securities	2,450			2,428			2,546			2,450
Other	495			2,860			91			495
Net cash used in investing activities	(108,908		)	(136,592		)	(125,662		)	(108,908		)
Financing Activities:
Issuance of long-term debt	220,000			—			—			220,000
Retirement of long-term debt	(130,000		)	(1,064		)	—			(130,000		)
Dividends on common stock	(59,941		)	(55,763		)	(64,077		)	(59,941		)
Net change in short-term borrowings	—			(21,250		)
Acquisition of treasury stock	(3,551		)	(3,174		)	(4,107		)	(3,551		)
Make-whole premium on retirement of long-term debt	(4,607		)	—			—			(4,607		)
Other	(2,925		)	(4		)
Net cash provided by (used in) financing activities	18,976			(81,255		)
Net increase (decrease) in cash and cash equivalents	106,492			(28,851		)
Debt issuance costs and other							(55		)	(2,925		)
Net cash (used in) provided by financing activities							(68,239		)	18,976
Net (decrease) increase in cash and cash equivalents							(27,828		)	106,492
Cash and cash equivalents at beginning of the period	76,649			61,480			267,492			76,649
Cash and cash equivalents at end of the period	$	183,141		$	32,629		$	239,664		$	183,141
Supplemental Disclosure of Cash Flow Information:
Cash paid during the period for:
Income taxes	$	—		$	1,202		$	—		$	—
Interest (net of amount capitalized)	$	39,494		$	39,481		42,204			39,494
Non-cash investing activities:
Additions to property, plant and equipment in accounts payable	$	20,650		$	21,410		$	26,700		$	20,650

The accompanying notes are an integral part of these statements.

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IDACORP, Inc.

Condensed Consolidated Statements of Equity

(unaudited)


	Six months ended June 30,						Three months ended June 30,						Six months ended June 30,
	2018			2017			2019			2018			2019			2018
	(in thousands)						(in thousands)						(in thousands)
Common Stock
Balance at beginning of period	$	857,207		$	851,833		$	863,425		$	857,533		$	863,593		$	857,207
Share-based compensation expense and other	2,445			1,771
Share-based compensation expense							1,830			2,870			4,667			5,411
Treasury shares issued							(1,016		)	(770		)	(4,047		)	(3,007		)
Other							27			19			53			41
Balance at end of period	859,652			853,604			864,266			859,652			864,266			859,652
Retained Earnings
Balance at beginning of period	1,426,528			1,323,198			1,542,175			1,432,584			1,531,543			1,426,528
Net income attributable to IDACORP, Inc.	98,430			82,933			53,156			62,288			95,842			98,430
Common stock dividends ($1.18 and $1.10 per share)	(59,949		)	(55,594		)
Common stock dividends ($0.63, $0.59, $1.26, and $1.18 per share, respectively)							(31,932		)	(29,863		)	(63,986		)	(59,949		)
Balance at end of period	1,465,009			1,350,537			1,563,399			1,465,009			1,563,399			1,465,009
Accumulated Other Comprehensive (Loss) Income
Balance at beginning of period	(30,964		)	(20,882		)	(22,356		)	(30,243		)	(22,844		)	(30,964		)
Unfunded pension liability adjustment (net of tax)	1,443			941			488			722			976			1,443
Balance at end of period	(29,521		)	(19,941		)	(21,868		)	(29,521		)	(21,868		)	(29,521		)
Treasury Stock
Balance at beginning of period	(1,386		)	(243		)	(3,008		)	(2,706		)	(1,932		)	(1,386		)
Issued	3,007			2,060			1,016			770			4,047			3,007
Acquired	(3,557		)	(3,174		)	—			—			(4,107		)	(3,557		)
Balance at end of period	(1,936		)	(1,357		)	(1,992		)	(1,936		)	(1,992		)	(1,936		)
Total IDACORP, Inc. shareholders’ equity at end of period	2,293,204			2,182,843			2,403,805			2,293,204			2,403,805			2,293,204
Noncontrolling Interests
Balance at beginning of period	4,729			3,960			5,402			4,698			5,451			4,729
Net income attributable to noncontrolling interests	274			168			244			305			195			274
Balance at end of period	5,003			4,128			5,646			5,003			5,646			5,003
Total equity at end of period	$	2,298,207		$	2,186,971		$	2,409,451		$	2,298,207		$	2,409,451		$	2,298,207

The accompanying notes are an integral part of these statements.

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Idaho Power Company

Condensed Consolidated Statements of Income

(unaudited)


	Three months ended June 30,						Six months ended June 30,						Three months ended June 30,						Six months ended June 30,
	2018			2017			2018			2017			2019			2018			2019			2018
	(in thousands)												(in thousands)

Operating Revenues	$	338,699		$	331,768		$	648,160		$	633,732		$	315,774		$	338,699		$	665,546		$	648,160

Operating Expenses:
Operation:
Purchased power	62,980			61,506			124,908			110,622			58,063			62,980			120,894			124,908
Fuel expense	21,515			20,416			49,250			56,668			20,826			21,515			72,696			49,250
Power cost adjustment	19,963			16,742			45,501			40,229			16,122			19,963			42,347			45,501
Other operations and maintenance	92,314			86,729			178,512			173,720			87,007			92,314			175,913			178,512
Energy efficiency programs	8,802			10,515			16,399			16,843			11,458			8,802			21,570			16,399
Depreciation	41,348			45,240			81,416			82,002			41,172			41,348			83,406			81,416
Taxes other than income taxes	9,118			8,843			18,395			17,521			9,377			9,118			18,237			18,395
Total operating expenses	256,040			249,991			514,381			497,605			244,025			256,040			535,063			514,381

Income from Operations	82,659			81,777			133,779			136,127			71,749			82,659			130,483			133,779

Other Income (Expense):
Allowance for equity funds used during construction	5,985			5,611			12,018			10,843			6,699			5,985			13,054			12,018
Earnings (losses) of equity-method investments	683			(337		)	4,825			917
Other expense, net	(391		)	(1,000		)	(1,519		)	(2,297		)
Earnings of unconsolidated equity-method investments													2,034			683			4,265			4,825
Other income (expense), net													165			(391		)	1,087			(1,519		)
Total other income	6,277			4,274			15,324			9,463			8,898			6,277			18,406			15,324

Interest Expense:
Interest Charges:
Interest on long-term debt	21,412			20,300			42,099			40,597			21,156			21,412			42,310			42,099
Other interest	2,148			2,740			5,093			5,438			3,677			2,148			7,106			5,093
Allowance for borrowed funds used during construction	(2,606		)	(2,408		)	(5,078		)	(4,720		)	(2,733		)	(2,606		)	(5,324		)	(5,078		)
Total interest expense, net	20,954			20,632			42,114			41,315
Total interest charges													22,100			20,954			44,092			42,114

Income Before Income Taxes	67,982			65,419			106,989			104,275			58,547			67,982			104,797			106,989

Income Tax Expense	7,345			17,038			10,496			23,412			7,371			7,345			12,037			10,496

Net Income	$	60,637		$	48,381		$	96,493		$	80,863		$	51,176		$	60,637		$	92,760		$	96,493

The accompanying notes are an integral part of these statements.

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Idaho Power Company

Condensed Consolidated Statements of Comprehensive Income

(unaudited)


	Three months ended June 30,				Six months ended June 30,				Three months ended June 30,				Six months ended June 30,
	2018		2017		2018		2017		2019		2018		2019		2018
	(in thousands)								(in thousands)

Net Income	$	60,637	$	48,381	$	96,493	$	80,863	$	51,176	$	60,637	$	92,760	$	96,493
Other Comprehensive Income:
Unfunded pension liability adjustment, net of tax of $250, $302, $500, and $604	722		470		1,443		941
Unfunded pension liability adjustment, net of tax of $169, $250, $338, and $500, respectively									488		722		976		1,443
Total Comprehensive Income	$	61,359	$	48,851	$	97,936	$	81,804	$	51,664	$	61,359	$	93,736	$	97,936

The accompanying notes are an integral part of these statements.

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Idaho Power Company

Condensed Consolidated Balance Sheets

(unaudited)


	June 30, 2018			December 31, 2017			June 30, 2019			December 31, 2018
	(in thousands)						(in thousands)
Assets

Electric Plant:
In service (at original cost)	$	6,005,176		$	5,906,162		$	6,197,160		$	6,103,856
Accumulated provision for depreciation	(2,162,143		)	(2,098,274		)	(2,269,628		)	(2,210,781		)
In service - net	3,843,033			3,807,888			3,927,532			3,893,075
Construction work in progress	465,413			452,424			501,550			480,259
Held for future use	4,727			8,075			4,689			4,751
Electric plant - net	4,313,173			4,268,387			4,433,771			4,378,085
Investments and Other Property	93,710			99,904			80,792			90,019
Current Assets:
Cash and cash equivalents	149,150			44,646			140,130			165,460
Receivables:
Customer (net of allowance of $1,913 and $2,013, respectively)	87,975			75,249
Other (net of allowance of $205 and $180, respectively)	5,143			30,274
Taxes receivable	—			26,492
Customer (net of allowance of $1,456 and $1,725, respectively)							83,646			77,178
Other (net of allowance of $290 and $264, respectively)							13,254			7,206
Income taxes receivable							—			11,829
Accrued unbilled revenues	79,818			75,120			73,226			69,318
Materials and supplies (at average cost)	60,229			55,745			58,441			54,987
Fuel stock (at average cost)	66,389			56,638			55,973			47,979
Prepayments	14,729			16,866			16,898			16,374
Current regulatory assets	37,977			48,613			53,660			48,707
Other	757			18			4,285			3,655
Total current assets	502,167			429,661			499,513			502,693
Deferred Debits:
Company-owned life insurance	60,537			59,323			59,726			59,852
Regulatory assets	1,106,110			1,083,483			1,195,079			1,165,467
Other	57,805			54,677			56,371			58,284
Total deferred debits	1,224,452			1,197,483			1,311,176			1,283,603
Total	$	6,133,502		$	5,995,435		$	6,325,252		$	6,254,400

The accompanying notes are an integral part of these statements.

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Idaho Power Company

Condensed Consolidated Balance Sheets

(unaudited)


	June 30, 2018			December 31, 2017			June 30, 2019			December 31, 2018
	(in thousands)						(in thousands)
Capitalization and Liabilities

Capitalization:
Common stock equity:
Common stock, $2.50 par value (50,000 shares authorized; 39,151 shares outstanding)	$	97,877		$	97,877		$	97,877		$	97,877
Premium on capital stock	712,258			712,258			712,258			712,258
Capital stock expense	(2,097		)	(2,097		)	(2,097		)	(2,097		)
Retained earnings	1,345,246			1,308,702			1,438,019			1,409,245
Accumulated other comprehensive loss	(29,521		)	(30,964		)	(21,868		)	(22,844		)
Total common stock equity	2,123,763			2,085,776			2,224,189			2,194,439
Long-term debt	1,834,055			1,746,123			1,835,521			1,834,788
Total capitalization	3,957,818			3,831,899			4,059,710			4,029,227
Current Liabilities:
Accounts payable	74,694			89,978			80,530			110,597
Accounts payable to affiliates	44,202			57,562			2,315			2,088
Taxes accrued	21,884			10,904			25,553			11,750
Interest accrued	23,153			22,379			23,599			23,622
Accrued compensation	39,863			46,832			39,435			54,910
Current regulatory liabilities	30,876			1,404			67,458			25,883
Advances from customers	28,408			18,414			37,401			20,037
Other	11,365			9,556			14,971			10,198
Total current liabilities	274,445			257,029			291,262			259,085
Deferred Credits:
Deferred income taxes	708,205			725,942			744,674			753,239
Regulatory liabilities	720,574			698,044			750,811			738,994
Pension and other postretirement benefits	429,513			438,869			433,725			431,475
Other	42,947			43,652			45,070			42,380
Total deferred credits	1,901,239			1,906,507			1,974,280			1,966,088

Commitments and Contingencies

Total	$	6,133,502		$	5,995,435		$	6,325,252		$	6,254,400

The accompanying notes are an integral part of these statements.

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Idaho Power Company

Condensed Consolidated Statements of Cash Flows

(unaudited)


	Six months ended June 30,						Six months ended June 30,
	2018			2017			2019			2018
	(in thousands)						(in thousands)
Operating Activities:
Net income	$	96,493		$	80,863		$	92,760		$	96,493
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	83,007			83,611			85,355			83,007
Deferred income taxes and investment tax credits	(9,505		)	6,144			(5,919		)	(9,505		)
Changes in regulatory assets and liabilities	45,691			37,736			31,643			45,691
Pension and postretirement benefit plan expense	14,038			14,513			13,894			14,038
Contributions to pension and postretirement benefit plans	(24,516		)	(3,920		)	(14,633		)	(24,516		)
Earnings of equity-method investments	(4,825		)	(917		)	(4,265		)	(4,825		)
Distributions from equity-method investments	11,300			8,100			11,800			11,300
Allowance for equity funds used during construction	(12,018		)	(10,843		)	(13,054		)	(12,018		)
Other non-cash adjustments to net income, net	(220		)	(47		)	(744		)	(220		)
Change in:
Accounts receivable	(4,884		)	(12,446		)	(9,137		)	(4,884		)
Accounts payable	(27,256		)	(1,109		)	(44,180		)	(27,256		)
Taxes accrued/receivable	37,472			13,679			25,632			37,472
Other current assets	(16,145		)	(16,945		)	(16,447		)	(16,145		)
Other current liabilities	9,099			6,974			9,432			9,099
Other assets	(5,439		)	(3,693		)	(1,482		)	(5,439		)
Other liabilities	(1,363		)	(275		)	1,083			(1,363		)
Net cash provided by operating activities	190,929			201,425			161,738			190,929
Investing Activities:
Additions to utility plant	(133,584		)	(146,328		)	(129,860		)	(133,584		)
Payments received from transmission project joint funding partners	20,323			5,787			1,016			20,323
Proceeds from the sale of emission allowances and renewable energy certificates	1,650			1,839			3,702			1,650
Purchase of equity securities	(228		)	(3,165		)	(470		)	(228		)
Proceeds from the sale of equity securities	2,450			2,428			2,546			2,450
Other	440			2,860			(2		)	440
Net cash used in investing activities	(108,949		)	(136,579		)	(123,068		)	(108,949		)
Financing Activities:
Issuance of long-term debt	220,000			—			—			220,000
Retirement of long-term debt	(130,000		)	(1,064		)	—			(130,000		)
Dividends on common stock	(59,949		)	(55,695		)	(63,986		)	(59,949		)
Net change in short term borrowings	—			(21,800		)
Make-whole premium on retirement of long-term debt	(4,607		)	—			—			(4,607		)
Other	(2,920		)	—
Net cash provided by (used in) financing activities	22,524			(78,559		)
Net increase (decrease) in cash and cash equivalents	104,504			(13,713		)
Debt issuance costs							(14		)	(2,920		)
Net cash (used in) provided by financing activities							(64,000		)	22,524
Net (decrease) increase in cash and cash equivalents							(25,330		)	104,504
Cash and cash equivalents at beginning of the period	44,646			44,140			165,460			44,646
Cash and cash equivalents at end of the period	$	149,150		$	30,427		$	140,130		$	149,150
Supplemental Disclosure of Cash Flow Information:
Cash paid to IDACORP related to income taxes	$	—		$	22,861
Cash received from IDACORP related to income taxes							$	2,244		$	—
Cash paid for interest (net of amount capitalized)	$	39,467		$	39,447		42,172			39,467
Non-cash investing activities:
Additions to property, plant and equipment in accounts payable	$	20,650		$	21,410		$	26,700		$	20,650

The accompanying notes are an integral part of these statements.

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IDACORP, INC. AND IDAHO POWER COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

This Quarterly Report on Form 10-Q is a combined report of IDACORP, Inc. (IDACORP) and Idaho Power Company (Idaho Power). Therefore, these Notes to Condensed Consolidated Financial Statements apply to both IDACORP and Idaho Power. However, Idaho Power makes no representation as to the information relating to IDACORP’s other operations.

Nature of Business

IDACORP is a holding company formed in 1998 whose principal operating subsidiary is Idaho Power. Idaho Power is an electric utility engaged in the generation, transmission, distribution, sale, and purchase of electric energy and capacity with a service area covering approximately 24,000 square miles in southern Idaho and eastern Oregon. Idaho Power is regulated primarily by the state utility regulatory commissions of Idaho and Oregon and the Federal Energy Regulatory Commission (FERC). Idaho Power is the parent of Idaho Energy Resources Co. (IERCo), a joint venturer in Bridger Coal Company (BCC), which mines and supplies coal to the Jim Bridger generating plant owned in part by Idaho Power (Jim Bridger plant).

IDACORP’s significant other wholly-owned subsidiaries include IDACORP Financial Services, Inc. (IFS), an investor in affordable housing and other real estate investments, and Ida-West Energy Company (Ida-West), an operator of small ~~hydroelectric~~hydropower generation projects that satisfy the requirements of the Public Utility Regulatory Policies Act of 1978 (PURPA).

Regulation of Utility Operations

As a regulated utility, many of Idaho Power's fundamental business decisions are subject to the approval of governmental agencies, including the prices that Idaho Power is authorized to charge for its electric service. These approvals are a critical factor in determining IDACORP's and Idaho Power's results of operations and financial condition.

IDACORP's and Idaho Power's financial statements reflect the effects of the different ratemaking principles followed by the jurisdictions regulating Idaho Power. The application of accounting principles related to regulated operations sometimes results in Idaho Power recording expenses and revenues in a different period than when an unregulated enterprise would record such expenses and revenues. In these instances, the amounts are deferred or accrued as regulatory assets or regulatory liabilities on the balance sheet. Regulatory assets represent incurred costs that have been deferred because it is probable they will be recovered from customers through future rates. Regulatory liabilities represent obligations to make refunds to customers for previous collections, or represent amounts collected in advance of incurring an expense. The effects of applying these regulatory accounting principles to Idaho Power's operations are discussed in more detail in Note 3 - "Regulatory Matters."

Financial Statements

In the opinion of management of IDACORP and Idaho Power, the accompanying unaudited condensed consolidated financial statements contain all adjustments necessary to present fairly each company's consolidated financial position as of June 30, ~~2018,~~2019, consolidated results of operations for the three and six months ended June 30, ~~2018~~2019 and ~~2017,~~2018, and consolidated cash flows for the six months ended June 30, ~~2018~~2019 and ~~2017.~~2018. These adjustments are of a normal and recurring nature. These financial statements do not contain the complete detail or ~~footnote disclosure~~note disclosures concerning accounting policies and other matters that would be included in full-year financial statements and should be read in conjunction with the audited consolidated financial statements included in IDACORP’s and Idaho Power’s Annual Report on Form 10-K for the year ended December 31, ~~2017.~~2018 (2018 Annual Report). The results of operations for the interim period are not necessarily indicative of the results to be expected for the full year. A change in management's estimates or assumptions could have a material impact on IDACORP's or Idaho Power's respective financial condition and results of operations during the period in which such change occurred.

Management Estimates

Management makes estimates and assumptions when preparing financial statements in conformity with generally accepted accounting principles. These estimates and assumptions include those related to rate regulation, retirement benefits, contingencies, asset impairment, income taxes, unbilled revenues, and bad debt. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. These estimates involve judgments

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with respect to, among other things, future economic factors that are difficult to predict and are beyond management's control. Accordingly, actual results could differ from those estimates.

New and Recently Adopted Accounting Pronouncements

Recently Adopted Accounting Pronouncements

In ~~May 2014,~~February 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) ~~2014-09,~~ ~~Revenue from Contracts with Customers (Topic 606)~~. ASU 2014-09 is intended to enable users of financial statements to better understand and consistently analyze an entity's revenue across industries, transactions, and geographies. Under the ASU, recognition of revenue occurs when a customer obtains control of promised goods or services. In addition, the ASU requires disclosure of the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The FASB amended certain aspects of ASU 2014-09 to clarify the implementation guidance, including clarifications related to principal versus agent considerations, licensing and identifying performance obligations, narrow scope improvements, and practical expedients. IDACORP and Idaho Power adopted ASU 2014-09 on January 1, 2018, using the modified-retrospective approach as provided for in the standard. The adoption did not change the timing or amounts of revenue currently recognized by the companies, so no cumulative-effect adjustment was required. The adoption did change presentation of revenues on the condensed consolidated statements of income and also added disclosures. To conform with current period presentation, electric utility revenues on IDACORP's and Idaho Power's condensed consolidated statements of income for the three and six months ended June 30, 2018 and 2017, which had previously been reported separately as "General business," "Off-system sales," and "Other revenues," are no longer reported separately. See Note 4 - "Revenues" for additional information on the disaggregation of revenue and additional disclosures.

~~In January 2016, the FASB issued ASU 2016-01,~~ ~~Financial Instruments—Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities,~~ which revises the accounting related to the classification and measurement of investments in equity securities and the presentation of certain fair value changes for financial liabilities measured at fair value. It also amends certain disclosure requirements associated with the fair value of financial instruments. The new standard is effective for fiscal years beginning after December 15, 2017, including interim periods. IDACORP and Idaho Power adopted ASU 2016-01 on January 1, 2018. The adoption did not have a material impact on the companies' financial statements as the companies previously elected the fair value option and reported available-for-sale securities at fair value.

~~In August 2016, the FASB issued ASU 2016-15,~~ ~~Statement of Cash Flows (Topic 230) Classification of Certain Cash Receipts and Cash Payments~~, to reduce diversity in practice in how certain cash receipts and cash payments are classified in the statement of cash flows. The companies' classification of proceeds from the settlement of corporate-owned life insurance policies and related costs will be classified as investing activities under the new guidance. The new guidance did not affect the companies' presentation of debt prepayment and extinguishment costs, proceeds from the settlement of insurance claims (other than corporate-owned life insurance), and distributions received from equity-method investments. IDACORP and Idaho Power adopted ASU 2016-15 on January 1, 2018, using the retrospective approach as provided for in the standard. To conform with current period presentation, the companies reclassified $2.6 million of company-owned life insurance proceeds received for the six months ended June 30, 2017, to "Other" within "Investing Activities" from "Change in accounts receivable" within "Operating Activities" on the condensed consolidated statements of cash flows.

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~~In March 2017, the FASB issued ASU 2017-07,~~ ~~Compensation -- Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,~~ which requires employers to disaggregate the service cost component from other components of net periodic benefit costs and to disclose the amounts of net periodic benefit costs that are included in each income statement line item. The standard requires employers to present the service cost component in the same line item as other compensation costs and to present the other components of net periodic benefit costs (which include interest costs, expected return on plan assets, amortization of prior service cost or credits, and actuarial gains and losses) separately and outside a subtotal of operating income. In addition, only the service cost component is eligible for capitalization. Idaho Power capitalizes amounts of pension or postretirement costs that are insignificant to the consolidated financial statements. The amendments in ASU 2017-07 are effective for interim and annual reporting periods beginning after December 15, 2017. Entities must use (1) a retrospective transition method to adopt the requirement for separate presentation in the income statement of service costs and other components and (2) a prospective transition method to adopt the requirement to limit the capitalization of benefit costs to the service cost component. IDACORP and Idaho Power adopted ASU 2017-07 on January 1, 2018, and accordingly, have retrospectively adjusted prior periods to reflect the disaggregation of service cost from other components of net periodic benefit costs. The adoption did not have a material impact on the companies' financial statements nor did it affect net income for the three and six months ended June 30, 2018. For IDACORP, for the three and six months ended June 30, 2017, $0.8 million and $1.5 million, respectively, were reclassified out of "Other operations and maintenance" and $2.0 million and $4.1 million, respectively, were reclassified out of "Other" operating expenses for a total of $2.8 million and $5.6 million, respectively, reclassified to "Other Income (Expense), Net" to conform to current period presentation. For Idaho Power, for the three and six months ended June 30, 2017, $0.8 million and $1.5 million, respectively, were reclassified from "Other operations and maintenance" to "Other expense, net" to conform to current period presentation.

~~Recent Accounting Pronouncements Not Yet Adopted~~

~~In February 2016, the FASB issued ASU~~ 2016-02, Leases (Topic 842), intended to improve financial reporting on leasing transactions. The ASU ~~significantly changes the accounting model used by~~requires lessees to ~~account for leases, requiring that all material leases be presented on the balance sheet. Under the current model, some leases are classified as capital leases~~recognize a right-of-use asset and ~~recorded~~lease liability on the balance sheet ~~while other leases are classified as operating leases~~for most leases. In addition, the ASU revises the definition of a lease in regards to when an arrangement conveys the right to control the use of the identified asset under the arrangement. IDACORP and ~~are~~Idaho Power adopted ASU 2016-02 on January 1, 2019. The adoption did not ~~recognized~~have a material impact on their respective financial statements. Neither IDACORP nor Idaho Power has material agreements that meet the ~~balance sheet.~~definition of a lease under ASU 2016-02.

Recent Accounting Pronouncements Not Yet Adopted

In August 2018, the FASB issued ASU 2018-15, Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract,

to provide guidance on implementation costs incurred in a cloud computing arrangement that is a service contract. ASU 2018-15 aligns the accounting for such costs with the guidance on capitalizing costs associated with developing or obtaining internal-use software. The new standard is effective for interim and annual reporting periods beginning after December 15, ~~2018,~~2019, with early adoption permitted. ~~The standard must be adopted using a modified retrospective approach.~~ IDACORP and Idaho Power are evaluating the impact of ASU ~~2016-02~~2018-15 on their respective financial statements. Specifically, the companies are considering whether the new guidance will affect their accounting for purchase power agreements, easements and rights-of-way, utility pole attachments, and other utility industry-related arrangements. At this time, the companies do not know, and cannot reasonably estimate, the dollar impact of the adoption.

~~Reclassifications~~

In these condensed consolidated financial statements, certain amounts in prior periods’ consolidated financial statements have been reclassified to conform with current period presentation. On IDACORP's and Idaho Power's December 31, 2017 condensed consolidated balance sheets, the "Long-term receivables" balances of $4.3 million and $0.5 million, respectively, which had previously been reported separately, were reclassified to "Other" within "Other Assets" and "Deferred Debits," respectively.

2. INCOME TAXES

In accordance with interim reporting requirements, IDACORP and Idaho Power use an estimated annual effective tax rate for computing their provisions for income taxes. An estimate of annual income tax expense (or benefit) is made each interim period using estimates for annual pre-tax income, income tax adjustments, and tax credits. The estimated annual effective tax rates do not include discrete events such as tax law changes, examination settlements, accounting method changes, or adjustments to tax expense or benefits attributable to prior years. Discrete events are recorded in the interim period in which they occur or become known. The estimated annual effective tax rate is applied to year-to-date pre-tax income to determine income tax expense (or benefit) for the interim period consistent with the annual estimate. In subsequent interim periods, income tax expense (or benefit) for the period is computed as the difference between the year-to-date amount reported for the previous interim period and the current period's year-to-date amount.

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Income Tax Expense

The following table provides a summary of income tax expense for the six months ended June 30, 2019 and 2018 (in thousands):


	IDACORP						Idaho Power						IDACORP						Idaho Power
	2018			2017			2018			2017			2019			2018			2019			2018
Income tax at statutory rates (federal and state)	$	27,909		$	41,468		$	27,539		$	40,772		$	27,590		$	27,909		$	26,975		$	27,539
First mortgage bond redemption costs	(1,261		)	—			(1,261		)	—			—			(1,261		)	—			(1,261		)
Share-based compensation	(1,053		)	(1,559		)	(1,040		)	(1,530		)
Excess deferred income tax reversal													(3,262		)	(3,880		)	(3,262		)	(3,880		)
Other⁽¹⁾	(15,597		)	(16,785		)	(14,742		)	(15,830		)	(12,984		)	(12,770		)	(11,676		)	(11,902		)
Income tax expense	$	9,998		$	23,124		$	10,496		$	23,412		$	11,344		$	9,998		$	12,037		$	10,496
Effective tax rate	9.2		%	21.8		%	9.8		%	22.5		%	10.6		%	9.2		%	11.5		%	9.8		%

⁽¹⁾ "Other" is primarily comprised of the net tax effect of Idaho Power's regulatory flow-through tax adjustments.

The ~~decreases~~increase in income tax expense for the six months ended June 30, ~~2018, as~~2019, compared towith the same period in ~~2017, were~~2018, was primarily due ~~to lower statutory tax rates and a flow-through income tax benefit related~~ to the tax deduction for bond redemption costs incurred in the second quarter of 2018. The decrease in statutory rates was due to the 2017 Tax Cuts and Jobs Act, which reduced the U.S. federal corporate income tax rate from 35 percent to 21 percent, and Idaho House Bill 463 which lowered the Idaho state corporate income tax rate from 7.4 percent to 6.925 percent. The federal and Idaho state income tax rate changes were effective January 1, 2018. On a net basis, Idaho Power’s estimate of its annual ~~2018~~2019 regulatory flow-through tax adjustments is comparable to ~~2017.~~2018.

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3. REGULATORY MATTERS

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

Idaho and Oregon General Rate Cases

Idaho Power's current base rates ~~are a~~ result offrom orders from the Idaho Public Utilities Commission (IPUC) and Public Utility Commission of Oregon (OPUC). The commissions approve settlement stipulations that generally provide for cost recovery and an authorized rate of return on their respective Idaho-jurisdiction and Oregon-jurisdiction rate bases. Idaho Power's most recent general rate cases in Idaho and Oregon were filed during 2011 and Idaho Power filed a large single-issue rate ~~case~~cases for the Langley Gulch power plant in Idaho and Oregon in 2012. These significant rate cases resulted in the resetting of base rates in both Idaho and Oregon during 2012. In 2014, Idaho Power ~~also~~ reset its base-rate power supply expenses in the Idaho jurisdiction for purposes of updating the collection of costs through retail rates, ~~in 2014~~ but without a resulting net increase in rates. The IPUC and OPUC have also approved smaller base rate changes in single issue cases subsequent to 2014.

Between general rate cases, Idaho Power relies upon customer growth, a fixed cost adjustment mechanism, power cost adjustment mechanisms, tariff riders, and other mechanisms to reduce the impact of regulatory lag, which refers to the period of time between making an investment or incurring an expense and recovering that investment or expense and earning a return. Also, Idaho Power may seek approval for additions to rate base or changes to base rates through other regulatory proceedings outside of a general rate case. For more information on the Idaho and Oregon general rate cases and base rate adjustments, refer to Note 3 - "Regulatory Matters" to the consolidated financial statements included in ~~IDACORP's and Idaho Power's~~the 2018 Annual ~~Report on Form 10-K for the year ended December 31, 2017.~~Report.

Idaho Settlement Stipulations

In October 2014, the IPUC issued an order approving an extension, with modifications, of the terms of a December 2011 Idaho settlement stipulation for the period from 2015 through 2019, or until the terms are otherwise modified or terminated by order of the IPUC (October 2014 Idaho Earnings Support and Sharing Settlement Stipulation). ~~The provisions~~A May 2018 Idaho settlement stipulation related to tax reform (May 2018 Idaho Tax Reform Settlement Stipulation) provides for the extension of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation beyond the initial termination date of December 31, 2019, with modified terms related to the accumulated deferred investment tax credits (ADITC) and revenue sharing mechanism to become effective beginning January 1, 2020. The October 2014 Idaho Earnings Support and Sharing Settlement Stipulation and the May 2018 Idaho Tax Reform Settlement Stipulation are described in Note 3 - "Regulatory Matters" to the ~~table~~consolidated financial statements included ~~under "Income Tax Reform - Regulatory Treatment" below.~~in the 2018 Annual Report and include provisions for the accelerated amortization of ADITC to help achieve a minimum 9.5 percent (9.4 percent after 2019) return on year-end equity in the Idaho jurisdiction (Idaho ROE). The settlement stipulations also provide for the potential sharing between Idaho Power and Idaho customers of Idaho-jurisdictional earnings in excess of 10.0 percent of Idaho ROE.

~~Under~~Based on its estimate of full-year 2019 Idaho ROE, in both the second quarter and first six months of 2019, Idaho Power recorded no additional ADITC amortization or provision against current revenues for sharing of earnings with customers for 2019 under the October 2014 Idaho Earnings Support and Sharing Settlement ~~Stipulation, during~~Stipulation. During the second quarter of 2018, Idaho Power reversed the $0.5 million of additional ~~accumulated deferred investment tax credits (ADITC)~~ADITC amortization recorded during the first quarter of 2018, based on Idaho Power's current estimate of return on year-end equity in the Idaho jurisdiction (Idaho ROE) for the full-year 2018. During the second quarter of 2017, Idaho Power reversed $1.9 million of additional ADITC amortization recorded during the first quarter of 2017, as actual financial results exceeded Idaho Power's early estimates.

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~~Income Tax Reform - Regulatory Treatment~~

In December 2017, the Tax Cuts and Jobs Act was signed into law, which, among other things, lowered the corporate federal income tax rate from 35 percent to 21 percent and modified or eliminated certain federal income tax deductions for corporations. In March 2018, Idaho House Bill 463 was signed into law reducing the Idaho state corporate income tax rate from 7.4 percent to 6.925 percent. In January 2018, the IPUC issued an order requiring utilities within its jurisdiction, including Idaho Power, to file a report with the IPUC, identifying and quantifying the financial impact of the income tax reform changes on the utility, along with proposed tariff schedule changes that would adjust the utility's rates to reflect the utility's modified federal tax obligations under the Tax Cuts and Jobs Act. The IPUC order required Idaho Power to estimate the income tax reform changes by comparing actual 2017 federal income tax components with what those federal income tax components would have been if the Tax Cuts and Jobs Act had been effective for the full year of 2017.

In March 2018, Idaho Power made a filing with the IPUC providing the results of its pro forma analysis indicating pro forma annual income tax reform expense reductions, composed of a current income tax expense reduction and a deferred income tax expense reduction. In May 2018, the IPUC ~~issued an order approving~~ a settlement stipulation (May 2018 Idaho Tax Reform Settlement Stipulation) related to income tax reform. Beginning June 1, 2018, the settlement stipulation provides an annual (a) $18.7 million reduction to Idaho customer base rates and (b) $7.4 million amortization of existing regulatory deferrals for specified items or future amortization of other existing or future unspecified regulatory deferrals that would otherwise be a future liability recoverable from Idaho customers. Additionally, a one-time ~~benefit~~ ~~of a $7.8 million rate reduction is being provided to Idaho customers through the Idaho-jurisdiction power cost adjustment (PCA) mech~~anism for the period from June 1, 2018 through May 31, 2019, for the income tax reform benefits accrued from January 1, 2018 to May 31, 2018, and the income tax reform benefits related to Idaho Power's open access transmission tariff (OATT). The amount provided via the PCA mechanism will decrease to $2.7 million on June 1, 2019, for income tax reform benefits related to Idaho Power's OATT and will cease on June 1, 2020, to reflect the impact of a full year of reduced OATT third-party transmission revenues.

The May 2018 Idaho Tax Reform Settlement Stipulation also provides for the indefinite extension of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation beyond its termination date of December 31, 2019. The table below summarizes and compares the terms of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation with the terms in the May 2018 Idaho Tax Reform Settlement Stipulation that will be applicable commencing on January 1, 2020.

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~~October 2014 Idaho Earnings Support and Sharing Settlement Stipulation~~ ~~(Effective through December 31, 2019)~~		~~May 2018 Idaho Tax Reform Settlement Stipulation~~ ~~(Effective beginning January 1, 2020, with no defined end date)~~
If Idaho Power's actual annual Idaho ROE in any year is less than 9.5 percent, then Idaho Power may record additional ADITC amortization up to $25 million to help achieve a 9.5 percent Idaho ROE for that year, and may record additional ADITC amortization up to a total of $45 million over the 2015 through 2019 period. If the $45 million of ADITC are completely amortized, the revenue sharing provisions below would no longer be applicable.		If Idaho Power's actual annual Idaho ROE in any year is less than 9.4 percent, then Idaho Power may amortize up to $25 million of additional ADITC to help achieve a 9.4 percent Idaho ROE for that year, so long as the cumulative amount of ADITC used does not exceed $45 million (Idaho Power will have available and may continue to use any unused portion of the $45 million of additional ADITC from the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation); however, Idaho Power may seek approval from the IPUC to replenish the total amount of ADITC it is permitted to amortize. If there are no remaining amounts of ADITC authorized to be amortized, the revenue sharing provisions below would not be applicable until ADITC is replenished.
If Idaho Power's annual Idaho ROE in any year exceeds 10.0 percent, the amount of earnings exceeding a 10.0 percent Idaho ROE and up to and including a 10.5 percent Idaho ROE will be allocated 75 percent to Idaho Power's Idaho customers as a rate reduction to be effective at the time of the subsequent year's PCA, and 25 percent to Idaho Power.		If Idaho Power's annual Idaho ROE in any year exceeds 10.0 percent, the amount of earnings exceeding a 10.0 percent Idaho ROE and up to and including a 10.5 percent Idaho ROE will be allocated 80 percent to Idaho Power's Idaho customers as a rate reduction to be effective at the time of the subsequent year's PCA, and 20 percent to Idaho Power.
If Idaho Power's annual Idaho ROE in any year exceeds 10.5 percent, the amount of earnings exceeding a 10.5 percent Idaho ROE will be allocated 50 percent to Idaho Power's Idaho customers as a rate reduction to be effective at the time of the subsequent year's PCA, 25 percent to Idaho Power's Idaho customers in the form of a reduction to the pension regulatory asset balancing account (to reduce the amount to be collected in the future from Idaho customers), and 25 percent to Idaho Power.		If Idaho Power's annual Idaho ROE in any year exceeds 10.5 percent, the amount of earnings exceeding a 10.5 percent Idaho ROE will be allocated 55 percent to Idaho Power's Idaho customers as a rate reduction to be effective at the time of the subsequent year's PCA, 25 percent to Idaho Power's Idaho customers in the form of a reduction to the pension regulatory asset balancing account (to reduce the amount to be collected in the future from Idaho customers), and 20 percent to Idaho Power.
In the event the IPUC approves a change to Idaho Power's allowed annual Idaho ROE as part of a general rate case proceeding before December 31, 2019, the Idaho ROE thresholds will be adjusted on a prospective basis as follows: (a) the Idaho ROE under which Idaho Power will be permitted to amortize an additional amount of ADITC will be set at 95 percent of the newly authorized Idaho ROE, (b) sharing with customers on an 75 percent basis as a customer rate reduction will begin at the newly authorized Idaho ROE, and (c) sharing with customers on a 75 percent basis but allocated 50 percent to a rate reduction, and 25 percent to a pension expense deferral regulatory asset, will begin at 105 percent of the newly authorized Idaho ROE.		In the event the IPUC approves a change to Idaho Power's allowed annual Idaho ROE as part of a general rate case proceeding effective on or after January 1, 2020, the Idaho ROE thresholds will be adjusted on a prospective basis as follows: (a) the Idaho ROE under which Idaho Power will be permitted to amortize an additional amount of ADITC will be set at 95 percent of the newly authorized Idaho ROE, (b) sharing with customers on an 80 percent basis as a customer rate reduction will begin at the newly authorized Idaho ROE, and (c) sharing with customers on an 80 percent basis but allocated 55 percent to a rate reduction, and 25 percent to a pension expense deferral regulatory asset, will begin at 105 percent of the newly authorized Idaho ROE.

Neither the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation nor the May 2018 Idaho Tax Reform Settlement Stipulation impose a moratorium on Idaho Power filing a general rate case or other form of rate proceeding in Idaho during their respective terms.

Also in May 2018, the OPUC issued an order approving a settlement stipulation that provides for an annual $1.5 million reduction to Oregon customer base rates beginning June 1, 2018, through May 31, 2020, related to income tax reform. Unless resolved in a regulatory proceeding before, the settlement stipulation requires Idaho Power to file a deferral request with the OPUC by December 31, 2019, to begin tracking tax reform benefits beginning January 1, 2020, at which time Idaho Power, the OPUC staff, and other interested parties will discuss the methodology to quantify potential future tax reform benefits. The settlement stipulation also deemed prudent Idaho Power's decision to pursue the end of its participation in coal-fired operations of Unit 1 at Idaho Power's jointly-owned North Valmy coal-fired plant and approved Idaho Power's request to recover annual incremental accelerated depreciation of $2.5 million relating to Unit 1, beginning June 1, 2018, and ending December 31, 2019.

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~~Hells Canyon Complex Relicensing Costs Settlement Stipulation~~

In December 2016, Idaho Power filed an application with the IPUC requesting a determination that Idaho Power's expenditures of $220.8 million through year-end 2015 on relicensing of the Hells Canyon Complex (HCC) were prudently incurred, and thus eligible for inclusion in retail rates in a future regulatory proceeding. In December 2017, Idaho Power filed with the IPUC a settlement stipulation signed by Idaho Power, the IPUC staff, and a third party intervenor, recognizing that a total of $216.5 million in HCC relicensing expenditures and other related costs were reasonably incurred, and therefore should be eligible for inclusion in customer rates at a later date. As a result of filing the settlement stipulation, Idaho Power recorded a $5.0 million pre-tax charge in the fourth quarter of 2017, which included $4.3 million for costs incurred through 2015, as well as $0.7 million related to associated costs incurred in 2016 and 2017. In ~~April 2018, the IPUC issued an order approving the settlement stipulation as filed with the IPUC and determined the $216.5 million of associated costs to be reasonably and prudently incurred.~~

Idaho Power Cost Adjustment Mechanisms

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

In May 2019, the IPUC approved a $50.1 million net decrease in Idaho-jurisdiction power cost adjustment (PCA) revenues, effective for the 2019-2020 PCA collection period from June 1, 2019 to May 31, 2020. The net decrease in PCA revenues reflects reduced power supply costs due to higher-than-expected wholesale energy sales and positive results from natural gas hedging activities, which combined to reduce actual net power supply costs for the 2018-2019 PCA year (April 2018 through

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March 2019). The net decrease in PCA revenues for the 2019-2020 PCA collection period also includes a $5.0 million credit to customers for sharing of 2018 earnings under the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation and a $2.7 million credit for income tax reform benefits related to Idaho Power's open access transmission tariff (OATT) rate under the May 2018 Idaho Tax Reform Settlement Stipulation. In addition, the net decrease in PCA revenues reflects benefits from Idaho Power's participation in the energy imbalance market implemented in the western United States (Western EIM). Previously, in May 2018, the IPUC issued an order approving a ~~$22.6~~$30.4 million net decrease in PCA rates, effective for the 2018-2019 PCA collection period from June 1, 2018, to May 31, 2019. The net decrease in PCA rates isincluded a $7.8 million one-time benefit for income tax savings from January 1, 2018 to May 31, 2018, as well as those related to Idaho Power's OATT rate. The remaining net decrease in PCA rates for the 2018-2019 PCA collection period was primarily due to better-than-expected actual water conditions for the 2017-2018 PCA year (April 2017 through March 2018), which resulted in additional low-cost ~~hydroelectric generation~~hydropower available to reduce net power supply costs. Previously in May 2017, the IPUC issued an order approving a $10.6 million net increase in PCA rates, effective for the 2017-2018 PCA collection period from June 1, 2017, to May 31, 2018. The net increase in PCA rates was primarily due to expected higher power supply costs resulting from new renewable energy power purchase agreements under PURPA and higher coal-fired generation costs, combined with the effect of lower-than-expected actual hydroelectric generation for the 2016-2017 PCA year. The net increase included an offsetting $13.0 million one-time refund of previously collected Idaho energy efficiency rider funds.

Idaho Fixed Cost Adjustment Mechanism

The Idaho jurisdiction fixed cost adjustment (FCA) mechanism, applicable to Idaho residential and small general service customers, is designed to remove a portion of Idaho Power’s financial disincentive to invest in energy efficiency programs by separating (or decoupling) the recovery of fixed costs from the variable kilowatt-hour charge and ~~instead~~ linking it instead to a set amount per customer. ~~The~~Under Idaho Power's current rate design, Idaho Power recovers a portion of fixed costs through the variable kilowatt-hour charge, which may result in over-collection or under-collection of fixed costs. To return over-collection to customers or to collect under-collection from customers, the FCA mechanism ~~applicable to residential and small commercial customers, is adjusted each year~~allows Idaho Power to accrue, or defer, the difference between the authorized fixed-cost recovery amount per customer and the actual fixed costs per customer recovered by Idaho Power during the year. Any annual increase in the FCA recovery may be capped at 3 percent of base revenue at the discretion of the IPUC, with any excess deferred for collection in a subsequent year. In May 2019, the IPUC approved an increase of $19.2 million in recovery from the FCA from $15.6 million to $34.8 million, with new rates effective for the period from June 1, 2019 to May 31, 2020. Previously, in May 2018, the IPUC issued an order approving a decrease of $19.4 million in the FCA from $35.0 million to $15.6 million, with ~~new~~ rates effective for the period from June 1, 2018 to May 31, 2019. ~~Previously~~

Valmy Exit Agreement and Base Rate Adjustment Approval Request

In February 2019, Idaho Power reached an agreement with NV Energy that facilitates the planned end of Idaho Power's participation in coal-fired operations at units 1 and 2 of its jointly-owned North Valmy coal-fired power plant (Valmy Plant) in 2019 and 2025, respectively. In May ~~2017,~~2019, the IPUC issued an order approving ~~an increase of $6.9~~the Valmy Plant agreement and allowing Idaho Power to recover through customer rates the $1.2 million ~~in the FCA from $28.1 million to $35.0 million,~~incremental annual levelized revenue requirement associated with ~~rates~~required Valmy Plant investments and other exit costs, effective ~~for the period from~~ June 1, ~~2017, to May~~2019 through December 31, ~~2018.~~2028.

~~Western Energy Imbalance Market Costs~~

Idaho Power's participation in the energy imbalance market implemented in the western United States (Western EIM) commenced on April 4, 2018. The Western EIM aims to reduce the power supply costs to serve customers through more efficient dispatch within the hour of a larger and more diverse pool of resources, to integrate intermittent power from renewable generation sources more effectively, and to enhance reliability.

In ~~August 2016,~~July 2019, Idaho Power filed an application with the ~~IPUC~~OPUC requesting ~~specified regulatory accounting treatment associated with its participation in~~that the ~~Western EIM. In January 2017,~~OPUC approve the ~~IPUC issued an order authorizing deferral accounting treatment for costs associated with joining the Western EIM.~~Valmy Plant agreement and authorize Idaho Power ~~deferred $1.0 million~~to adjust customer rates in Oregon, effective January 1, 2020, to reflect a decrease in annual levelized revenue requirement of ~~incremental other operations and maintenance (O&M) costs incurred through April 1, 2018.~~

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In November 2017, Idaho Power filed an application with the IPUC requesting approval to establish an interim method of recovery for costs associated with participation in the Western EIM. In July 2018, the IPUC issued an order approving a settlement stipulation that provides for a recovery mechanism administered through Idaho Power's PCA mechanism. The recovery mechanism provides for monthly incremental revenue, which includes a return on and return of Western EIM-related capital costs and recovery of ongoing Western EIM operating costs.$3.2 million. As of ~~April 1, 2018, Idaho Power ceased deferring incremental Western EIM participation O&M start-up costs, and began recognizing~~ the ~~monthly incremental revenue associated with Western EIM participation. During both~~date of this report, the ~~three and six months ended June 30, 2018, Idaho Power recorded $0.7 million of revenue relating to Western EIM participation and deferred the same amount to the PCA deferral account.~~application remains pending.

4. REVENUES

On January 1, 2018, IDACORP and Idaho Power adopted ASU 2014-09 using the modified retrospective method. The adoption did not change the timing or amounts of revenue recognized by IDACORP or Idaho Power and, therefore, no cumulative-effect adjustment was recorded. The following table provides a summary of electric utility operating revenues for IDACORP and Idaho Power for the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands):



	Three months ended June 30,				Six months ended June 30,
	2019		2018		2019		2018
Electric utility operating revenues:
Revenue from contracts with customers	$	307,779	$	331,298	$	643,180	$	620,871
Alternative revenue programs and other revenues	7,995		7,401		22,366		27,289
Total electric utility operating revenues	$	315,774	$	338,699	$	665,546	$	648,160

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Three months ended
June 30, Six months ended
June 30,
2018 2017 2018 2017
Electric utility operating revenues:
Revenue from contracts with customers $ 331,298
$ 326,190
$ 620,871
$ 620,081
Alternative revenue programs and other revenues 7,401
5,578
27,289
13,651
Total electric utility operating revenues $ 338,699
$ 331,768
$ 648,160
$ 633,732

Revenues from Contracts with Customers

Revenues from contracts with customers are primarily related to Idaho Power’s regulated tariff-based sales of energy or related services. Generally, tariff-based sales do not involve a written contract, but are classified as revenues from contracts with customers under ASU 2014-09. Idaho Power assesses revenues on a contract-by-contract basis to determine the nature, amount, timing and uncertainty, if any, of revenues being recognized. The following table presents revenues from contracts with customers disaggregated by revenue source for the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands):


	Three months ended June 30,						Six months ended June 30,						Three months ended June 30,						Six months ended June 30,
	2018			2017			2018			2017			2019			2018			2019			2018
Revenues from contracts with customers:
Retail revenues:
Residential (includes $5,508, $3,205, $19,052 and $8,331, respectively, related to the FCA⁽¹⁾)	$	109,155		$	112,534		$	255,838		$	264,689
Commercial(includes $291, $276, $652 and $387, respectively, related to the FCA⁽¹⁾)	76,965			78,982			151,191			153,260
Residential (includes $7,232, $5,508, $18,543, and $19,052, respectively, related to the FCA)⁽¹⁾													$	104,797		$	109,155		$	255,016		$	255,838
Commercial(includes $350, $291, $691, and $652, respectively, related to the FCA)⁽¹⁾													70,973			76,965			144,079			151,191
Industrial	48,868			49,766			94,660			95,224			45,602			48,868			91,100			94,660
Irrigation	65,065			56,068			65,471			56,993			48,954			65,065			49,953			65,471
Deferred revenue related to HCC relicensing AFUDC⁽²⁾	(1,462		)	(2,349		)	(4,046		)	(4,933		)	(1,927		)	(1,462		)	(4,046		)	(4,046		)
Total retail revenues	298,591			295,001			563,114			565,233			268,399			298,591			536,102			563,114
Less: FCA mechanism revenues⁽¹⁾	(5,799		)	(3,481		)	(19,704		)	(8,718		)	(7,582		)	(5,799		)	(19,234		)	(19,704		)
Wholesale energy sales	10,214			6,003			24,283			13,967			16,158			8,919			63,373			22,685
Transmission services (wheeling) revenues	13,205			11,965			24,600			20,824
Transmission wheeling-related revenues													12,518			14,500			28,246			26,198
Energy efficiency program revenues	8,802			10,515			16,399			16,843			11,458			8,802			21,570			16,399
Other revenues from contracts with customers	6,285			6,187			12,179			11,932			6,828			6,285			13,123			12,179
Total revenues from contracts with customers	$	331,298		$	326,190		$	620,871		$	620,081		$	307,779		$	331,298		$	643,180		$	620,871

⁽¹⁾ The FCA mechanism is an alternative revenue program in the Idaho jurisdiction and does not represent revenue from contracts with customers.

⁽²⁾As part of its January 30, 2009, general rate case order, the IPUC is allowing Idaho Power to recover a portion of the allowance for funds used during construction (AFUDC) on construction work in progress related to the ~~HCC~~Hells Canyon Complex (HCC) relicensing process, even though the relicensing process is not yet complete and the costs have not been moved to electric plant in service. Idaho Power is collecting $8.8 million annually in the Idaho jurisdiction but is deferring revenue recognition of the amounts collected until the license is issued and the accumulated license costs approved for recovery are placed in service. ~~Prior to the May 2018 Idaho Tax Reform Settlement Stipulation described in Note 3 - "Regulatory Matters," Idaho Power was collecting $10.7 million annually.~~

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~~Retail Revenues:~~Idaho Power’s retail revenues primarily relate to the sale of electricity to customers based on regulated tariff-based prices. Idaho Power recognizes retail revenues in amounts for which it has the right to invoice the customer in the period when energy is delivered or services are provided to customers. The total energy price generally has a fixed component related to having service available and a usage-based component related to the demand, delivery, and consumption of energy. The revenues recognized reflect the consideration Idaho Power expects to be entitled to in exchange for that energy or those services. Retail customers are classified as residential, commercial, industrial, or irrigation. Approximately 95 percent of Idaho Power's retail revenue originates from customers located in Idaho, with the remainder originating from customers located in Oregon. Idaho Power’s retail customer rates are based on Idaho Power’s cost of service and are determined through general rate case proceedings, settlement stipulations, and other filings with the IPUC and OPUC. Changes in rates and changes in customer demand are typically the primary causes of fluctuations in retail revenue from period to period. The primary influences on changes in customer demand for electricity are weather, economic conditions (including growth in the number of Idaho Power customers), and energy efficiency. Idaho Power's utility revenues are not earned evenly during the year.

Retail revenues are billed monthly based on meter readings taken throughout the month. Payments for amounts billed are generally due from the customer within 15 days of billing. Idaho Power accrues estimated unbilled revenues for energy or related services delivered to customers but not yet billed at period-end based on actual meter readings at period-end and estimated rates.

Credit losses recorded on receivables arising from Idaho Power’s contracts with customers were $1.5 million and $1.8 million for the three and six months ended June 30, 2018, respectively, and $2.2 million and $2.4 million for the three and six months ended June 30, 2017, respectively.

~~Residential Customers~~: Idaho Power’s energy sales to residential customers typically peak during the winter heating season and summer cooling season. Extreme temperatures increase sales to residential customers who use electricity for cooling and heating, compared with normal temperatures. Idaho Power's rate structure provides for higher rates during the summer when overall system loads are at their highest, and includes tiers such that rates increase as a customer's consumption level increases. These seasonal and tiered rate structures contribute to the seasonal fluctuations in revenues and earnings. Economic and demographic conditions can also affect residential customer demand; strong job growth and population growth in Idaho Power’s service area have led to increasing customer growth rates in recent years. Residential demand is also impacted by energy efficiency initiatives. Idaho Power’s FCA mechanism mitigates some of the fluctuations caused by weather and energy efficiency initiatives.

~~Commercial Customers~~: Most businesses are included in Idaho Power's commercial customer class, as well as small industrial companies, and public street and highway lighting accounts. Idaho Power’s commercial customers are less influenced by weather conditions than residential customers, although weather does affect commercial customer energy use. Economic conditions, including manufacturing activity levels, and energy efficiency initiatives also affect energy use of commercial customers.

~~Industrial Customers~~: Industrial customers consist of large industrial companies, including special contract customers. Energy use of industrial customers is primarily driven by economic conditions, with weather having little impact on this customer class.

~~Irrigation Customers~~: Irrigation customers use electricity to operate irrigation pumps, primarily during the agricultural growing season. The amount and timing of precipitation as well as temperature levels can affect the timing and amounts of sales to irrigation customers with increased precipitation generally resulting in decreased sales.

~~Wholesale Energy Sales:~~As a public utility under the Federal Power Act (FPA), Idaho Power has the authority to charge market-based rates for wholesale energy sales under its FERC tariff. Idaho Power’s wholesale electricity sales are primarily to utilities and power marketers and are predominantly short-term and consist of a single performance obligation satisfied as energy is transferred to the counterparty. Idaho Power's wholesale energy sales depend largely on the availability of generation resources in excess of the amount necessary to serve customer loads as well as adequate market power prices at the time when those resources are available. A reduction in either factor may lead to lower wholesale energy sales.

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~~Transmission Services (Wheeling) Revenues:~~ As a public utility under the FPA, Idaho Power has the authority to provide cost-based wholesale and retail access transmission services under its OATT. Services under the OATT are offered on a nondiscriminatory basis such that all potential customers have an equal opportunity to access the transmission system. Idaho Power’s transmission revenue is primarily related to third parties reserving capacity on Idaho Power’s transmission system to transmit electricity through Idaho Power’s service area. The reservations are predominantly short-term but may be part of a long-term capacity contract, short-term contract, or on demand when available. Transmission services revenues consist of a single performance obligation satisfied as capacity on Idaho Power’s transmission system is provided to the third party. Transmission service revenues are affected by changes in Idaho Power’s OATT transmission rate and customer demand. Demand for transmission services can be affected by regional market factors, such as loads and generation of utilities in Idaho Power’s region.

~~Energy Efficiency Program Revenues:~~ Idaho Power collects most of its energy efficiency program costs through an energy efficiency rider on customer bills. The rider collections are deferred until expenditures are incurred. Energy efficiency program expenditures funded through the rider are reported as an operating expense with an equal amount recorded in revenues, resulting in no net impact on earnings. Energy efficiency program revenues are recognized in the period when the related costs of the energy efficiency program are incurred by Idaho Power. The cumulative variance between expenditures and amounts collected through the rider is recorded as a regulatory asset or liability. A liability balance indicates that Idaho Power has collected more than it has spent, and an asset balance indicates that Idaho Power has spent more than it has collected. At June 30, 2018, Idaho Power's energy efficiency rider balances were a $2.6 million regulatory liability in the Idaho jurisdiction and a $6.5 million regulatory asset in the Oregon jurisdiction.

Alternative Revenue Programs and Other Revenues

While revenues from contracts with customers make up most of Idaho Power’s revenues, the IPUC has authorized the use of an additional regulatory mechanism, which may increase or decrease tariff-based rates billed to customers. The Idaho FCA mechanism ~~applicable to residential and small commercial customers,~~ is ~~designed to remove a portion of Idaho Power’s financial disincentive to invest~~described in energy efficiency programs by separating (or decoupling) the recovery of fixed costs from the variable kilowatt-hour charge and linking it instead to a set amount per customer. Under Idaho Power's current rate design, recovery of a portion of fixed costs is included in the variable kilowatt-hour charge, which may result in overcollection or undercollection of fixed costs. To return overcollection to customers or to collect undercollection from customers, the FCA mechanism allows Idaho Power to accrue, or defer, the difference between the authorized fixed-cost recovery amount per customer and the actual fixed costs per customer recovered by Idaho Power during the year. Increases in FCA recovery are capped at"Note 3 ~~percent of base revenue annually, with any excess deferred for collection in a subsequent year.~~

- Regulatory Matters." The FCA mechanism revenues include only the initial recognition of FCA revenues when revenues meet the regulator-specified conditions for ~~recognition have been met.~~recognition. Revenue from contracts with customers excludes the portion of the tariff price representing FCA revenues that ~~had been~~Idaho Power initially recorded in prior periods when revenues met regulator-specified ~~conditions were met.~~conditions. When Idaho Power includes those amounts ~~are included~~ in the price of utility service ~~and~~ billed to customers, Idaho Power records such amounts ~~are recorded~~ as recovery of the associated regulatory asset or liability and not as revenues.

The table below presents the FCA mechanism revenues and other revenues for the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands):



	Three months ended June 30,				Six months ended June 30,
	2019		2018		2019		2018
Alternative revenue programs and other revenues:
FCA mechanism revenues	$	7,582	5,799		$	19,234	$	19,704
Derivative revenues	413		1,602		3,132		7,585
Total alternative revenue programs and other revenues	$	7,995	$	7,401	$	22,366	$	27,289

Three months ended
June 30, Six months ended
June 30,
2018 2017 2018 2017
Alternative revenue programs and other revenues:
FCA mechanism revenues $ 5,799
3,481
$ 19,704
$ 8,718
Derivative revenues 1,602
2,097
7,585
4,933
Total alternative revenue programs and other revenues $ 7,401
$ 5,578
$ 27,289
$ 13,651

~~IDACORP's Other Revenues~~

~~IDACORP's other revenues are primarily comprised of revenues from IDACORP’s subsidiary, Ida-West. Ida-West operates small hydroelectric generation projects that satisfy the requirements of PURPA.~~

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~~5. LONG-TERM DEBT~~

In March 2018, Idaho Power issued $220 million in principal amount of 4.20 percent first mortgage bonds, secured medium-term notes, Series K, maturing on March 1, 2048. In April 2018, Idaho Power redeemed, prior to maturity, $130 million in principal amount of 4.50 percent first mortgage bonds, medium-term notes, Series H due March 2020. In accordance with the redemption provisions of the notes, the redemption included Idaho Power's payment of a make-whole premium to the holders of the redeemed notes in the aggregate amount of $4.6 million. Idaho Power used a portion of the net proceeds from the March 2018 sale of first mortgage bonds, medium-term notes to effect the redemption.

As of June 30, 2018, $280 million in principal amount of long-term debt securities remained available for issuance under a selling agency agreement executed on September 27, 2016, and pursuant to state regulatory authority.

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5. COMMON STOCK

IDACORP Common Stock

During the six months ended June 30, ~~2018,~~2019, IDACORP granted ~~75,761~~70,419 restricted stock unit awards to employees and ~~12,950~~issued 6,396 shares of common stock to directors, but made no original issuances of shares of common stock pursuant to the IDACORP, Inc. 2000 Long-Term Incentive and Compensation Plan. As directed by IDACORP, plan administrators of the IDACORP, Inc. Dividend Reinvestment and Stock Purchase Plan and Idaho Power Company Employee Savings Plan ~~use~~used 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 use original issuances of common stock under those plans.

Restrictions on Dividends

Idaho Power’s ability to pay dividends on its common stock held by IDACORP and IDACORP’s ability to pay dividends on its common stock are limited to the extent payment of such dividends would violate the covenants in their respective credit facilities or Idaho Power’s Revised Code of Conduct. A covenant under IDACORP’s credit facility and Idaho Power’s credit facility requires IDACORP and Idaho Power to maintain leverage ratios of consolidated indebtedness to consolidated total capitalization, as defined therein, of no more than 65 percent at the end of each fiscal quarter. At June 30, ~~2018,~~2019, the leverage ratios for IDACORP and Idaho Power were 4443 percent and 4645 percent, respectively. Based on these restrictions, IDACORP’s and Idaho Power’s dividends were limited to ~~$1.3~~$1.4 billion and ~~$1.1~~$1.2 billion, respectively, at June 30, ~~2018.~~2019. There are additional facility covenants, subject to exceptions, that prohibit or restrict the sale or disposition of property without consent and any agreements restricting dividend payments to IDACORP and Idaho Power from any material subsidiary. At June 30, ~~2018,~~2019, IDACORP and Idaho Power were in compliance with those financial covenants.

Idaho Power’s Revised Code of Conduct relating to transactions between and among Idaho Power, IDACORP, and other affiliates, which was approved by the IPUC in April 2008, provides that Idaho Power will not pay any dividends to IDACORP that will reduce Idaho Power’s common equity capital below 35 percent of its total adjusted capital without IPUC approval. At June 30, ~~2018,~~2019, Idaho Power's common equity capital was 5455 percent of its total adjusted capital. Further, Idaho Power must obtain approval from the OPUC before it can directly or indirectly loan funds or issue notes or give credit on its books to IDACORP.

Idaho Power’s articles of incorporation contain restrictions on the payment of dividends on its common stock if preferred stock dividends are in arrears. As of the date of this report, Idaho Power has no preferred stock outstanding.

In addition to contractual restrictions on the amount and payment of dividends, the ~~FPA~~Federal Power Act (FPA) prohibits the payment of dividends from "capital accounts." The term "capital account" is undefined in the FPA or its regulations, but Idaho Power does not believe the restriction would limit Idaho Power's ability to pay dividends out of current year earnings or retained earnings.

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7.6. EARNINGS PER SHARE

The table below presents the computation of IDACORP’s basic and diluted earnings per share for the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands, except for per share amounts).



	Three months ended June 30,				Six months ended June 30,
	2019		2018		2019		2018
Numerator:
Net income attributable to IDACORP, Inc.	$	53,156	$	62,288	$	95,842	$	98,430
Denominator:
Weighted-average common shares outstanding - basic	50,499		50,435		50,504		50,430
Effect of dilutive securities	8		46		8		42
Weighted-average common shares outstanding - diluted	50,507		50,481		50,512		50,472
Basic earnings per share	$	1.05	$	1.24	$	1.90	$	1.95
Diluted earnings per share	$	1.05	$	1.23	$	1.90	$	1.95

Three months ended
June 30, Six months ended
June 30,
2018 2017 2018 2017
Numerator:

Net income attributable to IDACORP, Inc. $ 62,288
$ 49,831
$ 98,430
$ 82,933
Denominator:

Weighted-average common shares outstanding - basic 50,435
50,363
50,430
50,361
Effect of dilutive securities 46
44
42
41
Weighted-average common shares outstanding - diluted 50,481
50,407
50,472
50,402
Basic earnings per share $ 1.24
$ 0.99
$ 1.95
$ 1.65
Diluted earnings per share $ 1.23
$ 0.99
$ 1.95
$ 1.65

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7. COMMITMENTS

Purchase Obligations

~~IDACORP's and Idaho Power's purchase obligations did not change materially, outside of the ordinary course of business, during~~During the six months ended June 30, 2019, IDACORP's and Idaho Power's contractual obligations, outside the ordinary course of business, did not change materially from the amounts disclosed in the notes to the consolidated financial statements in the 2018 Annual Report, except that Idaho Power entered into four new replacement contracts for expiring power purchase agreements with ~~solar and biomass~~hydropower PURPA-qualifying facilities and one new agreement with a solar PURPA-qualifying facility, which increased Idaho Power's contractual ~~payment~~purchase obligations by approximately ~~$51~~$24 million over the 20-year terms of the contracts. Also, in March 2019, Idaho Power signed a 20-year power purchase agreement, pending regulatory approval, to purchase the output from a 120 megawatt solar facility proposed to be constructed by a third party. The agreement would increase contractual obligations by $136 million over the 20-year term.

Guarantees

Through a self-bonding mechanism, Idaho Power guarantees its portion of reclamation activities and obligations at BCC, of which IERCo owns a one-third interest. This guarantee, which is renewed annually with the Wyoming Department of Environmental Quality, was ~~$58.4~~$58.3 million at June 30, ~~2018,~~2019, representing IERCo's one-third share of BCC's total reclamation obligation of ~~$175.2~~$175.0 million. BCC has a reclamation trust fund set aside specifically for the purpose of paying these reclamation costs. At June 30, ~~2018,~~2019, the value of BCC's reclamation trust fund was ~~$108.3~~$125.9 million. During the six months ended June 30, ~~2018,~~2019, the reclamation trust fund made no distributions ~~of $3.0 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, and does, add a per-ton surcharge to coal sales, all of which are made to the Jim Bridger plant. Because of the existence of the fund and the ability to apply a per-ton surcharge, the estimated fair value of this guarantee is minimal.

In May 2019, the state of Wyoming enacted legislation that limits a mine operator's maximum amount of self-bonding. Idaho Power and the co-owners of BCC have 18 months to comply with the new regulations, which would reduce the portion of Idaho Power's guarantee of reclamation activities and obligations at BCC that Idaho Power is allowed to self-bond. As of the date of this report, Idaho Power believes the cost of any insurance, third-party assurance, or additional collateral that might be required for this guarantee due to the new law would be immaterial to the companies' consolidated financial statements.

IDACORP and Idaho Power enter into financial agreements and power purchase and sale agreements that include indemnification provisions relating to various forms of claims or liabilities that may arise from the transactions contemplated by these agreements. Generally, a maximum obligation is not explicitly stated in the indemnification provisions and, therefore, the overall maximum amount of the obligation under such indemnification provisions cannot be reasonably estimated. IDACORP and Idaho Power periodically evaluate the likelihood of incurring costs under such indemnities based on their historical experience and the evaluation of the specific indemnities. As of June 30, ~~2018,~~2019, 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.

9.8. CONTINGENCIES

IDACORP and Idaho Power have in the past and expect in the future to become involved in various claims, controversies, disputes, and other contingent matters, some of which involve litigation and regulatory or other contested proceedings. The ultimate resolution and outcome of litigation and regulatory proceedings is inherently difficult to determine, particularly where (a) the remedies or penalties sought are indeterminate, (b) the proceedings are in the early stages or the substantive issues have not been well developed, or (c) the matters involve complex or novel legal theories or a large number of parties. In accordance with applicable accounting guidance, IDACORP and Idaho Power, as applicable, establish an accrual for legal proceedings

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when those matters proceed to a stage where they present loss contingencies that are both probable and reasonably estimable. If the loss contingency at issue is not both probable and reasonably estimable, IDACORP and Idaho Power do not establish an accrual and the matter will continue to be monitored for any developments that would make the loss contingency both probable and reasonably estimable. As of the date of this report, IDACORP's and Idaho Power's accruals for loss contingencies are not material to their financial statements as a whole; however, future accruals could be material in a given period. IDACORP's and Idaho Power's determination is based on currently available information, and estimates presented in financial statements and other financial disclosures involve significant judgment and may be subject to significant uncertainty. 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.~~incurred, although there is no assurance that such recovery would be granted.

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IDACORP and Idaho Power are parties to legal claims and legal and regulatory actions and proceedings in the ordinary course of business and, as noted above, record an accrual for associated loss contingencies when they are probable and reasonably estimable. In connection with its utility operations, Idaho Power is subject to claims by individuals, entities, and governmental agencies for damages for alleged personal injury, property damage, and economic losses relating to the company’s provision of electric service and the operation of its generation, transmission, and distribution facilities. Some of those claims relate to electrical contacts, service quality, property damage, and wildfires. In recent years, utilities in the western United States have been subject to significant liability for personal injury, loss of life, property damage, trespass, and economic losses, and in some cases, punitive damages and criminal charges, associated with wildfires that originated from utility property, most commonly transmission and distribution lines. In recent years, Idaho Power has regularly received claims by both governmental agencies and private landowners for damages for fires allegedly originating from Idaho Power’s transmission and distribution system. As of the date of this report, the companies believe that resolution of ~~those matters~~existing claims will not have a material adverse effect on their respective consolidated financial statements. Idaho Power is also actively monitoring various pending environmental regulations and executive orders related to environmental matters 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.

~~10.~~9. BENEFIT PLANS

Idaho Power has a noncontributory defined benefit pension plan (pension plan) and two nonqualified defined benefit plans for certain senior management employees called the Security Plan for Senior Management Employees I and Security Plan for Senior Management Employees II (collectively, SMSP). Idaho Power also has a nonqualified defined benefit pension plan for directors that was frozen in 2002. Remaining vested benefits from that plan are included with the SMSP in the disclosures below. The benefits under the pension plan are based on years of service and the employee’s final average earnings. Idaho Power also maintains a defined benefit postretirement benefit plan (consisting of health care and death benefits) that covers all employees who were enrolled in the active-employee group plan at the time of retirement as well as their spouses and qualifying dependents. The ~~following~~ table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the three months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands).


	Pension Plan						SMSP					Postretirement Benefits						Total						Pension Plan						SMSP						Postretirement Benefits						Total
	2018			2017			2018			2017		2018			2017			2018			2017			2019			2018			2019			2018			2019			2018			2019			2018
Service cost	$	9,742		$	8,245		$	(79	)	$	190	$	242		$	197		$	9,905		$	8,632		$	8,316		$	9,742		$	(45	)	$	(79	)	$	196		$	242		$	8,467		$	9,905
Interest cost	9,683			9,716			1,061			1,079		656			702			11,400			11,497			10,560			9,683			1,145			1,061			762			656			12,467			11,400
Expected return on plan assets	(13,056		)	(11,181		)	—			—		(605		)	(584		)	(13,661		)	(11,765		)	(12,187		)	(13,056		)	—			—			(557		)	(605		)	(12,744		)	(13,661		)
Amortization of prior service cost	2			7			25			32		12			17			39			56			2			2			24			25			12			12			38			39
Amortization of net loss	3,394			3,212			947			740		—			—			4,341			3,952			3,302			3,394			633			947			—			—			3,935			4,341
Net periodic benefit cost	9,765			9,999			1,954			2,041		305			332			12,024			12,372			9,993			9,765			1,757			1,954			413			305			12,163			12,024
Regulatory deferral of net periodic benefit cost⁽¹⁾	(9,309		)	(9,488		)	—			—		—			—			(9,309		)	(9,488		)	(9,523		)	(9,309		)	—			—			—			—			(9,523		)	(9,309		)
Previously deferred pension costs recognized⁽¹⁾	4,289			4,289			—			—		—			—			4,289			4,289			4,289			4,289			—			—			—			—			4,289			4,289
Net periodic benefit cost recognized for financial reporting⁽¹⁾⁽²⁾	$	4,745		$	4,800		$	1,954		$	2,041	$	305		$	332		$	7,004		$	7,173		$	4,759		$	4,745		$	1,757		$	1,954		$	413		$	305		$	6,929		$	7,004

⁽¹⁾ Net periodic benefit costs for the pension plan are recognized for financial reporting based upon the authorization of each regulatory jurisdiction in which Idaho Power operates. Under IPUC order, the Idaho portion of net periodic benefit cost is recorded as a regulatory asset and is recognized in the income statement as those costs are recovered through rates.

⁽²⁾ Of total net periodic benefit cost recognized for financial reporting, $4.2 million and $4.1 million, ~~and $4.4 million,~~ respectively, ~~was~~were recognized in "Other operations and maintenance" and $2.7 million and $2.9 million, ~~and $2.8 million,~~ respectively, ~~was~~were recognized in "Other expense, net" on the condensed consolidated statements of income of the companies for the three months ended June 30, ~~2018~~2019 and ~~2017.~~2018.

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The ~~following~~ table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands).


	Pension Plan						SMSP					Postretirement Benefits						Total						Pension Plan						SMSP						Postretirement Benefits						Total
	2018			2017			2018			2017		2018			2017			2018			2017			2019			2018			2019			2018			2019			2018			2019			2018
Service cost	$	19,485		$	16,871		$	(158	)	$	380	$	526		$	486		$	19,853		$	17,737		$	17,030		$	19,485		$	(90	)	$	(158	)	$	427		$	526		$	17,367		$	19,853
Interest cost	19,365			19,479			2,124			2,157		1,322			1,392			22,811			23,028			21,156			19,365			2,288			2,124			1,494			1,322			24,938			22,811
Expected return on plan assets	(26,111		)	(22,569		)	—			—		(1,234		)	(1,154		)	(27,345		)	(23,723		)	(24,311		)	(26,111		)	—			—			(1,110		)	(1,234		)	(25,421		)	(27,345		)
Amortization of prior service cost	3			14			49			64		24			24			76			102			3			3			48			49			24			24			75			76
Amortization of net loss	6,788			6,595			1,894			1,481		—			—			8,682			8,076			6,782			6,788			1,266			1,894			—			—			8,048			8,682
Net periodic benefit cost	19,530			20,390			3,909			4,082		638			748			24,077			25,220			20,660			19,530			3,512			3,909			835			638			25,007			24,077
Regulatory deferral of net periodic benefit cost⁽¹⁾	(18,616		)	(19,284		)	—			—		—			—			(18,616		)	(19,284		)	(19,690		)	(18,616		)	—			—			—			—			(19,690		)	(18,616		)
Previously deferred pension costs recognized⁽¹⁾	8,577			8,577			—			—		—			—			8,577			8,577			8,577			8,577			—			—			—			—			8,577			8,577
Net periodic benefit cost recognized for financial reporting⁽¹⁾⁽²⁾	$	9,491		$	9,683		$	3,909		$	4,082	$	638		$	748		$	14,038		$	14,513
Net periodic benefit cost recognized for financial reporting(1)(2)																								$	9,547		$	9,491		$	3,512		$	3,909		$	835		$	638		$	13,894		$	14,038

⁽²⁾ Of total net periodic benefit cost recognized for financial reporting, $8.4 million and $8.2 million, ~~and $8.9 million,~~ respectively, ~~was~~were recognized in "Other operations and maintenance" and $5.5 million and $5.8 million, ~~and $5.6 million,~~ respectively, ~~was~~were recognized in "Other expense, net" on the condensed consolidated statements of income of the companies for the six months ended June 30, ~~2018~~2019 and ~~2017.~~2018.

Idaho Power has no minimum contribution requirement to its defined benefit pension plan in ~~2018.~~2019. However, during the six months ended June 30, ~~2018,~~2019, Idaho Power made ~~$20~~$10 million of discretionary contributions to its defined benefit pension plan, in a continued effort to balance the regulatory collection of these expenditures with the amount and timing of contributions and to mitigate the cost of being in an underfunded position. The primary impact of pension contributions is on the timing of cash flows, as the timing of cost recovery lags behind contributions.

Idaho Power also has an Employee Savings Plan that complies with Section 401(k) of the Internal Revenue Code and covers substantially all employees. Idaho Power matches specified percentages of employee contributions to the Employee Savings Plan.

~~11.~~10. DERIVATIVE FINANCIAL INSTRUMENTS

Commodity Price Risk

Idaho Power is exposed to market risk relating to electricity, natural gas, and other fuel commodity prices, all of which are heavily influenced by supply and demand. Market risk may be influenced by market participants’ nonperformance of their contractual obligations and commitments, which affects the supply of or demand for the commodity. Idaho Power uses derivative instruments, such as physical and financial forward contracts, for both electricity and fuel to manage the risks relating to these commodity price exposures. The primary objectives of Idaho Power’s energy purchase and sale activity are to meet the demand of retail electric customers, maintain appropriate physical reserves to ensure reliability, and make economic use of temporary surpluses that may develop.

All of Idaho Power's derivative instruments have been entered into for the purpose of economically hedging forecasted purchases and sales, though none of these instruments have been designated as cash flow hedges. Idaho Power offsets fair value amounts recognized on its balance sheet and applies collateral related to derivative instruments executed with the same counterparty under the same master netting agreement. Idaho Power does not offset a counterparty's current derivative contracts with the counterparty's long-term derivative contracts, although Idaho Power's master netting arrangements would allow current and long-term positions to be offset in the event of default. Also, in the event of default, Idaho Power's master netting arrangements would allow for the offsetting of all transactions executed under the master netting arrangement. These types of transactions may include non-derivative instruments, derivatives qualifying for scope exceptions, receivables and payables arising from settled positions, and other forms of non-cash collateral (such as letters of credit). These types of transactions are excluded from the offsetting presented in the derivative fair value and offsetting table that follows.

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The table below presents the gains and losses on derivatives not designated as hedging instruments for the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands).



		Gain/(Loss) on Derivatives Recognized in Income⁽¹⁾
	Location of Realized Gain/(Loss) on Derivatives Recognized in Income	Three months ended June 30,						Six months ended June 30,
		2019			2018			2019			2018
Financial swaps	Operating revenues	$	414		$	27		$	(2,789	)	$	266
Financial swaps	Purchased power	(56		)	13			687			(189		)
Financial swaps	Fuel expense	7			(112		)	12,402			(800		)
Financial swaps	Other operations and maintenance	—			31			—			38
Forward contracts	Operating revenues	—			—			64			2
Forward contracts	Purchased power	—			(7		)	(64		)	(20		)
Forward contracts	Fuel expense	—			10			416			24

Gain/(Loss) on Derivatives Recognized in Income⁽¹⁾
Location of Realized Gain/(Loss) on Derivatives Recognized in Income Three months ended
June 30, Six months ended
June 30,
2018 2017 2018 2017
Financial swaps Operating revenues $ 27
$ (305 ) $ 266
$ 1,173
Financial swaps Purchased power 13
(287 ) (189 ) (735 )
Financial swaps Fuel expense (112 ) (4 ) (800 ) 666
Financial swaps Other operations and maintenance 31
(55 ) 38
(81 )
Forward contracts Operating revenues —
—
2
—
Forward contracts Purchased power (7 ) (8 ) (20 ) (10 )
Forward contracts Fuel expense 10
3
24
3

(1)⁽¹⁾Excludes unrealized gains or losses on derivatives, which are recorded on the balance sheet as regulatory assets or regulatory liabilities.

Settlement gains and losses on electricity swap contracts are recorded on the income statement in operating revenues ~~from contracts with customers~~ 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 1211 - "Fair Value Measurements" for additional information concerning the determination of fair value for Idaho Power’s assets and liabilities from price risk management activities.

~~Derivative Instrument Summary~~

The table below presents the fair values and locations of derivative instruments not designated as hedging instruments recorded on the balance sheets and reconciles the gross amounts of derivatives recognized as assets and as liabilities to the net amounts presented in the balance sheets at June 30, 2018, and December 31, 2017 (in thousands).

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

June 30, 2018
Current:

Financial swaps Other current assets $ 1,545
$ (791 ) $ 754
$ 791
$ (791 ) $ —
Financial swaps Other current liabilities 195
(195 ) —
1,051
(195 ) 856
Forward contracts Other current assets 3
—
3
—
—
—
Long-term:

Financial swaps Other assets 49
(1 ) 48
1
(1 ) —
Financial swaps Other liabilities 15
(15 ) —
354
(15 ) 339
Total $ 1,807
$ (1,002 ) $ 805
$ 2,197
$ (1,002 ) $ 1,195
December 31, 2017
Current:

Financial swaps Other current assets $ 18
$ —
$ 18
$ —
$ —
$ —
Financial swaps Other current liabilities 553
(553 ) —
1,971
(748 )
⁽¹⁾
1,223
Forward contracts Other current liabilities —
—
—
2
—
2
Long-term:

Financial swaps Other assets 4
—
4
—
—
—
Total $ 575
$ (553 ) $ 22
$ 1,973
$ (748 ) $ 1,225

⁽¹⁾ ~~Current liability derivative amount offset includes $0.2 million of collateral receivable for the period ended December 31, 2017.~~

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~~The table below presents the volumes of derivative commodity forward contracts and swaps outstanding at June 30, 2018 and 2017 (in thousands of units).~~

June 30,
Commodity Units 2018 2017
Electricity purchases MWh 323
194
Electricity sales MWh 58
38
Natural gas purchases MMBtu 12,371
10,297
Natural gas sales MMBtu 233
75
Diesel purchases Gallons 451
605

Credit Risk

At June 30, ~~2018,~~2019, 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 Idaho Power derivative instruments contain provisions that require Idaho Power's unsecured debt to maintain an investment grade credit rating from Moody's Investors Service and Standard & Poor's Ratings Services. If Idaho Power's unsecured debt were to fall below investment grade, it would be in violation of these provisions, and the counterparties to the derivative instruments could request immediate payment or demand immediate and ongoing full overnight collateralization on derivative instruments in net liability positions. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position at June 30, ~~2018~~2019, was ~~$2.2~~$4.6 million. Idaho Power posted ~~$0.8~~$1.8 million cash collateral related to this amount. If the credit-risk-related contingent features underlying these agreements were triggered on June 30, ~~2018,~~2019, Idaho Power would have been required to pay or post collateral to its counterparties up to an additional ~~$3.0~~$4.6 million to cover the open liability positions as well as completed transactions that have not yet been paid.

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Derivative Instrument Summary



		Asset Derivatives								Liability Derivatives
	Balance Sheet Location	Gross Fair Value		Amounts Offset				Net Assets		Gross Fair Value		Amounts Offset			Net Liabilities
	Balance Sheet Location	Gross Fair Value		Amounts Offset				Net Assets		Gross Fair Value		Amounts Offset			Net Liabilities
June 30, 2019
Current:
Financial swaps	Other current assets	$	5,003	$	(915	)		$	4,088	$	915	$	(915	)	$	—
Financial swaps	Other current liabilities	173		(173		)		—		2,940		(173		)	2,767
Forward contracts	Other current assets	197		—				197		—		—			—
Long-term:
Financial swaps	Other liabilities	71		(71		)		—		746		(71		)	675
Total		$	5,444	$	(1,159	)		$	4,285	$	4,601	$	(1,159	)	$	3,442

December 31, 2018
Current:
Financial swaps	Other current assets	$	4,639	$	(984	)	⁽¹⁾	$	3,655	$	938	$	(938	)	$	—
Financial swaps	Other current liabilities	—		—				—		806		—			806
Forward contracts	Other current liabilities	—		—				—		104		—			104
Long-term:
Financial swaps	Other assets	—		—				—		64		—			64
Total		$	4,639	$	(984	)		$	3,655	$	1,912	$	(938	)	$	974

(1) Current asset derivative amounts offset include $45 thousandof collateral payable for the period ending December 31, 2018.

The table below presents the volumes of derivative commodity forward contracts and swaps outstanding at June 30, 2019 and 2018 (in thousands of units).



		June 30,
Commodity	Units	2019	2018
Electricity purchases	MWh	216	323
Electricity sales	MWh	106	58
Natural gas purchases	MMBtu	13,980	12,371
Natural gas sales	MMBtu	308	233
Diesel purchases	Gallons	—	451

~~12.~~11. FAIR VALUE MEASUREMENTS

IDACORP and Idaho Power have categorized their financial instruments into a three-level fair value hierarchy, based on the priority of the inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). If the inputs used to measure the financial instruments fall within different levels of the hierarchy, the categorization is based on the lowest level input that is significant to the fair value measurement of the instrument.

Financial assets and liabilities recorded on the condensed consolidated balance sheets are categorized based on the inputs to the valuation techniques as follows:

• Level 1: Financial assets and liabilities whose values are based on unadjusted quoted prices for identical assets or liabilities in an active market that IDACORP and Idaho Power have the ability to access.

• Level 2: Financial assets and liabilities whose values are based on the following:

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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.

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• 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 six months ended June 30, ~~2018.~~2019.

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 June 30, ~~2018,~~2019, and December 31, ~~2017~~2018 (in thousands).



	June 30, 2019								December 31, 2018
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets:
Money market funds
IDACORP⁽¹⁾	$	50,399	$	—	$	—	$	50,399	$	97,833	$	—	$	—	$	97,833
Idaho Power	30,981		—		—		30,981		79,228		—		—		79,228
Derivatives	4,088		197		—		4,285		3,655		—		—		3,655
Equity securities	34,795		—		—		34,795		36,488		—		—		36,488
Liabilities:
Derivatives	3,442		—		—		3,442		870		104		—		974

June 30, 2018 December 31, 2017
Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total
Assets:

Money market funds
IDACORP ⁽¹⁾
$ 30,611
$ —
$ —
$ 30,611
$ 28,038
$ —
$ —
$ 28,038
Idaho Power 80,593
—
—
80,593
10,260
—
—
10,260
Derivatives 802
3
—
805
22
—
—
22
Equity securities 27,916
—
—
27,916
30,266
—
—
30,266
Liabilities:
Derivatives 1,195
—
—
1,195
1,223
2
—
1,225

⁽¹⁾ Holding company only. Does not include amounts held by Idaho Power.

Idaho Power’s derivatives are contracts entered into as part of its management of loads and resources. Electricity derivatives are valued on the Intercontinental Exchange with quoted prices in an active market. Natural gas and diesel derivatives are valued using New York Mercantile Exchange (NYMEX) and Intercontinental Exchange (ICE) pricing, adjusted for location basis, which are also quoted under NYMEX and ICE pricing. Equity securities consist of employee-directed investments related to an executive deferred compensation plan and actively traded money market and exchange traded funds related to the SMSP. The investments are measured using quoted prices in active markets and are held in a Rabbi trust.

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The table below presents the carrying value and estimated fair value of financial instruments that are not reported at fair value, as of June 30, ~~2018,~~2019, and December 31, ~~2017,~~2018, using available market information and appropriate valuation methodologies (in thousands).



	June 30, 2019				December 31, 2018
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
IDACORP
Assets:
Notes receivable⁽¹⁾	$	3,804	$	3,804	$	3,804	$	3,804
Liabilities:
Long-term debt⁽¹⁾	1,835,521		2,024,566		1,834,788		1,942,773
Idaho Power
Liabilities:
Long-term debt⁽¹⁾	1,835,521		2,024,566		1,834,788		1,942,773

June 30, 2018 December 31, 2017
Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value
IDACORP

Assets:

Notes receivable⁽¹⁾
$ 3,804
$ 3,804
$ 3,804
$ 3,804
Liabilities:

Long-term debt⁽¹⁾
1,834,055
1,946,794
1,746,123
1,915,459
Idaho Power

Liabilities:

Long-term debt⁽¹⁾
1,834,055
1,946,794
1,746,123
1,915,459

⁽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.~~11 - "Fair Value Measurements."

Notes receivable are related to Ida-West and are valued based on unobservable inputs, including discounted cash flows, which are partially based on forecasted ~~hydroelectric~~hydropower conditions. Long-term debt is not traded on an exchange and is valued using quoted rates for similar debt in active markets. Carrying values for cash and cash equivalents, deposits, customer and other receivables, notes payable, accounts payable, interest accrued, and taxes accrued approximate fair value.

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~~13.~~12. SEGMENT INFORMATION

IDACORP’s only reportable segment is utility operations. The utility operations segment’s primary source of revenue is the regulated operations of Idaho Power. Idaho Power’s regulated operations include the generation, transmission, distribution, purchase, and sale of electricity. This segment also includes income from IERCo, a wholly-owned subsidiary of Idaho Power that is also subject to regulation and is a one-third owner of BCC, an unconsolidated joint venture.

IDACORP’s other operating segments are below the quantitative and qualitative thresholds for reportable segments and are included in the "All Other" category in the table below. This category is comprised of IFS’s investments in affordable housing developments and historic rehabilitation projects, Ida-West’s joint venture investments in small ~~hydroelectric~~hydropower generation projects, and IDACORP’s holding company expenses.

The table below summarizes the segment information for IDACORP’s utility operations and the total of all other segments, and reconciles this information to total enterprise amounts (in thousands).



	Utility Operations		All Other		Eliminations			Consolidated Total
Three months ended June 30, 2019:
Revenues	$	315,774	$	1,121	$	—		$	316,895
Net income attributable to IDACORP, Inc.	51,176		1,980		—			53,156
Total assets as of June 30, 2019	6,325,252		170,610		(35,009		)	6,460,853
Three months ended June 30, 2018:
Revenues	$	338,699	$	1,253	$	—		$	339,952
Net income attributable to IDACORP, Inc.	60,637		1,651		—			62,288
Six months ended June 30, 2019:
Revenues	$	665,546	$	1,668	$	—		$	667,214
Net income attributable to IDACORP, Inc.	92,760		3,082		—			95,842
Six months ended June 30, 2018:
Revenues	$	648,160	$	1,898	$	—		$	650,058
Net income attributable to IDACORP, Inc.	96,493		1,937		—			98,430

Utility
Operations

All
Other
Eliminations
Consolidated
Total
Three months ended June 30, 2018:
Revenues $ 338,699
$ 1,253
$ —
$ 339,952
Net income attributable to IDACORP, Inc. 60,637
1,651
—
62,288
Total assets as of June 30, 2018 6,133,502
153,529
(80,914 ) 6,206,117
Three months ended June 30, 2017:
Revenues $ 331,768
$ 1,238
$ —
$ 333,006
Net income attributable to IDACORP, Inc. 48,381
1,450
—
49,831
Six months ended June 30, 2018:
Revenues $ 648,160
$ 1,898
$ —
$ 650,058
Net income attributable to IDACORP, Inc. 96,493
1,937
—
98,430
Six months ended June 30, 2017:
Revenues $ 633,732
$ 1,818
$ —
$ 635,550
Net income attributable to IDACORP, Inc. 80,863
2,070
—
82,933

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~~14.~~13. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME

The table below presents changes in components of accumulated other comprehensive income (AOCI), net of tax, during the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands). Items in parentheses indicate charges to AOCI.


	Defined Benefit Pension Items												Defined Benefit Pension Items
	Three months ended June 30,						Six months ended June 30,						Three months ended June 30,						Six months ended June 30,
	2018			2017			2018			2017			2019			2018			2019			2018
Balance at beginning of period	$	(30,243	)	$	(20,411	)	$	(30,964	)	$	(20,882	)	$	(22,356	)	$	(30,243	)	$	(22,844	)	$	(30,964	)
Amounts reclassified out of AOCI	722			470			1,443			941			488			722			976			1,443
Balance at end of period	$	(29,521	)	$	(19,941	)	$	(29,521	)	$	(19,941	)	$	(21,868	)	$	(29,521	)	$	(21,868	)	$	(29,521	)

The table below presents amounts reclassified out of components of AOCI and the income statement location of those amounts reclassified during the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands). Items in parentheses indicate increases to net income.


	Amount Reclassified from AOCI												Amount Reclassified from AOCI
Details About AOCI	Three months ended June 30,						Six months ended June 30,						Three months ended June 30,						Six months ended June 30,
	2018			2017			2018			2017			2019			2018			2019			2018
Amortization of defined benefit pension items⁽¹⁾
Prior service cost	$	25		$	32		$	49		$	64		$	24		$	25		$	48		$	49
Net loss	947			740			1,894			1,481			633			947			1,266			1,894
Total before tax	972			772			1,943			1,545			657			972			1,314			1,943
Tax benefit⁽²⁾	(250		)	(302		)	(500		)	(604		)	(169		)	(250		)	(338		)	(500		)
Net of tax	722			470			1,443			941
Total reclassification for the period	$	722		$	470		$	1,443		$	941
Total reclassification for the period, net of tax													$	488		$	722		$	976		$	1,443

⁽¹⁾ Amortization of these items is included in IDACORP's condensed consolidated income statements in other operating expenses and in Idaho Power's condensed consolidated statements of income in other expense, net.

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

14. CHANGES IN IDAHO POWER RETAINED EARNINGS

The table below presents changes in Idaho Power retained earnings during the three and six months ended June 30, 2019 and 2018 (in thousands).



	Three months ended June 30,						Six months ended June 30,
	2019			2018			2019			2018
Balance at beginning of period	$	1,418,775		$	1,314,472		$	1,409,245		$	1,308,702
Net income	51,176			60,637			92,760			96,493
Dividends to parent	(31,932		)	(29,863		)	(63,986		)	(59,949		)
Balance at end of period	$	1,438,019		$	1,345,246		$	1,438,019		$	1,345,246

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the shareholders and the Board of Directors of IDACORP, Inc.

Results of Review of Interim Financial Information

We have reviewed the accompanying condensed consolidated balance sheet of IDACORP, Inc. and subsidiaries (the “Company”) as of June 30, ~~2018~~2019, ~~and~~ the related condensed consolidated statements of income, ~~and~~ comprehensive income and equity for the three-month and six-month periods ended June 30, 2019 and 2018, and ~~2017 and~~ of ~~equity and~~ cash flows for the six-month periods ended June 30, ~~2018~~2019 and ~~2017~~,2018, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of the Company as of December 31, ~~2017~~2018, and the related consolidated statements of income, comprehensive income, equity, and cash flows for the year then ended (not presented herein); and in our report dated February ~~22, 2018,~~21, 2019, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying condensed consolidated balance sheet as of December 31, ~~2017~~2018, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of the Company’s management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with ~~the~~ standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/ DELOITTE & TOUCHE LLP

Boise, Idaho

August ~~2, 2018~~1, 2019

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the shareholder and the Board of Directors of Idaho Power Company

Results of Review of Interim Financial Information

We have reviewed the accompanying condensed consolidated balance sheet of Idaho Power Company and subsidiary (the “Company”) as of June 30, ~~2018,~~2019, the related condensed consolidated statements of income and comprehensive income for the three-month and six-month periods ended June 30, 2019 and 2018, and ~~2017 and~~of cash flows for the six-month periods ended June 30, ~~2018~~2019 and ~~2017,~~2018, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of the Company as of December 31, ~~2017,~~2018, and the related consolidated statements of income, comprehensive income, retained earnings and cash flows for the year then ended (not presented herein); and in our report dated February ~~22, 2018,~~21, 2019, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying condensed consolidated balance sheet as of December 31, ~~2017,~~2018, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

/s/ DELOITTE & TOUCHE LLP

Boise, Idaho

August ~~2, 2018~~1, 2019

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS

In Management’s Discussion and Analysis of Financial Condition and Results of Operations (MD&A) in this report, the general financial condition and results of operations for IDACORP, Inc. and its subsidiaries (collectively, IDACORP) and Idaho Power Company and its subsidiary (collectively, Idaho Power) are discussed. While reading the MD&A, please refer to the accompanying condensed consolidated financial statements of IDACORP and Idaho Power. Also refer to "Cautionary Note Regarding Forward-Looking Statements" in this report for important information regarding forward-looking statements made in this MD&A and elsewhere in this report. This discussion updates the MD&A included in ~~the~~IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, ~~2017,~~2018 (2018 Annual Report), and should also be read in conjunction with the information in that report. The results of operations for an interim period generally will not be indicative of results for the full year, particularly in light of the seasonality of Idaho Power's sales volumes, as discussed below.

INTRODUCTION

IDACORP is a holding company formed in 1998 whose principal operating subsidiary is Idaho Power. IDACORP’s common stock is listed and trades on the New York Stock Exchange under the trading symbol "IDA". Idaho Power is an electric utility whose rates and other matters are regulated by the Idaho Public ~~Utility~~Utilities Commission (IPUC), Public Utility Commission of Oregon (OPUC), and Federal Energy Regulatory Commission (FERC). Idaho Power generates revenues and cash flows primarily from the sale and distribution of electricity to customers in its Idaho and Oregon service territories, as well as from the wholesale sale and transmission of electricity. Idaho Power experiences its highest retail energy sales during the summer irrigation and cooling season, with a lower peak in the winter that generally results from heating demand. Idaho Power’s rates are established through regulatory proceedings that affect its ability to recover its costs and the potential to earn a return on its investment.

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 (Jim Bridger plant). IDACORP’s other significant subsidiaries include IDACORP Financial Services, Inc. ~~(IFS)~~, an investor in affordable housing and other real estate investments, and Ida-West Energy Company, an operator of small ~~hydroelectric~~hydropower generation projects that satisfy the requirements of the Public Utility Regulatory Policies Act of 1978 (PURPA).

EXECUTIVE OVERVIEW

Management's Outlook and Company Initiatives

In the 2018 Annual Report, ~~on Form 10-K for the year ended December 31, 2017,~~ IDACORP's and Idaho Power's management included a brief overview of their ~~initiatives and~~business strategies for the companies for ~~2018~~2019 and beyond, under the heading "Executive ~~Overview - 2018 Initiatives and Strategy"~~Overview" in the MD&A. As of the date of this report, management's outlook and strategy remain consistent with that discussion. Most notably:

Idaho Power continues to expect positive customer growth in its service area, and continues to participate in and support state and local economic development initiatives aimed at responsible and sustainable growth. During the first six months of ~~2018,~~2019, Idaho Power's customer count grew by ~~approximately 5,700~~nearly 6,800 customers, and for the twelve months ended June 30, ~~2018,~~2019, the customer growth rate was ~~2.2~~2.5 percent.

In 2019, Idaho Power achieved its highest ever residential customer satisfaction score, the highest of any investor-owned utility in the nation, as rated by an independent third party.

In March 2019, Idaho Power announced its "Clean Today, Cleaner Tomorrow.™" goal to provide its customers with 100-percent clean energy by 2045.

Idaho Power anticipates substantial capital investments, with expected total capital expenditures of approximately $1.5 billion over the five-year period from ~~2018~~2019 (including the expenditures incurred so far in ~~2018)~~2019) through ~~2022.~~2023.

Idaho Power continues to execute on its four strategic areas: growing to enhance financial strength, improving Idaho Power's core business, enhancing Idaho ~~Power’s~~Power's brand, and focusing on safety and employee engagement.

Idaho Power continues to focus on timely recovery of costs and earning a reasonable return on investment, including working to evaluate and ensure that its rate design and regulatory mechanisms properly reflect the cost to provide electric service.

~~During the first six months of 2018,~~In February 2019, Idaho Power reached ~~various regulatory settlements~~an agreement with NV Energy that ~~were approved by~~facilitates the ~~IPUC~~planned end of Idaho Power's participation in coal-fired operations at units 1 and ~~OPUC. These approved settlements related to recent income tax reform, the indefinite extension, with modifications,~~2 of ~~the current earnings support~~its jointly-owned North Valmy coal-fired power plant (Valmy Plant) in 2019 and sharing mechanism, the prudence of certain Hells Canyon Complex (HCC) relicensing costs, and the treatment of costs incurred to join the energy imbalance market implemented in the western United States (Western EIM).2025, respectively. In May ~~2018,~~2019, the IPUC issued an order ~~authorizing~~approving the ~~creation of new customer classes for customers with on-site generation,~~Valmy Plant agreement and ~~in June 2018, the IPUC issued an order requiring further investigation to resolve eligibility issues for the new~~allowing Idaho

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Power to recover through customer ~~classes. Idaho Power believes that these regulatory actions are positive outcomes as they reduce future uncertainty for both shareholders~~rates, effective June 1, 2019, the $1.2 million incremental annual levelized revenue requirement associated with required Valmy Plant planned and ~~customers. Refer to "Regulatory Matters" in this MD&A for more information on the related regulatory proceedings.~~actual investments and other exit costs.

Summary of Financial Results

The following is a summary of Idaho Power's net income, net income attributable to IDACORP, and IDACORP's earnings per diluted share for the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands, except earnings per share amounts):


	Three months ended June 30,				Six months ended June 30,				Three months ended June 30,				Six months ended June 30,
	2018		2017		2018		2017		2019		2018		2019		2018
Idaho Power net income	$	60,637	$	48,381	$	96,493	$	80,863	$	51,176	$	60,637	$	92,760	$	96,493
Net income attributable to IDACORP, Inc.	$	62,288	$	49,831	$	98,430	$	82,933	$	53,156	$	62,288	$	95,842	$	98,430
Average outstanding shares – diluted	50,481		50,407		50,472		50,402		50,507		50,481		50,512		50,472
IDACORP, Inc. earnings per diluted share	$	1.23	$	0.99	$	1.95	$	1.65	$	1.05	$	1.23	$	1.90	$	1.95

The table below provides a reconciliation of net income attributable to IDACORP for the three and six months ended June 30, ~~2018,~~2019, from the same ~~periods~~period in ~~2017~~2018 (items are in millions and are before related income tax impact unless otherwise noted).

Three months ended Six months ended
Net income attributable to IDACORP, Inc. - June 30, 2017 $ 49.8
$ 82.9
Increase (decrease) in Idaho Power net income:

Customer growth, net of associated power supply costs and power cost adjustment mechanisms 1.8

4.2

Usage per retail customer, net of associated power supply costs and power cost adjustment mechanisms 4.7
(6.9 )
Idaho fixed cost adjustment (FCA) revenues 2.3
11.0

Retail revenues per megawatt-hour (MWh), net of associated power supply costs and power cost adjustment mechanisms (6.8 ) (9.4 )
Transmission services (wheeling) and other revenues 1.3
4.0

Other operations and maintenance (O&M) expense (5.6 ) (4.8 )
Depreciation expense 3.9
0.6

Other changes in operating revenues and expenses, net (0.7 ) (1.1 )
Increase (decrease) in Idaho Power operating income 0.9
(2.4 )
Earnings of equity-method investments 1.0
3.9

Non-operating income and expenses 0.7
1.2

Additional accumulated deferred investment tax credits (ADITC) amortization 1.4
—

Tax benefit from make-whole premium for early bond redemption 1.3
1.3

Income tax expense (excluding additional ADITC amortization and tax benefit from early bond redemption) 7.0
11.6

Total increase in Idaho Power net income 12.3
15.6
Other IDACORP changes (net of tax) 0.2
(0.1 )
Net income attributable to IDACORP, Inc. - June 30, 2018 $ 62.3
$ 98.4



	Three months ended					Six months ended
Net income attributable to IDACORP, Inc. - June 30, 2018			$	62.3				$	98.4
Increase (decrease) in Idaho Power net income:
Customer growth, net of associated power supply costs and power cost adjustment mechanisms	4.2					8.2
Usage per retail customer, net of associated power supply costs and power cost adjustment mechanisms	(13.4	)				(10.4	)
Idaho fixed cost adjustment (FCA) revenues	1.8					(0.5	)
Retail revenues per MWh, net of associated power supply costs and power cost adjustment mechanisms	(7.0	)				(4.3	)
Transmission wheeling-related revenues	(2.0	)				2.0
Other operations and maintenance (O&M) expenses	5.3					2.6
Other changes in operating revenues and expenses, net	0.2					(0.9	)
Decrease in Idaho Power operating income	(10.9	)				(3.3	)
Earnings of equity-method investments	1.4					(0.6	)
Non-operating income and expenses	—					1.7
Income tax expense	—					(1.5	)
Total decrease in Idaho Power net income			(9.5		)			(3.7		)
Other IDACORP changes (net of tax)			0.4					1.1
Net income attributable to IDACORP, Inc. - June 30, 2019			$	53.2				$	95.8

Net Income - Second Quarter ~~2018~~

2019

IDACORP's net income ~~increased $12.5~~decreased $9.1 million for the second quarter of ~~2018~~2019 compared with the second quarter of ~~2017,~~2018, primarily due to ~~higher~~lower net income at Idaho Power.

Customer growth increased operating income by ~~$1.8~~$4.2 million in the second quarter of ~~2018~~2019 compared with the second quarter of ~~2017,~~2018, as the number of Idaho Power customers grew by ~~2.2~~2.5 percent during the twelve months ended June 30, ~~2018.~~2019. Sales volumes on a per-customer basis ~~also increased~~decreased operating income by ~~$4.7~~$13.4 million in the second quarter of ~~2018 compared with~~

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the second quarter of 2017. Precipitation in Idaho Power's service area was near normal in the second quarter of 2018, but was significantly less than precipitation in the second quarter of 2017. This resulted in a 15 percent increase in usage per agricultural irrigation customer, who use electricity to operate irrigation pumps. The increase in sales volumes to irrigation customers was partially offset by a decrease in usage per residential customer as milder temperatures in the second quarter of 20182019 compared with the second quarter of ~~2017 caused residential~~2018. Greater precipitation in Idaho Power's service area led agricultural irrigation customers to use 20 percent less ~~electricity~~energy per customer to operate irrigation pumps. Also, residential and commercial customers used less energy per customer for cooling ~~and heating.~~purposes, primarily due to cooler temperatures. The decrease in residential sales volumes per customer was ~~partially~~mostly offset by the FCA mechanism (applicable to residential and small general service customers), which increased revenues by ~~$2.3 million during the second quarter~~$1.8 million.

Table of ~~2018 compared with the second quarter of 2017.~~Contents

The net decrease in retail revenues per ~~MWh~~megawatt-hour (MWh) decreased operating income by ~~$6.8~~$7.0 million in the second quarter of ~~2018~~2019 compared with the second quarter of ~~2017.~~2018. The settlement stipulations approved by the IPUC and OPUC during the second quarter of 2018 relating to ~~recent~~ income tax reform ~~(discussed in more detail below),~~ reduced revenues in the second quarter of 2018. In the second quarter of 2017, the IPUC and OPUC each approved settlement stipulations related to Idaho Power’s plan to end its participation in coal-fired operations at Idaho Power’s jointly-owned North Valmy coal-fired power plant (Valmy Plant) by the end of 2025. The Valmy Plant settlement stipulations provided for an accrual of six months of the increase in retail revenues, depreciation expense, and associated income tax expense2019 more significantly than in the second quarter of ~~2017, resulting~~2018. To a lesser extent, changes in the customer sales mix decreased the retail revenues per MWh as volumes sold to residential, commercial, and irrigation customers made up a ~~decrease in these items~~lesser portion of the customer sales mix than industrial customers in the second quarter of ~~2018 compared with the same period in 2017.~~

~~Other O&M expenses were $5.6 million higher in the second quarter of 2018~~2019 compared with the second quarter of ~~2017.~~2018. Residential, commercial, and irrigation customers generally pay a higher per-MWh rate than industrial customers.

During the second quarter of 2019, transmission wheeling-related revenues decreased $2.0 million compared with the second quarter of 2018, largely due to a decrease in Idaho Power's open access transmission tariff (OATT) rates that became effective in October 2018.

Other O&M expenses were $5.3 million lower in the second quarter of 2019 compared with the second quarter of 2018. Other O&M expenses related to Idaho Power's hydropower generation decreased $1.1 million, due primarily to fewer maintenance projects at hydropower locations in the second quarter of 2019 compared with the second quarter of 2018. Labor and benefit costs decreased $1.5 million, primarily related to the levels of accruals for variable employee-related costs. As provided by the settlement stipulation approved by the IPUC in 2018 related to income tax reform, O&M expenses in the second quarter of 2018 included $1.1 million of non-cash amortization expense of regulatory deferrals that would otherwise be a future liability of Idaho customers. Also, transmission and distribution asset maintenance expense increased $0.9 million in the second quarter of 2018 compared with 2017 due to higher maintenance service costs. Labor and benefit costs increased $3.1 million, primarily related to the timing of accruals for variable employee-related costs which resulted in earlier recognition of expense in the second quarter of 2018 compared with 2017.

Depreciation expense was $3.9 million lower in the second quarter of 2018 compared with the second quarter of 2017, due mostly to the effect of recognizing six months of the accelerated depreciation during the second quarter of 2017 as provided by the 2017 Valmy Plant settlement stipulation described above. This decrease was partially offset by higher depreciation expense from an increase in electric plant in service.

Idaho Power income tax expense, excluding additional ADITC amortization and the $1.3 million flow-through benefit of tax deductible make-whole premiums that Idaho Power paid in connection with the early redemption of long-term debt in April 2018, decreased $7.0 million in the second quarter of 2018 compared with the second quarter of 2017, due primarily to the lower federal and state statutory income tax rates resulting from income tax reform discussed in further detail below. In addition, the Valmy Plant settlement stipulation described above increased income tax expense in the second quarter of 2017. Idaho Power reversed $0.5 million of previously recorded additional ADITC amortization under its Idaho regulatory settlement stipulation during the second quarter of 2018, compared with a reversal of $1.9 million during the second quarter of 2017. Based on Idaho Power's current expectations of full-year 2018 results, Idaho Power does not expect to record additional ADITC amortization in 2018.

Net Income - Year-to-Date ~~2018~~2019

IDACORP's net income ~~increased $15.5~~decreased $2.6 million for the first half of ~~2018~~2019 compared with the same period ~~in 2017,~~of 2018, primarily due to ~~higher~~lower net income at Idaho Power.

Customer growth ~~added $4.2~~increased operating income by $8.2 million ~~to Idaho Power operating income,~~in the first half of 2019 compared with the first half of ~~2017. Lower usage~~2018. Sales volumes on a per-customer basis decreased operating income by $10.4 million in the first half of 2019 compared with the first half of 2018, primarily due to lower irrigation, residential, and commercial revenues in the second quarter of 2019, as described above. The lower sales volumes on a per-customer basis in the second quarter of 2019 were partially offset by a 3 percent increase in sales volumes per residential customer in the first ~~six months~~quarter of ~~2018 reduced operating income by $6.9 million, due primarily to milder temperatures,~~2019 compared with the first ~~six months of 2017. The lower residential customer usage was partially offset by higher usage per irrigation customer in the second~~ quarter of 2018, ~~due to lower precipitation, compared with the same period in 2017. However, due to the lower usage by~~as colder temperatures led residential customers ~~the FCA mechanism added $11.0 million~~ to ~~operating income during the first six months of 2018, compared with the first six months of 2017.~~

use more energy for heating.

The net decrease in retail revenues per MWh decreased operating income by ~~$9.4~~$4.3 million in the first ~~six months~~half of ~~2018~~2019 compared with the ~~same period in 2017. The~~first half of 2018, due primarily to the effects of the settlement stipulations approved by the IPUC and OPUC during the second quarter of 2018 ~~relating~~related to ~~recent~~ income tax reform ~~(discussed in more detail below) reduced revenue in the first six months of 2018.~~noted above.

During the first ~~six months~~half of ~~2018,~~2019, Idaho Power benefited from a ~~$4.0~~$2.0 million increase in ~~third-party use of electric property, wheeling, and other~~transmission wheeling-related revenue, compared with the first ~~six months~~half of ~~2017.~~2018. This change was largely due to an increase in wheeling-related volumes driven by regional wholesale energy market activity in the first quarter of 2019, partially offset by a decrease in Idaho Power's ~~open access transmission tariff (OATT)~~OATT rates that became effective in October ~~2017.~~2018.

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Other O&M expenses were ~~$4.8~~$2.6 million ~~higher~~lower in the first ~~six months~~half of ~~2018~~2019 compared with the first ~~six months~~half of ~~2017. As noted above,~~2018. Other O&M expenses related to ~~recent~~Idaho Power's hydropower generation decreased $2.3 million, due primarily to fewer maintenance projects at hydropower locations in the first half of 2019. As provided by the settlement stipulation approved by the IPUC in 2018 related to income tax reform, ~~regulatory settlements,~~ O&M expenses in the first ~~six months~~half of 2018 included $1.1 million of non-cash amortization expense of regulatory deferrals that would otherwise be a future liability of Idaho customers. ~~Also, transmission and distribution asset maintenance expense increased $2.0 million~~

Based on its estimate of full-year 2019 return on year-end equity in the ~~second quarter of 2018 compared with~~Idaho jurisdiction (Idaho ROE), in the first half of 2017 due to higher maintenance service costs. Labor and benefit costs increased $1.7 million primarily related to the timing of accruals for variable employee-related costs, which resulted in earlier recognition of expense in the first six months of 2018 compared with 2017.

~~Idaho Power's income tax expense, excluding the $1.3 million flow-through benefit of tax deductible make-whole premiums that~~2019, Idaho Power ~~paid~~recorded no additional accumulated deferred investment tax credits (ADITC) amortization under the Idaho regulatory settlement stipulation approved in connection with the early redemption of long-term debt in April 2018, was $11.6 million lower during the first six months of 2018 compared with the first six months of 2017, due mostly to the lower federal and state statutory income tax rates resulting from income tax reform discussed in further detail below.October 2014.

Overview of General Factors and Trends Affecting Results of Operations and Financial Condition

IDACORP's and Idaho Power's results of operations and financial condition are affected by a number of factors, and the impact of those factors is discussed in more detail below in this MD&A. To provide context for the discussion elsewhere in this report, some of the more notable factors are summarized below:

~~Income Tax Reform:~~ In December 2017, the Tax Cuts and Jobs Act was signed into law, which lowered the corporate federal income tax rate from 35 percent to 21 percent and modified or eliminated certain federal income tax deductions for corporations. The majority of the changes, including the rate reduction, became effective on January 1, 2018. In March 2018, Idaho House Bill 463 was signed into law reducing the Idaho state corporate income tax rate from 7.4 percent to 6.925 percent. In May 2018, the IPUC ~~issued an order approving~~ a settlement stipulation (May 2018 Idaho Tax Reform Settlement Stipulation) related to income tax reform. Beginning June 1, 2018, the settlement stipulation provides an annual (a) $18.7 million reduction to Idaho customer base rates and (b) $7.4 million amortization of existing regulatory deferrals for specified items or future amortization of other existing or future unspecified regulatory deferrals that would otherwise be a future liability recoverable from Idaho customers. Additionally, a one-time ~~benefit~~ ~~of a $7.8 million rate reduction is being provided to Idaho customers through the Idaho-jurisdiction power cost adjustment (PCA) mech~~anism during the period from June 1, 2018, through May 31, 2019, for the income tax reform benefits accrued from January 1, 2018 to May 31, 2018, and the income tax reform benefits related to Idaho Power's OATT. The amount provided via the PCA mechanism will decrease to $2.7 million on June 1, 2019, for income tax reform benefits related to Idaho Power's OATT and will cease on June 1, 2020, to reflect the impact of a full year of reduced OATT third-party transmission revenues. The May 2018 Idaho Tax Reform Settlement Stipulation was designed to return to Idaho customers their share of the estimated annual pro forma tax expense reductions resulting from income tax reform, based on the full-year 2017 as required by the IPUC. Idaho Power financial results from 2018 forward will be affected by any differences between annual income tax expense and the pro forma 2017 income tax expense used in the settlement until affected by a future rate proceeding or rate case. The May 2018 Idaho Tax Reform Settlement Stipulation also provides for the indefinite extension of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation beyond its termination date of December 31, 2019. Refer to "Regulatory Matters" in this MD&A for more information on the related regulatory proceedings.

~~Regulation of Rates and Cost Recovery:~~ The price that Idaho Power is authorized to charge for its electric and transmission service is a critical factor in determining IDACORP's and Idaho Power's results of operations and financial condition. Those rates are established by state regulatory commissions and the FERC and are intended to allow Idaho Power an opportunity to recover its expenses and earn a reasonable return on investment. Idaho Power focuses on timely recovery of its costs through filings with its regulators, working to put in place innovative regulatory mechanisms, and on the prudent management of expenses and investments. Idaho Power currently has a regulatory settlement stipulation in Idaho that includes provisions for the accelerated amortization of certain tax credits to help achieve a minimum 9.5 percent Idaho ROE. The settlement stipulation also provides for the potential sharing between Idaho Power and customers of Idaho-jurisdictional earnings in excess of specified levels of Idaho ROE. In May 2018, the IPUC approved an Idaho settlement stipulation that provides for the indefinite extension of the current mechanism with the modification of certain terms, which are described in "Regulatory Matters" in this MD&A and in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report. During 2018, Idaho Power will continue to assess the need to file a general rate case to reset base rates, but does not anticipate filing a rate case in the next twelve months.

~~Economic Conditions and Loads:~~ ~~Economic conditions impact consumer demand for energy, revenues, collectability of accounts, the volume of wholesale energy sales, and the need to construct and improve infrastructure, purchase~~

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•

Regulation of Rates and Cost Recovery: The prices that Idaho Power is authorized to charge for its electric and transmission service is a critical factor in determining IDACORP's and Idaho Power's results of operations and financial condition. Those rates are established by state regulatory commissions and the FERC and are intended to allow Idaho Power an opportunity to recover its expenses and earn a reasonable return on investment. Idaho Power focuses on timely recovery of its costs through filings with its regulators, working to put in place innovative regulatory mechanisms, and on the prudent management of expenses and investments. Idaho Power has regulatory settlement stipulations in Idaho that include provisions for the accelerated amortization of certain tax credits to help achieve a minimum 9.5 percent (9.4 percent after 2019) Idaho ROE. The settlement stipulations also provide for the potential sharing between Idaho Power and its Idaho customers of Idaho-jurisdictional earnings in excess of 10.0 percent of Idaho ROE. The settlement stipulations provide for modification of certain terms and the indefinite extension of the mechanism beyond the original termination date of December 31, 2019. The specific terms of these settlement stipulations are described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 2018 Annual Report. During 2019, Idaho Power will continue to assess the need to file a general rate case to reset base rates but does not anticipate filing a rate case in the next twelve months.

power, and implement programs to meet customer load demands. In recent years, Idaho Power has seen growth in the number of customers in its service area. Over the 12 months ended June 30, 2018, Idaho Power's customer count grew by 2.2 percent. Idaho Power expects its number of customers to continue to increase in the foreseeable future. Employment in Idaho Power's service area grew by approximately 3.2 percent during the twelve months ended June 30, 2018, based on Idaho Department of Labor preliminary June 2018 data. Idaho Power has in recent years supported State of Idaho-coordinated efforts to promote economic development with an emphasis on attracting industrial and commercial customers to its service area.

Idaho Power’s system is dual peaking, with the larger peak demand occurring in the summer. On July 9, 2018, Idaho Power reached its highest system peak demand so far in 2018 of 3,392 MW, which was 30 MW below the all-time system peak demand. The all-time system peak demand was 3,422 MW, set on July 7, 2017.

•

Economic Conditions and Loads: Economic conditions impact consumer demand for energy, revenues, collectability of accounts, the volume of wholesale energy sales, and the need to construct and improve infrastructure, purchase power, and implement programs to meet customer load demands. In recent years, Idaho Power has seen growth in the number of customers in its service area. Over the 12 months ended June 30, 2019, Idaho Power's customer count grew by 2.5 percent. Idaho Power expects its number of customers to continue to increase in the foreseeable future. Employment in Idaho Power's service area grew by approximately 2.7 percent during the twelve months ended June 30, 2019, based on Idaho Department of Labor preliminary June 2019 data. Idaho Power has in recent years supported State of Idaho-coordinated efforts to promote economic development with an emphasis on attracting industrial and commercial customers to its service area.

In June ~~2017,~~2019, Idaho Power ~~filed~~released its 2019 Integrated Resource Plan (IRP)~~, Idaho Power's long-term forecast of loads and resources.~~. The load forecast assumptions Idaho Power used in the ~~2017~~2019 IRP are included in the table below. For comparison purposes, the analogous average annual growth rates used in the prior two IRPs are included.


	5-Year Forecast		20-Year Forecast		5-Year Forecast		20-Year Forecast
	Annual Growth Rate: Retail Sales (Billed MWh)	Annual Growth Rate: Annual Peak (Peak Demand)	Annual Growth Rate: Retail Sales (Billed MWh)	Annual Growth Rate: Annual Peak (Peak Demand)	Annual Growth Rate: Retail Sales (Billed MWh)	Annual Growth Rate: Annual Peak (Peak Demand)	Annual Growth Rate: Retail Sales (Billed MWh)	Annual Growth Rate: Annual Peak (Peak Demand)
2019 IRP					1.3%	1.4%	1.0%	1.2%
2017 IRP	1.1%	1.6%	0.9%	1.4%	1.1%	1.6%	0.9%	1.4%
2015 IRP	1.1%	1.5%	1.1%	1.4%	1.5%	1.8%	1.2%	1.5%
2013 IRP	1.2%	1.5%	1.0%	1.3%

•

Weather Conditions: Weather and agricultural growing conditions have a significant impact on Idaho Power's energy sales. Relatively low and high temperatures result in greater energy use for heating and cooling, respectively. During the agricultural growing season, which in large part occurs during the second and third quarters, irrigation customers use electricity to operate irrigation pumps, and weather conditions can impact the timing and extent of use of those pumps. Idaho Power also has tiered rates and seasonal rates, which contribute to increased revenues during higher-load periods, most notably during the third quarter of each year when overall customer demand is highest. Much of the adverse or favorable impact of weather on sales of energy to residential and small commercial customers is mitigated through the Idaho FCA mechanism, which is described in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report.

~~Weather Conditions:~~ Weather and agricultural growing conditions have a significant impact on Idaho Power's energy sales. Relatively low and high temperatures result in greater energy use for heating and cooling, respectively. During the agricultural growing season, which in large part occurs during the second and third quarters, irrigation customers use electricity to operate irrigation pumps, and weather conditions can impact the timing and extent of use of those pumps. Idaho Power also has tiered rates and seasonal rates, which contribute to increased revenues during higher-load periods, most notably during the third quarter of each year when overall customer demand is highest. Much of the adverse or favorable impact of weather on sales of energy to residential and small commercial customers is mitigated through the Idaho FCA mechanism, which is described in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements in this report.

Further, as Idaho Power's ~~hydroelectric~~hydropower facilities comprise nearly one-half of Idaho Power's nameplate generation capacity, precipitation levels impact the mix of Idaho Power's generation resources. When ~~hydroelectric~~hydropower generation is reduced, Idaho Power must rely on more expensive generation sources and purchased power. When favorable ~~hydroelectric~~hydropower generating conditions exist for Idaho Power, they also may exist for other Pacific Northwest ~~hydroelectric~~hydropower facility operators, lowering regional wholesale market prices and impacting the revenue Idaho Power receives from wholesale energy ~~sales of its excess power.~~sales. Much of the adverse or favorable impact of this volatility is addressed through the Idaho and Oregon power cost adjustment mechanisms. For ~~2018,~~2019, Idaho Power expects generation from its ~~hydroelectric~~hydropower resources to be in the range of 8.0 to 9.0 million MWh, compared with 20-year average annual ~~hydroelectric~~hydropower generation of ~~7.6~~7.5 million MWh.

~~Rate Base Growth and Infrastructure Investment:~~ As noted above, the rates established by the IPUC and OPUC are determined so as to provide an opportunity for Idaho Power to recover authorized operating expenses and earn a reasonable return on “rate base.” Rate base is generally determined by reference to the original cost (net of accumulated depreciation) of utility plant in service and certain other assets, subject to various adjustments for deferred taxes and other items. Over time, rate base is increased by additions to utility plant in service and reduced by depreciation and retirement of utility plant and write-offs as authorized by the IPUC and OPUC. In recent years, Idaho Power has been pursuing significant enhancements to its utility infrastructure, including major ongoing transmission projects such as the Boardman-to-Hemingway and Gateway West projects, in an effort to ensure an adequate supply of electricity, to provide service to new customers, and to maintain system reliability. Idaho Power's existing hydroelectric and thermal generation facilities also require continuing upgrades and component replacement, and the company is undertaking a significant relicensing effort for the HCC, its largest hydroelectric generation resource. Idaho Power expects to include completed capital projects in its next general rate case or, in circumstances where appropriate, a single-issue rate case for individual projects with a significant capital cost. Depending on the outcome of

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•

Rate Base Growth and Infrastructure Investment: As noted above, the rates established by the IPUC and OPUC are determined so as to provide an opportunity for Idaho Power to recover authorized operating expenses and earn a reasonable return on “rate base.” Rate base is generally determined by reference to the original cost (net of accumulated depreciation) of utility plant in service and certain other assets, subject to various adjustments for deferred taxes and other items. Over time, rate base is increased by additions to utility plant in service and reduced by depreciation and retirement of utility plant and write-offs as authorized by the IPUC and OPUC. In recent years, Idaho Power has been pursuing significant enhancements to its utility infrastructure in an effort to maintain system reliability, to ensure an adequate supply of electricity, and to provide service to new customers, including major ongoing transmission projects such as the Boardman-to-Hemingway and Gateway West projects. Idaho Power's existing hydropower and thermal generation facilities also require continuing upgrades and equipment replacement, and the company is undertaking a significant relicensing effort for the Hells Canyon Complex (HCC), its largest hydropower generation resource. Idaho Power intends to pursue inclusion of significant completed capital projects into rate base as part of a general rate case or other appropriate regulatory proceeding.

~~the regulatory process and items such as the rate of return authorized by the IPUC and OPUC, this growth in rate base has the potential to increase Idaho Power's revenues and earnings.~~

•

Mitigation of Impact of Fuel and Purchased Power Expense: In addition to hydropower generation, Idaho Power relies significantly on natural gas and coal to fuel its generation facilities and on power purchases in the wholesale markets. Fuel costs are impacted by electricity sales volumes, the terms and conditions of contracts for fuel, Idaho Power's generation capacity, the availability of hydropower generation resources, transmission capacity, energy market prices, and Idaho Power's hedging program for managing fuel costs. Purchased power costs are impacted by the terms and conditions of contracts for purchased power, the rate of expansion of alternative energy generation sources such as wind or solar energy, and wholesale energy market prices. The Idaho and Oregon power cost adjustment mechanisms mitigate in large part the potential adverse impacts to Idaho Power of fluctuations in power supply costs.

~~Mitigation of Impact of Fuel and Purchased Power Expense:~~ In addition to hydroelectric generation, Idaho Power relies significantly on natural gas and coal to fuel its generation facilities and power purchases in the wholesale markets. Fuel costs are impacted by electricity sales volumes, the terms of contracts for fuel, Idaho Power's generation capacity, the availability of hydroelectric generation resources, transmission capacity, energy market prices, and Idaho Power's hedging program for managing fuel costs. Recently, low natural gas prices have made operation of Idaho Power's natural gas power plants more economical, resulting in increased operation of those plants and decreased operation of coal-fired plants. Purchased power costs are impacted by the terms of contracts for purchased power, the rate of expansion of alternative energy generation sources such as wind or solar energy, and wholesale energy market prices. The Idaho and Oregon power cost adjustment mechanisms mitigate in large part the potential adverse impacts of fluctuations in power supply costs to Idaho Power.

~~Regulatory and Environmental Compliance Costs:~~ Idaho Power is subject to extensive federal and state laws, policies, and regulations, as well as regulatory actions and audits by agencies and quasi-governmental agencies, including the FERC, the North American Electric Reliability Corporation, and the Western Electricity Coordinating Council. Compliance with these requirements directly influences Idaho Power's operating environment and affects Idaho Power's operating costs. Environmental laws and regulations, in particular, may increase the cost of operating generation plants and constructing new facilities, require that Idaho Power install additional pollution control devices at existing generating plants, or require that Idaho Power cease operating certain generation plants. Idaho Power expects to spend a considerable amount on environmental compliance and controls in the next decade.

•

Regulatory and Environmental Compliance Costs: Idaho Power is subject to extensive federal and state laws, policies, and regulations, as well as regulatory actions and audits by agencies and quasi-governmental agencies, including the FERC, the North American Electric Reliability Corporation, and the Western Electricity Coordinating Council. Compliance with these requirements directly influences Idaho Power's operating environment and affects Idaho Power's operating costs. Recently, energy industry regulators have issued substantial penalties for utilities alleged to have violated reliability and critical infrastructure protection requirements. Moreover, environmental laws and regulations, in particular, may increase the cost of constructing new facilities, may increase the cost of operating generation plants, including Idaho Power's jointly-owned coal-fired generating plants, may require that Idaho Power install additional pollution control devices at existing generating plants, or may require that Idaho Power cease operating certain generation plants. Idaho Power expects to spend significant amounts on environmental compliance and controls in the next decade, and due to economic factors in part associated with the costs of compliance with environmental regulation, has accelerated the retirement dates of two of its co-owned coal-fired power plants.

•

Water Management and Relicensing of the Hells Canyon Hydropower Project: Because of Idaho Power's reliance on stream flow in the Snake River and its tributaries, Idaho Power participates in numerous proceedings and venues that may affect its water rights, seeking to preserve the long-term availability of its rights for its hydropower projects. Also, Idaho Power is involved in renewing its long-term federal license for the HCC, its largest hydropower generation source. Given the number of parties involved, Idaho Power's relicensing costs have been and are expected to continue to be substantial. Idaho Power cannot currently determine the ultimate terms of, and costs associated with, any resulting long-term license.

~~Water Management and Relicensing of the Hells Canyon Hydroelectric Project:~~ Because of Idaho Power's reliance on stream flow in the Snake River and its tributaries, Idaho Power participates in numerous proceedings and venues that may affect its water rights, seeking to preserve the long-term availability of its rights for its hydroelectric projects. Also, Idaho Power is involved in renewing its long-term federal license for the HCC, its largest hydroelectric generation source. Given the number of parties involved, Idaho Power's relicensing costs have been and are expected to continue to be substantial. Idaho Power cannot currently determine the ultimate terms of, and costs associated with, any resulting long-term license.

RESULTS OF OPERATIONS

This section of MD&A takes a closer look at the significant factors that affected IDACORP’s and Idaho Power’s earnings during the three and six months ended June 30, ~~2018.~~2019. In this analysis, the results for the three and six months ended June 30, ~~2018,~~2019, are compared with the same ~~period~~periods in ~~2017.~~2018.

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The table below presents Idaho Power’s energy sales and supply (in thousands of MWh) for the three and six months ended June 30, ~~2018~~2019 and ~~2017.~~2018.


	Three months ended June 30,				Six months ended June 30,				Three months ended June 30,				Six months ended June 30,
	2018		2017		2018		2017		2019		2018		2019		2018
Retail energy sales	3,576		3,464		6,822		6,872		3,409		3,576		6,780		6,822
Wholesale energy sales	821		751		1,681		1,439		1,042		821		1,902		1,681
Bundled energy sales	73		85		297		151		—		73		146		297
Total energy sales	4,470		4,300		8,800		8,462		4,451		4,470		8,828		8,800
Hydroelectric generation	2,847		2,815		5,571		5,177		3,032		2,847		5,132		5,571
Coal generation	459		505		1,067		1,342		422		459		1,554		1,067
Natural gas and other generation	124		68		228		399		137		124		564		228
Total system generation	3,430		3,388		6,866		6,918		3,591		3,430		7,250		6,866
Purchased power	1,383		1,246		2,572		2,154		1,195		1,404		2,256		2,594
Line losses	(343	)	(334	)	(638	)	(610	)	(335	)	(364	)	(678	)	(660	)
Total energy supply	4,470		4,300		8,800		8,462		4,451		4,470		8,828		8,800

~~Table of Contents~~

~~Sales Volume and Generation:~~ In the second quarter of 2018, retail sales volumes increased 112 thousand MWh, or 3 percent, compared with the second quarter of 2017. During the first six months of 2018, retail sales volumes decreased 50 thousand MWh, or 1 percent, compared with the same period in the prior year. Customer growth increased sales volumes duringWeather-related information for Boise, Idaho for the three and six months ended June 30, 2019 and 2018, ~~compared with~~is presented in the ~~same periods in 2017, with~~table below. While Boise, Idaho weather conditions are not necessarily representative of weather conditions throughout Idaho Power's service area, the ~~number~~greater Boise area has the majority of Idaho Power's customers growing by 2.2 percent over the prior twelve months. During the second quarter of 2018, usage per irrigation customer was approximately 15 percent higher compared with the same period in 2017. Precipitationand is included for illustrative purposes.



	Three months ended June 30,			Six months ended June 30,
	2019	2018	Normal	2019	2018	Normal ⁽²⁾
Heating degree-days⁽¹⁾	583	486	298	3,020	2,783	2,778
Cooling degree-days⁽¹⁾	159	192	183	159	192	183
Precipitation (inches)	6.0	3.1	3.3	12.1	6.9	6.9

(1) Heating and cooling degree-days are common measures used in the ~~Idaho Power service area during~~utility industry to analyze the ~~three months ended June 30, 2018 was significantly less than in the same period of 2017, which increased usage by irrigation customers. Usage per residential~~demand for electricity and indicate when a customer was approximately 4 percent and 8 percent lower in the second quarter and the first six months of 2018, respectively, compared with the second quarter and first six months of 2017. The decrease in residential usage was primarily due to more moderate weather during the first six months of 2018 compared with the first six months of 2017, which decreased thewould use of electricity for heating and cooling. A degree-day measures how much the average daily temperature varies from 65 degrees. Each degree of temperature above 65 degrees is counted as one cooling ~~purposes. Heating~~degree-day, and each degree of temperature below 65 degrees is counted as one heating degree-day.

(2) Normal heating degree-days ~~were 16 percent lower during~~and cooling degree-days elements are, by convention, the ~~six months ended June~~arithmetic mean of the elements computed over 30 ~~2018 compared with~~consecutive years. The normal amounts are the ~~six months ended June 30, 2017,~~sum of the monthly normal amounts. These normal amounts are computed by the National Oceanic and ~~13 percent below normal during the six months ended June 30, 2018.~~Atmospheric Administration.

~~Wholesale energy~~Sales Volume and Generation: Retail sales volumes ~~increased 70 thousand MWh, or 9~~decreased 5 percent and ~~242 thousand MWh, or 17~~1 percent in the second quarter and first six months of ~~2018,~~2019, respectively, compared with the same periods of 2018. During the second quarter of 2019, usage per irrigation customer was approximately 20 percent lower compared with the same period in 2018. Precipitation in the Idaho Power service area increased significantly during the three months ended June 30, 2019, compared with the same period of 2018, which decreased usage by irrigation customers. During the second quarter of 2019, usage per residential customer was approximately 3 percent lower than the same period of 2018, primarily due to cooler temperatures during the second quarter of 2019, which decreased the use of electricity for cooling purposes. Cooling degree-days in Boise, Idaho, were 17 percent lower during the three months ended June 30, 2019, compared with the three months ended June 30, 2018, and 13 percent below normal. Customer growth partially offset the decrease in sales volumes per customer during the three and six months ended June 30, 2019, compared with the same periods in 2018, with the number of Idaho Power's customers growing by 2.5 percent over the prior twelve months.

Total system generation increased 5 percent and 6 percent, respectively, during the second quarter and first six months of ~~2017, due primarily to an increase~~2019 compared with the same periods in ~~hydroelectric generation and purchased power resulting in increased energy available for wholesale energy sales. For~~2018. In the second quarter and first six months of ~~2018, hydroelectric generation comprised 83~~2019, higher regional energy market prices resulted in a 15 percent and 8113 percent ~~of Idaho Power's total system generation,~~decrease, respectively, in purchased power volumes compared with ~~83 percent and 75 percent, respectively, for~~ the ~~second quarter and first six months~~same periods of ~~2017. Generation from~~2018 as Idaho ~~Power's hydroelectric plants increased due~~Power used its own generation resources to ~~strong reservoir storage attributable to above-normal snowpack from 2017 and near-normal snowpack in 2018.~~meet customer demand.

The financial impacts of fluctuations in wholesale energy sales, purchased power, fuel expense, and other power supply-related expenses are addressed in Idaho Power's Idaho and Oregon power cost adjustment mechanisms, which are described later in this MD&A.

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Operating Revenues

Retail Revenues: The table below presents Idaho Power’s retail revenues (in thousands) and MWh sales volumes (in thousands) for the three and six months ended June 30, ~~2018~~2019 and ~~2017,~~2018, and the number of customers as of June 30, ~~2018~~2019 and ~~2017.~~2018.


	Three months ended June 30,						Six months ended June 30,						Three months ended June 30,						Six months ended June 30,
	2018			2017			2018			2017			2019			2018			2019			2018
Retail revenues:
Residential (includes $5,508, $3,205, $19,052 and $8,331, respectively, related to the FCA⁽¹⁾)	$	109,155		$	112,534		$	255,838		$	264,689
Commercial(includes $291, $276, $652 and $387, respectively, related to the FCA⁽¹⁾)	76,965			78,982			151,191			153,260
Residential (includes $7,232, $5,508, $18,543, and $19,052, respectively, related to the FCA)⁽¹⁾													$	104,797		$	109,155		$	255,016		$	255,838
Commercial(includes $350, $291, $691, and $652, respectively, related to the FCA)⁽¹⁾													70,973			76,965			144,079			151,191
Industrial	48,868			49,766			94,660			95,224			45,602			48,868			91,100			94,660
Irrigation	65,065			56,068			65,471			56,993			48,954			65,065			49,953			65,471
Deferred revenue related to HCC relicensing AFUDC⁽²⁾	(1,462		)	(2,349		)	(4,046		)	(4,933		)	(1,927		)	(1,462		)	(4,046		)	(4,046		)
Total retail revenues	$	298,591		$	295,001		$	563,114		$	565,233		$	268,399		$	298,591		$	536,102		$	563,114
Volume of retail sales (MWh)
Residential	1,036			1,057			2,439			2,597			1,032			1,036			2,522			2,439
Commercial	969			952			1,970			1,980			945			969			1,964			1,970
Industrial	815			811			1,648			1,641			830			815			1,682			1,648
Irrigation	756			644			765			654			602			756			612			765
Total retail MWh sales	3,576			3,464			6,822			6,872			3,409			3,576			6,780			6,822
Number of retail customers at period end
Residential	458,448			448,159									470,609			458,448
Commercial	71,074			69,818									72,318			71,074
Industrial	116			121									128			116
Irrigation	21,165			20,886									21,370			21,165
Total customers	550,803			538,984									564,425			550,803

⁽¹⁾ The FCA mechanism is an alternative revenue program and does not represent revenue from contracts with customers.

⁽²⁾As part of its January 30, 2009, general rate case order, the IPUC is allowing Idaho Power to recover a portion of the allowance for funds used during construction (AFUDC) on construction work in progress related to the HCC relicensing process, even though the relicensing process is not yet complete and the costs have not been moved to electric plant in service. Idaho Power is collecting approximately $8.8 million annually in the Idaho jurisdiction but is deferring revenue recognition of the amounts collected until the license is issued and the accumulated license costs approved for recovery are placed in service. ~~Prior to the May 2018 Idaho Tax Reform Settlement Stipulation described in Note 3 - "Regulatory Matters," Idaho Power was collecting $10.7 million annually.~~

Changes in rates, changes in customer demand, and changes in FCA mechanism revenues are the primary reasons for fluctuations in retail revenues from period to period. The primary influences on customer demand for electricity are weather, economic conditions, and ~~economic conditions.~~energy efficiency. Extreme temperatures increase sales to customers who use electricity for cooling and heating, while moderate temperatures decrease sales. Precipitation levels and the timing of precipitation during the agricultural growing season also affect sales to customers who use electricity to operate irrigation pumps. Rates are also seasonally adjusted, providing for higher rates during peak load periods, and residential customer rates are tiered, providing for higher rates based on higher levels of usage. The seasonal and tiered rate structures contribute to seasonal fluctuations in revenues and earnings. ~~For purposes of illustration, Boise, Idaho weather-related information for the three and six months ended June 30, 2018 and 2017, is presented in the table that follows.~~

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Three months ended
June 30, Six months ended
June 30,
2018 2017 Normal 2018 2017
Normal ⁽²⁾
Heating degree-days⁽¹⁾
486
720
719
2,783
3,311
3,199
Cooling degree-days⁽¹⁾
192
233
183
192
233
183
Precipitation (inches) 3.1
4.2
3.3
6.9
11.2
6.9

⁽¹⁾ Heating and cooling degree-days are common measures used in the utility industry to analyze the demand for electricity and indicate when a customer would use electricity for heating and air conditioning. A degree-day measures how much the average daily temperature varies from 65 degrees. Each degree of temperature above 65 degrees is counted as one cooling degree-day, and each degree of temperature below 65 degrees is counted as one heating degree-day. While Boise, Idaho weather conditions are not necessarily representative of weather conditions throughout Idaho Power's service area, the greater Boise area has the majority of Idaho Power's customers.

⁽²⁾ Normal heating degree-days and cooling degree-days elements are, by convention, the arithmetic mean of the elements computed over 30 consecutive years. The normal amounts are the sum of the monthly normal amounts. These normal amounts are computed by the National Oceanic and Atmospheric Administration.

Retail revenues ~~increased $3.6~~decreased $30.2 million during the second quarter of ~~2018, but~~2019, and decreased ~~$2.1~~$27.0 million during the first six months of ~~2018,~~2019, compared with the same periods in ~~2017.~~2018. The factors affecting retail revenues during the period are discussed below.

•

Rates: Customer rates, excluding collections of amounts related to the power cost adjustment mechanism, decreased revenues by approximately $9 million and $6 million for the three and six months ended June 30, 2019, respectively, compared with the same periods in 2018. The settlement stipulations approved by the IPUC and OPUC during the second quarter of 2018 relating to income tax reform reduced revenues in the second quarter and first six months of 2019 more significantly than in the same periods of 2018. To a lesser extent, changes in the customer sales mix decreased average rates as volumes sold to residential customers made up a lesser portion of the customer sales mix in the second quarter of 2019 compared with the second quarter of 2018. Residential, commercial, and irrigation customers generally pay a higher per-MWh rate than industrial customers.

~~Rates: Rate changes, including~~Customer rates also include the ~~revenue accruals provided for~~return to customers of amounts related to the power cost adjustment mechanism, which decreased revenues by $9.4 million and $17.1 million in the ~~2017 Valmy Plant settlement stipulations~~second quarter and ~~the revenue reductions due to the settlement stipulations related to recent income tax reform, decreased retail revenues by $7.3 million and $6.6 million for the three and~~first six months ~~ended June 30, 2018,~~of 2019, respectively, compared with the same periods in 2017. In the second quarter of 2017, the IPUC and OPUC each approved settlement stipulations related to Idaho Power’s plan to end its participation in coal-fired operations at the Valmy Plant by the end of 2025. The Valmy Plant settlement stipulations provided for an accrual of six months of the increase in retail revenues, depreciation expense, and associated income tax expenses in the second quarter of 2017, resulting in a decrease in these items in the second quarter of 2018 compared with the same period in 2017. As a direct result of settlement stipulations approved by the IPUC and OPUC during the second quarter of 2018 relating to income tax reform, Idaho Power's revenues decreased in the second quarter of 2018. Also, more moderate winter and spring temperatures in the first half of 2018 compared with the first half of 2017 led to a lower proportion of residential sales in higher rate categories under Idaho Power's tiered rate structure in the first half of 2018. The ~~customer~~amount returned to customers in rates ~~include collection of amounts related to~~under the ~~PCA~~power cost adjustment mechanism which decreased revenue $0.8 million in the three months ended June 30, 2018, but increased revenue $2.5 million in the six months ended June 30, 2018, compared with the first three and six months of 2017. The collection of amounts related to the PCA mechanism in rates has no effect on operating income as a corresponding amount is recorded as expense in the same period it is ~~collected~~returned through rates.

~~Customers: Continued customer growth increased retail revenues $2.2 million~~ Also, during the second quarter and ~~$5.6 million in the~~ first ~~three and~~ six months of ~~2018, respectively,~~2019, residential and commercial customers used less energy per customer for cooling purposes, primarily due to cooler temperatures compared with the same periods ~~in 2017.~~of 2018.


•	Customers: Customer growth of 2.5 percent increased retail revenues by $5.6 million and $11.7 million in the second quarter and first six months of 2019, respectively, compared with the same periods of 2018.

•

Usage: Decreased usage (on a per customer basis), primarily by irrigation customers, decreased retail revenues by $19.6 million and $15.3 million for the second quarter and first six months of 2019, respectively, compared with the same periods of 2018. Decreased usage by irrigation customers was primarily the result of higher precipitation in Idaho Power's service area during the second quarter and first six months of 2019 compared with the same periods of 2018.

•

Idaho FCA Revenue: The FCA mechanism, applicable to Idaho residential and small commercial customers, adjusts revenue each year to accrue, or defer, the difference between the authorized fixed-cost recovery amount per customer and the actual fixed costs per customer recovered by Idaho Power through volume-based rates during the year. Lower usage (on a per customer basis) by residential and small general service customers during the second quarter of 2019 increased the amount of FCA revenue accrued by $1.8 million compared with the second quarter of 2018. Higher usage (on a per customer basis) by residential and small general service customers during the first six months of 2019 decreased the amount of FCA revenue accrued by $0.5 million compared with the same period in 2018.

~~Usage~~: Higher usage (on a per customer basis), primarily by irrigation customers, increased retail revenues by $6.3 million during the second quarter of 2018 when compared with the second quarter of 2017. Increased usage was primarily the result of lower precipitation in the Idaho Power service area during the second quarter of 2018 compared with the second quarter of 2017, which led to increased usage by irrigation customers. For the six months ended June 30, 2018, a 15 percent increase in usage per irrigation customer was more than offset by an 8 percent decrease in usage per residential customer, compared with the same period in 2017, resulting in a decrease in retail revenues of $12.0 million. Decreased usage per residential customer was primarily the result of more moderate winter and spring temperatures in Idaho Power's service area, which led to decreased usage by residential customers for heating and cooling. Heating degree-days were 16 percent lower during the first half of 2018 compared with the first half of 2017.

~~FCA Revenue~~: The FCA mechanism adjusts revenue each year to accrue, or defer, the difference between the authorized fixed-cost recovery amount per customer and the actual fixed costs per customer recovered by Idaho Power through volume-based rates during the year. Lower usage (on a per customer basis) by residential and small general service customers during the three and six months ended June 30, 2018 increased the amount of FCA revenue accrued by $2.3 million and $11.0 million, respectively, compared with the same periods in 2017.

~~Table of Contents~~

Wholesale Energy Sales: Wholesale energy sales consist primarily of long-term sales contracts, opportunity sales of surplus system energy, and sales into the ~~Western EIM,~~energy imbalance market implemented in the western United States (Western EIM), and do not include derivative transactions. The table below presents Idaho Power’s wholesale energy sales for the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands, except for per MWh amounts).


	Three months ended June 30,				Six months ended June 30,				Three months ended June 30,				Six months ended June 30,
	2018		2017		2018		2017		2019		2018		2019		2018
Wholesale energy revenues	$	10,214	$	6,003	$	24,283	$	13,967	$	16,158	$	8,919	$	63,373	$	22,685
Wholesale MWh sold	821		751		1,681		1,439		1,042		821		1,902		1,681
Wholesale energy revenues per MWh	$	12.44	$	7.99	$	14.45	$	9.71
Average wholesale energy revenues per MWh									$	15.51	$	10.86	$	33.32	$	13.49

In the second quarter and first ~~three and~~ six months of ~~2018,~~2019, wholesale energy ~~revenue~~revenues increased by ~~$4.2~~$7.2 million ~~or 70 percent,~~ and ~~$10.3~~$40.7 million, ~~or 74 percent,~~ respectively, compared with the same periods of ~~2017. The average price of wholesale~~2018. Wholesale energy sales ~~was 56~~volumes increased 27 percent and 4913 percent ~~higher for~~in the ~~three~~second quarter and first six months ~~ended June 30, 2018,~~of 2019, respectively, compared with the same periods of ~~2017. Wholesale energy sales volumes increased 9 percent and 17 percent~~2018. Below-normal temperatures in the Northwest, a decrease in energy imports due to equipment maintenance, and limited production from the federal hydroelectric system due to freezing temperatures and low water flow increased regional wholesale energy prices during the first ~~three~~quarter, and ~~six months~~to a lesser extent, the second quarter of ~~2018, respectively,~~2019, compared with the same periods of ~~2017, as generation from Idaho Power's hydroelectric plants increased due~~2018. During the fourth quarter of 2018, a natural gas pipeline ruptured in British Columbia, Canada, disrupting natural gas flows to ~~strong reservoir storage attributable to above-normal snowpack from 2017~~the Pacific Northwest and ~~near-normal snowpack in 2018. The increase in hydroelectric generation resulted in additional~~Western Canada, driving up wholesale energy ~~available for wholesale sales~~and natural gas prices in the region. During the first ~~three~~quarter and ~~six months~~the beginning of ~~2018~~the second quarter of 2019, the pipeline was operating at reduced capacity, which also contributed to continued increased energy prices during the periods.

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Transmission Wheeling-Related Revenues: Transmission wheeling-related revenues decreased $2.0 million, or 14 percent, during the second quarter of 2019 compared with the ~~same periods~~second quarter of ~~2017. The increase in wholesale energy sales volumes was also~~2018, primarily due to ~~transactions~~a decrease in ~~the Western EIM, which commenced in April 2018.~~

~~Transmission Services (Wheeling) Revenues:~~ ~~Revenue from transmission services increased $1.2 million and $3.8 million during the first three and six months of 2018, respectively, compared with the same periods of 2017, largely due to~~ Idaho Power's OATT rates that ~~increased~~became effective in October ~~2017.~~2018. Transmission wheeling-related revenues increased $2.0 million, or 8 percent, in the first six months of 2019 compared with the same period of 2018, largely due to an increase in wheeling-related volumes during the first three months of 2019, partially offset by a decrease in Idaho Power's OATT rates that became effective in October 2018. Regional wholesale energy market activity increased wheeling-related volumes in the first quarter of 2019.

Energy Efficiency Program Revenues: In both Idaho and Oregon, energy efficiency riders fund energy efficiency program expenditures. Expenditures funded through the riders are reported as an operating expense with an equal amount recorded in revenues, resulting in no net impact on earnings. The cumulative variance between expenditures and amounts collected through the rider is recorded as a regulatory asset or liability. A liability balance indicates that Idaho Power has collected more than it has spent and an asset balance indicates that Idaho Power has spent more than it has collected. At June 30, ~~2018,~~2019, Idaho Power's energy efficiency rider balances were a ~~$2.6~~$1.6 million regulatory liability in the Idaho jurisdiction and a ~~$6.5~~$1.2 million regulatory asset in the Oregon jurisdiction.

~~Table of Contents~~

Operating Expenses

Purchased Power: The table below presents Idaho Power’s purchased power expenses and volumes for the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands, except for per MWh amounts).


	Three months ended June 30,				Six months ended June 30,				Three months ended June 30,				Six months ended June 30,
	2018		2017		2018		2017		2019		2018		2019		2018
Expense
PURPA contracts	$	47,867	$	46,397	$	89,805	$	77,237	$	45,906	$	47,867	$	86,989	$	89,805
Other purchased power (including wheeling)	15,113		15,109		35,103		33,385		12,157		15,113		33,905		35,103
Total purchased power expense	$	62,980	$	61,506	$	124,908	$	110,622	$	58,063	$	62,980	$	120,894	$	124,908
MWh purchased
PURPA contracts	908		916		1,619		1,435		881		908		1,559		1,619
Other purchased power	475		330		953		719		314		496		697		975
Total MWh purchased	1,383		1,246		2,572		2,154		1,195		1,404		2,256		2,594
Cost per MWh from PURPA contracts	$	52.72	$	50.65	$	55.47	$	53.82
Cost per MWh from other sources	$	31.82	$	45.78	$	36.83	$	46.43
Average cost per MWh from PURPA contracts									$	52.11	$	52.72	$	55.80	$	55.47
Average cost per MWh from other sources									$	38.72	$	30.47	$	48.64	$	36.00
Weighted average - all sources	$	45.54	$	49.36	$	48.56	$	51.36	$	48.59	$	44.86	$	53.59	$	48.15

Purchased power expense ~~increased $1.5~~decreased $4.9 million, or 28 percent, and ~~$14.3~~$4.0 million, or 133 percent, in the second quarter and first ~~three and~~ six months of ~~2018, respectively,~~2019 compared with the same periods of ~~2017.~~2018. The ~~increase~~decrease in purchased power expense for the second quarter and first six months of 2019 compared with the same periods of 2018 was primarily due to ~~an increase of 13~~a 37 percent and 29 percent decrease, respectively, in MWh purchased from ~~generation projects under~~sources other than PURPA contracts, ~~offset partially by decreases in costs per MWh of other purchased power.~~

as Idaho Power ~~is required by federal law~~used its own generation to purchase power from some PURPA generation projects at a specified price regardless of the then-current load demand or wholesale energy market prices. The intermittent, non-dispatchable nature of most PURPA generation increases the likelihood that Idaho Power will at times be required to reduce output from its lower-cost hydroelectric and fossil fuel-fired generation resources and may be required to sell its excess power in the wholesale power market at a significant loss. The other purchased power cost per MWh often exceeds the wholesale energy sales revenue per MWh because Idaho Power generally needs to purchase more power during heavy load periods than during light load periods, and conversely has less energy available for wholesale energy sales during heavy load periods than light load periods. Market energy prices are typically higher during heavy load periods than during light load periods. Also, in accordance with Idaho Power's risk management policy, Idaho Power may purchase or sell energy several months in advance of anticipated delivery. The regional energy market price is dynamic and additional energy transactions that Idaho Power makes at current market prices may be noticeably different than the advance transaction prices. Most of the non-PURPA purchased power and substantially all of the PURPA power purchase costs are recovered through base rates and Idaho Power's power cost adjustment mechanisms.

meet customer demand.

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Fuel Expense: The table below presents Idaho Power’s fuel expenses and thermal generation for the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands, except for per MWh amounts).


	Three months ended June 30,				Six months ended June 30,				Three months ended June 30,				Six months ended June 30,
	2018		2017		2018		2017		2019		2018		2019		2018
Expense
Coal	$	18,092	$	16,638	$	41,373	$	44,494	$	16,687	$	18,092	$	55,310	$	41,373
Natural gas⁽¹⁾	3,423		3,778		7,877		12,174
Natural gas									4,139		3,423		17,386		7,877
Total fuel expense	$	21,515	$	20,416	$	49,250	$	56,668	$	20,826	$	21,515	$	72,696	$	49,250
MWh generated
Coal	459		505		1,067		1,342		422		459		1,554		1,067
Natural gas⁽¹⁾	124		68		228		399
Natural gas									137		124		564		228
Total MWh generated	583		573		1,295		1,741		559		583		2,118		1,295
Cost per MWh - Coal	$	39.42	$	32.95	$	38.78	$	33.15
Cost per MWh - Natural gas	$	27.60	$	55.56	$	34.55	$	30.51
Average cost per MWh - Coal									$	39.54	$	39.42	$	35.59	$	38.78
Average cost per MWh - Natural gas									$	30.21	$	27.60	$	30.83	$	34.55
Weighted average, all sources	$	36.90	$	35.63	$	38.03	$	32.55	$	37.26	$	36.90	$	34.32	$	38.03

⁽¹⁾~~Includes a negligible amount of expense and generation related to the Salmon diesel-fired generation plant.~~

The majority of the fuel for Idaho Power’s jointly-owned coal-fired plants is purchased through long-term contracts, including purchases from BCC, a one-third owned joint venture of IERCo. The price of coal from BCC is subject to fluctuations in mine operating expenses, geologic conditions, and production levels. BCC supplies up to two-thirds of the coal used by the Jim Bridger plant. Natural gas is mainly purchased on the regional wholesale spot market at published index prices. In addition to commodity (variable) costs, both natural gas and coal expenses include costs that are more fixed in nature for items such as capacity charges, transportation, and fuel handling. Period to period variances in fuel expense per MWh are noticeably impacted by these fixed charges when generation output is substantially different between the periods.

Fuel expense ~~increased $1.1~~decreased $0.7 million, or 53 percent, in the second quarter of ~~2018,~~2019, but ~~decreased $7.4~~increased $23.4 million, or 1348 percent, in the first six months of ~~2018,~~2019, compared with the same periods of ~~2017.~~2018. The ~~increase~~decrease in fuel expense in the second quarter of ~~2018~~2019 compared with the second quarter of ~~2017~~2018 was due to ana 7 percent increase in ~~the prices of coal purchased from BCC. BCC shipped fewer tons to the Jim Bridger plant,~~hydroelectric generation, which ~~resulted in a higher price per ton as fixed costs were spread over fewer tons. The decrease in the first half of 2018 compared with 2017 was primarily due to increased output from~~reduced Idaho Power's ~~hydroelectric plants, which reduced~~ utilization of gas and coal generation. ~~Generation from~~The increase in fuel expense in the ~~hydroelectric plants increased 1 percent and 8 percent during the~~ first ~~three and~~ six months of ~~2018, respectively,~~2019 compared with the same period of 2018, was due to thermal generation volumes, which were 64 percent higher in 2019 compared with 2018, partially offset by the beneficial impact of natural gas hedges entered into during the first six months of 2019. Increased thermal generation in the first six months of 2019 offset an 8 percent decrease in hydroelectric generation between the comparable periods and provided generation for economic sales of ~~2017. Generation from~~energy in the wholesale energy market. In the first six months of 2019, gains on financial gas hedges of $12.4 million, entered into in accordance with Idaho Power's ~~hydroelectric plants increased due~~energy risk management policies, reduced natural gas fuel expense. Most of these realized hedging gains are providing a benefit to ~~strong reservoir storage attributable to above-normal snowpack from 2017 and near-normal snowpack in 2018.~~customers through the power cost adjustment mechanisms described below.

Power Cost Adjustment Mechanisms: Idaho Power's power supply costs (primarily purchased power and fuel expense, less wholesale energy sales) can vary significantly from year to year. Volatility of power supply costs arises from factors such as weather conditions, wholesale market prices, volumes of power purchased and sold in the wholesale markets, Idaho Power's hydroelectric and thermal generation volumes and fuel costs, generation plant availability, and retail loads. To address the volatility of power supply costs, Idaho Power's power cost adjustment mechanisms in the Idaho and Oregon jurisdictions allow Idaho Power to recover from customers, or refund to customers, most of the fluctuations in power supply costs. In the Idaho jurisdiction, the PCA includes a cost or benefit sharing ratio that allocates the deviations in net power supply expenses between customers (95 percent) and Idaho Power (5 percent), with the exception of PURPA power purchases and demand response program incentives, which are allocated 100 percent to customers. The Idaho deferral period, or PCA year, runs from April 1 through March 31. Amounts deferred during the PCA year are primarily recovered or refunded during the subsequent June 1 through May 31 period. Because of the power cost adjustment mechanisms, the primary financial impacts of power supply cost variations is that cash is paid out but recovery from customers does not occur until a future period, or cash that is collected is refunded to customers in a future period, resulting in fluctuations in operating cash flows from year to year.

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The table that follows presents the components of the Idaho and Oregon power cost adjustment mechanisms for the three and six months ended June 30, ~~2018~~2019 and ~~2017~~2018 (in thousands).


	Three months ended June 30,				Six months ended June 30,				Three months ended June 30,					Six months ended June 30,
	2018		2017		2018		2017		2019			2018		2019			2018
Idaho power supply cost accrual	$	16,353	$	7,981	$	33,899	$	21,844
Power supply cost accrual									$	24,811		$	16,353	$	55,752		$	33,899
Amortization of prior year authorized balances	3,610		8,761		11,602		18,385		(8,689		)	3,610		(13,405		)	11,602
Total power cost adjustment expense	$	19,963	$	16,742	$	45,501	$	40,229	$	16,122		$	19,963	$	42,347		$	45,501

The power supply accruals represent the portion of the power supply cost fluctuations accrued under the power cost adjustment mechanisms. When actual power supply costs are lower than the amount forecasted in power cost adjustment rates, which was the case for all periods presented, most of the difference is accrued. When actual power supply costs are higher than the amount forecasted in power cost adjustment rates, most of the difference is deferred. The amortization of the prior year’s balances represents the offset to the amounts being collected or refunded in the current power cost adjustment year that were deferred or accrued in the prior power cost adjustment year (the true-up component of the power cost adjustment mechanism).

Other O&M Expenses: Other O&M expenses ~~increased $5.6~~decreased $5.3 million, or 6 percent, and ~~$4.7~~$2.6 million, or 31 percent, in the second quarter and first ~~three and~~ six months of ~~2018, respectively,~~2019 compared with the same periods of ~~2017. Transmission and distribution asset maintenance expense increased $0.9~~2018. Other O&M expenses related to Idaho Power's hydropower generation decreased $1.1 million and ~~$2.0~~$2.3 million infor the second quarter and first ~~three and~~ six months of ~~2018,~~2019, respectively, compared with the same periods in ~~2017,~~2018, due primarily ~~due~~ to ~~higher~~more costly maintenance ~~service~~projects at hydropower locations in the first half of 2018. For the second quarter of 2019, labor and benefit costs decreased $1.5 million compared with the second quarter of 2018, primarily related to the levels of accruals for variable employee-related costs. As provided by the settlement stipulation approved by the IPUC in 2018 related to ~~recent~~ income tax reform, O&M expenses in the second quarter and first six months of 2018 ~~also~~ included $1.1 million of non-cash amortization expense of regulatory deferrals that would otherwise be a future liability of Idaho customers. Labor and benefit costs increased $3.1 million and $1.7 million in the second quarter and first six months of 2018, respectively, primarily related to the timing of accruals for variable employee-related costs which resulted in earlier recognition of expense compared with the same periods of 2017.

Income Taxes

IDACORP's and Idaho Power's income tax expense increased $1.3 million and $1.5 million, respectively, for the six months ended June 30, ~~2018,~~2019, when compared with the same period in ~~2017, decreased $13.1 million and $12.9 million, respectively,~~2018, primarily due ~~to lower statutory tax rates and a $1.3 million flow-through income tax benefit related~~ to the tax deduction for bond redemption costs incurred in the second quarter of 2018. The lower statutory tax rates were the result of the Tax Cuts and Jobs Act, which reduced the U.S. federal corporate income tax rate from 35 percent to 21 percent, and Idaho House Bill 463, which lowered the Idaho state corporate income tax rate from 7.4 percent to 6.925 percent. The new tax rates were effective on January 1, 2018. For information relating to IDACORP's and Idaho Power's computation of income tax expense and estimated annual effective tax rate, see Note 2 - "Income Taxes" to the condensed consolidated financial statements included in this report.

LIQUIDITY AND CAPITAL RESOURCES

Overview

Idaho Power has been pursuing significant enhancements to its utility infrastructure in an effort to ensure an adequate supply of electricity, to provide service to new customers, and to maintain system reliability. Idaho Power's existing ~~hydroelectric~~hydropower and thermal generation facilities also require continuing upgrades and component replacement. Idaho Power anticipates these substantial capital expenditures to continue, with expected total capital expenditures of approximately $1.5 billion over the five-year period from ~~2018~~2019 (including expenditures incurred to-date in ~~2018)~~2019) through ~~2022.~~2023.

Idaho Power funds its liquidity needs for capital expenditures through cash flows from operations, debt offerings, commercial paper markets, credit facilities, and capital contributions from IDACORP. Idaho Power periodically files for rate adjustments for recovery of operating costs and capital investments to provide the opportunity to align Idaho Power's earned returns with those allowed by regulators. Idaho Power uses operating and capital budgets to control operating costs and capital expenditures. During the first six months of ~~2018,~~2019, Idaho Power continued its efforts to optimize operations, control costs, and generate operating cash inflows to meet operating expenditures, contribute to capital expenditure requirements, and pay dividends to shareholders.

As of July ~~27, 2018,~~26, 2019, IDACORP's and Idaho Power's access to debt, equity, and credit arrangements included:

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their respective $100 million and $300 million revolving credit facilities;

IDACORP's shelf registration statement filed with the U.S. Securities and Exchange Commission (SEC) on May ~~20, 2016,~~17, 2019, which may be used for the issuance of debt securities and common stock;

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Idaho Power's shelf registration statement filed with the SEC on May ~~20, 2016,~~17, 2019, which may be used for the issuance of first mortgage bonds and debt securities; ~~$280~~$500 million remains available for issuance pursuant to state regulatory authority; and

IDACORP's and Idaho Power's ~~issuance of~~ commercial paper, which may be issued up to an amount equal to the available credit capacity under their respective credit facilities.

IDACORP and Idaho Power monitor capital markets with a view toward opportunistic debt and equity transactions, taking into account current and potential future long-term needs. As a result, IDACORP may issue debt securities or common stock, and Idaho Power may issue debt securities or first mortgage bonds, if the companies believe terms available in the capital markets are favorable and that issuances would be financially prudent.

In March 2018, Idaho Power issued $220 million in principal amount of 4.20% first mortgage bonds, Series K, maturing on March 1, 2048. In April 2018, Idaho Power redeemed, prior to maturity, its $130 million in principal amount of 4.50% first mortgage bonds, medium-term notes due March 2020. In accordance with the redemption provisions of the original terms of the notes, the redemption included payment by Idaho Power of a make-whole premium of $4.6 million. Idaho Power used a portion of the net proceeds of the March 2018 sale of first mortgage bonds, medium-term notes to effect the redemption.

Based on planned capital expenditures and other O&M expenses, the companies believe they will be able to meet capital and debt service requirements and fund corporate expenses during at least the next twelve months with a combination of existing cash, operating cash flows generated by Idaho Power's utility business, availability under existing credit facilities, and access to commercial paper and long-term debt markets.

IDACORP and Idaho Power seek to maintain capital structures of approximately 50 percent debt and 50 percent equity, and maintaining this ratio influences IDACORP's and Idaho Power's debt and equity issuance decisions. As of June 30, ~~2018,~~2019, IDACORP's and Idaho Power's capital structures, as calculated for purposes of applicable debt covenants, were as follows:


	IDACORP	Idaho Power	IDACORP	Idaho Power
Debt	44%	46%	43%	45%
Equity	56%	54%	57%	55%

IDACORP and Idaho Power generally maintain their cash and cash equivalents in highly liquid investments, such as U.S. Treasury Bills, money market funds, and bank deposits.

Operating Cash Flows

IDACORP’s and Idaho Power’s operating cash inflows for the six months ended June 30, ~~2018,~~2019, were ~~$196~~$166 million and ~~$191~~$162 million, respectively, ~~an increase of $7 million and~~ a decrease of ~~$10~~$30 million ~~respectively,~~for IDACORP and $29 million for Idaho Power, compared with the same period in ~~2017.~~2018. With the exception of cash flows related to income taxes, IDACORP's operating cash flows are principally derived from the operating cash flow of Idaho Power. Significant items that affected the comparability of the companies' operating cash flows in the first six months of ~~2018~~2019 compared with the same period in ~~2017~~2018 were as follows:

decreased net ~~income increased $16 million, for the reasons described in "Results of Operations" above in this MD&A;~~income;

changes in deferred taxes and in taxes accrued and receivable combined to increase cash flows by $4 million at IDACORP and decrease cash flows by ~~$12 million and increase by~~ $8 million at ~~IDACORP~~Idaho Power;

changes in regulatory assets and liabilities, mostly related to the relative amounts of costs deferred and collected under the Idaho ~~Power, respectively;~~FCA mechanism and demand-side management program, decreased operating cash flows by $14 million;

Idaho Power made ~~$25~~$15 million of benefit plan contributions during the first six months of ~~2018,~~2019, while it made contributions of $4$25 million for the same period in ~~2017; and~~2018;

changes in working capital balances due primarily to timing, including fluctuations in accounts receivable ~~other current assets,~~ and accounts payable, as follows:


◦	timing of collections of accounts receivable balances ~~increased~~decreased operating cash flows by $8$3 million and $4 million for IDACORP and Idaho ~~Power. For IDACORP, the increase was offset by IDACORP's collection in 2017 of $8 million from a legal settlement;~~Power, respectively; and

◦

timing of accounts payable payments ~~increased operating cash flows by $18 million for IDACORP and~~ decreased operating cash flows by ~~$26~~$31 million and $17 million for IDACORP and Idaho Power, ~~(the~~respectively, of which $14 million of the difference ~~relates to a $44 million payable from~~between IDACORP and Idaho Power related to ~~IDACORP relating to~~intercompany estimated income tax ~~payments).~~payments.

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Investing Cash Flows

Investing activities consist primarily of capital expenditures related to new construction and improvements to Idaho Power’s generation, transmission, and distribution facilities. IDACORP’s and Idaho Power’s net investing cash outflows for the six months ended June 30, ~~2018,~~2019, were ~~$109 million.~~$126 million and $123 million, respectively. Investing cash outflows for ~~2018~~2019 and ~~2017~~2018 were primarily for construction of utility infrastructure needed to address Idaho Power’s aging plant and equipment, customer growth, and environmental and regulatory compliance requirements. ~~During the six months ended June 30, 2018, Idaho Power received $20 million in payments from transmission project co-participants pursuant to the terms~~

Table of ~~the joint funding arrangements for their share of costs.~~Contents

Financing Cash Flows

Financing activities provide supplemental cash for both day-to-day operations and capital requirements, as needed. Idaho Power funds liquidity needs for capital investment, working capital, managing commodity price risk, and other financial commitments through cash flows from operations, debt offerings, commercial paper markets, credit facilities, and capital contributions from IDACORP. IDACORP funds its cash requirements, such as payment of taxes, capital contributions to Idaho Power, and non-utility expenses allocated to IDACORP, through cash flows from operations, commercial paper markets, sales of common stock, and credit facilities.

IDACORP's and Idaho Power's net financing cash ~~inflows~~outflows for the six months ended June 30, ~~2018~~2019, were ~~$19~~$68 million and ~~$23~~$64 million, respectively. In March 2018, Idaho Power issued $220 million in first mortgage bonds. In April 2018, Idaho Power redeemed, prior to maturity, $130 million in principal amount of 4.50% first mortgage bonds, medium-term notes due March 2020. In accordance with the redemption provisions of the original terms of the notes, the redemption included payment by Idaho Power of a make-whole premium of $4.6 million. Idaho Power also expects to receive an incremental net benefit to net income as a result of the lower interest rate of the notes issued in March 2018 compared to the interest rate associated with the redeemed notes. Financing cash flows also included the payment of $60 million of dividends on common stock during the first six months of ~~2018.~~2019, IDACORP and Idaho Power paid cash dividends of $64 million.

Financing Programs and Available Liquidity

IDACORP Equity Programs: In recent years, IDACORP has entered into sales agency agreements under which ~~IDACORP~~it could offer and sell shares of its common stock from time to time through a third-party agent. The most recent sales agency agreement terminated in May 2016. ~~In May 2016, IDACORP filed a shelf registration statement with the SEC, which became effective upon filing, for the potential offer and sale of an unspecified amount of shares of common stock.~~ IDACORP has no current plans to issue equity securities other than under its equity compensation plans during ~~2018,~~2019, and as of the date of this report, IDACORP has not pursued the execution of a new sales agency agreement.

Idaho Power First Mortgage Bonds: Idaho Power's issuance of long-term indebtedness is subject to the approval of the IPUC, OPUC, and Wyoming Public Service Commission (WPSC). In April and May ~~2016,~~2019, Idaho Power received orders from the IPUC, OPUC, and WPSC authorizing the company to issue and sell from time to time of up to $500 million in aggregate principal amount of debt securities and first mortgage bonds, subject to conditions specified in the orders. Authority from the IPUC is effective through May 31, ~~2019,~~2022, subject to extension upon request to the IPUC. The OPUC’s and WPSC’s orders do not impose a time limitation for issuances, but the OPUC order does impose a number of other conditions, including a requirement that the interest rates for the debt securities or first mortgage bonds fall within either (a) designated spreads over comparable U.S. Treasury rates or (b) a maximum interest rate limit of seven percent.

In ~~September 2016,~~May 2019, Idaho Power ~~entered into~~filed a ~~selling agency agreement with seven banks named in the agreement in connection~~shelf registration statement with the ~~potential issuance~~SEC, which became effective upon filing, for the offer and sale ~~from time to time~~ of ~~up to $500 million in aggregate~~an unspecified principal amount of its first mortgage bonds. The issuance of first mortgage bonds ~~secured medium term notes, Series K (Series K Notes), under~~requires that Idaho ~~Power’s~~Power meet interest coverage and security provisions set forth in Idaho Power's Indenture of Mortgage and Deed of Trust, dated as of October 1, 1937, as amended and supplemented from time to time (Indenture). At the same time, Idaho Power entered into the Forty-eighth Supplemental Indenture, dated as of September 1, 2016, to the Indenture (Forty-eighth Supplemental Indenture). The Forty-eighth Supplemental Indenture provides for, among other items, (a) the issuance of up to $500 million in aggregate principal amount of Series K Notes pursuant to the Indenture and (b) the increase of the maximum amount of obligations to be secured by the Indenture to $2.5 billion (which maximum amount may be further increased or decreased by Idaho Power without the consent of the holders of first mortgage bonds). As of the date of this report, Idaho Power has $280 million available for the issuanceFuture issuances of first mortgage bonds ~~including Series K Notes, or debt securities under~~are subject to satisfaction of covenants and security provisions set forth in the ~~selling agency agreement.~~Indenture, market conditions, regulatory authorizations, and covenants contained in other financing agreements.

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The Indenture limits the amount of first mortgage bonds at any one time outstanding to $2.5 billion, and as a result, the maximum amount of additional first mortgage bonds Idaho Power could issue as of June 30, ~~2018~~2019 was limited to approximately $669 million. Separately, the Indenture also limits the amount of additional first mortgage bonds that Idaho Power may issue to the sum of (a) the principal amount of retired first mortgage bonds and (b) 60 percent of total unfunded property additions, as defined in the Indenture. As of June 30, ~~2018,~~2019, Idaho Power could issue approximately ~~$1.8~~$1.9 billion of additional first mortgage bonds based on retired first mortgage bonds and total unfunded property additions.

IDACORP and Idaho Power Credit Facilities: In November 2015, IDACORP and Idaho Power entered into Credit Agreements for $100 million and $300 million credit facilities, respectively, replacing prior credit agreements. Each of the credit facilities may be used for general corporate purposes and commercial paper back-up. IDACORP's facility permits borrowings under a revolving line of credit of up to $100 million at any one time outstanding, including swingline loans not to exceed $10 million at any one time and letters of credit not to exceed $50 million at any one time. IDACORP's facility may be increased, subject to specified conditions, to $150 million. Idaho Power's facility permits borrowings through the issuance of loans and standby letters of credit of up to $300 million at any one time outstanding, including swingline loans not to exceed $30 million at any one time and letters of credit not to exceed $100 million at any one time outstanding. Idaho Power's facility may be increased, subject to specified conditions, to $450 million. The credit facilities currently provide for a maturity date of November 4, 2022. Other terms and conditions of the credit facilities are described in ~~IDACORP's and Idaho Power's~~the 2018 Annual Report, ~~on Form 10-K for the year ended December 31, 2017,~~ in Part II, Item 7 - "MD&A - Liquidity and Capital Resources."

Each facility contains a covenant requiring each company to maintain a leverage ratio of consolidated indebtedness to consolidated total capitalization equal to or less than 65 percent as of the end of each fiscal quarter. In determining the leverage ratio, "consolidated indebtedness" broadly includes all indebtedness of the respective borrower and its subsidiaries, including, in some instances, indebtedness evidenced by certain hybrid securities (as defined in the credit agreement). "Consolidated total capitalization" is calculated as the sum of all consolidated indebtedness, consolidated stockholders' equity of the borrower and

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its subsidiaries, and the aggregate value of outstanding hybrid securities. At June 30, ~~2018,~~2019, the leverage ratios for IDACORP and Idaho Power were 4443 percent and 4645 percent, respectively. IDACORP's and Idaho Power's ability to utilize the credit facilities is conditioned upon their continued compliance with the leverage ratio covenants included in the credit facilities. There are additional covenants, subject to exceptions, that prohibit certain mergers, acquisitions, and investments, restrict the creation of certain liens, and prohibit entering into any agreements restricting dividend payments from any material subsidiary.

At June 30, ~~2018,~~2019, IDACORP and Idaho Power believed they were in compliance with all facility covenants. Further, IDACORP and Idaho Power do not believe they will be in violation or breach of their respective debt covenants during ~~2018.~~2019.

Without additional approval from the IPUC, the OPUC, and the WPSC, the aggregate amount of short-term borrowings by Idaho Power at any one time outstanding may not exceed $450 million. Idaho Power has obtained approval of the state public utility commissions of Idaho, Oregon, and Wyoming for the issuance of short-term borrowings through November 2022.

IDACORP and Idaho Power Commercial Paper: IDACORP and Idaho Power have commercial paper programs under which they issue unsecured commercial paper notes up to a maximum aggregate amount outstanding at any time not to exceed the available capacity under their respective credit facilities, described above. IDACORP's and Idaho Power's credit facilities are available to the companies to support borrowings under their commercial paper programs. The commercial paper issuances are used to provide an additional financing source for the companies' short-term liquidity needs. The maturities of the commercial paper issuances will vary but may not exceed 270 days from the date of issue. Individual instruments carry a fixed rate during their respective terms, although the interest rates are reflective of current market conditions, subjecting the companies to fluctuations in interest rates.

Available Short-Term Borrowing Liquidity

The table below outlines available short-term borrowing liquidity as of the dates specified (in thousands).


	June 30, 2018					December 31, 2017					June 30, 2019					December 31, 2018
	IDACORP⁽²⁾		Idaho Power			IDACORP⁽²⁾		Idaho Power			IDACORP⁽²⁾		Idaho Power			IDACORP⁽²⁾		Idaho Power
Revolving credit facility	$	100,000	$	300,000		$	100,000	$	300,000		$	100,000	$	300,000		$	100,000	$	300,000
Commercial paper outstanding	—		—			—		—			—		—			—		—
Identified for other use⁽¹⁾	—		(24,245		)	—		(24,245		)	—		(24,245		)	—		(24,245		)
Net balance available	$	100,000	$	275,755		$	100,000	$	275,755		$	100,000	$	275,755		$	100,000	$	275,755

⁽¹⁾ Port of Morrow and American Falls bonds that Idaho Power could be required to purchase prior to maturity under the optional or mandatory purchase provisions of the bonds, if the remarketing agent for the bonds is unable to sell the bonds to third parties.

⁽²⁾ Holding company only.

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At July ~~27, 2018,~~26, 2019, IDACORP hadno loans outstanding under its credit facilities and had no commercial paper outstanding. Idaho Power hadno loans outstanding under its credit facilities and no commercial paper outstanding. During the three and six months ended June 30, ~~2018,~~2019, IDACORP and Idaho Power borrowed no short-term commercial ~~paper was borrowed at IDACORP or Idaho Power.~~paper.

Impact of Credit Ratings on Liquidity and Collateral Obligations

IDACORP’s and Idaho Power’s access to capital markets, including the commercial paper market, and their respective financing costs in those markets, depend in part on their respective credit ratings. There have been no changes to IDACORP's or Idaho Power's ratings or ratings outlook by Standard & Poor’s Ratings Services or Moody’s Investors Service from those included in the ~~companies'~~2018 Annual ~~Report on Form 10-K for the year ended December 31, 2017.~~Report. However, any rating can be revised upward or downward or withdrawn at any time by a rating agency if it decides that the circumstances warrant the change.

Idaho Power maintains margin agreements relating to its wholesale commodity contracts that allow performance assurance collateral to be requested of and/or posted with certain counterparties. As of June 30, ~~2018,~~2019, Idaho Power had posted ~~$0.8~~$1.8 million of performance assurance collateral related to these contracts. Should Idaho Power experience a reduction in its credit rating on its unsecured debt to below investment grade, Idaho Power could be subject to requests by its wholesale counterparties to post additional performance assurance collateral, and counterparties to derivative instruments and other forward contracts could request immediate payment or demand immediate ongoing full daily collateralization on derivative instruments and contracts in net liability positions. Based upon Idaho Power’s current energy and fuel portfolio and market conditions as of June 30, ~~2018,~~2019, the amount of additional collateral that could be requested upon a downgrade to below investment grade is approximately ~~$4.2~~$5.4 million. To minimize capital requirements, Idaho Power actively monitors its portfolio exposure and the potential exposure to additional requests for performance assurance collateral through sensitivity analysis.

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Capital Requirements

Idaho Power's construction expenditures, excluding AFUDC,were ~~$129~~$125 million during the six months ended June 30, ~~2018.~~2019. The cash expenditure amount excludes net costs of removing assets from service. The table below presents Idaho Power's ~~expected cash requirements~~estimated accrual-basis expenditures for construction ~~excluding AFUDC,~~ for ~~2018~~2019 (including amounts incurred to-date) through ~~2022~~2023 (in ~~millions)~~millions of dollars). The amounts in the table exclude AFUDC but include net costs of removing assets from service that Idaho Power expects would be eligible to include in rate base in future rate case proceedings. However, given the uncertainty associated with the timing of infrastructure projects and associated expenditures, actual expenditures and their timing could deviate substantially from those set forth in the table.

2018 2019 2020-2022
Expected capital expenditures (excluding AFUDC) $280-290 $285-300 $850-900

Major Infrastructure Projects: Idaho Power is engaged in the development of a number of significant projects and has entered into arrangements with third parties concerning joint infrastructure development. The discussion below provides a summary of developments in certain of those projects since the discussion of these matters included in Part II, Item 7 - "MD&A - Capital Requirements" in ~~IDACORP's and Idaho Power's~~the 2018 Annual ~~Report on Form 10-K for the year ended December 31, 2017.~~Report. The discussion below should be read in conjunction with that report.

Boardman-to-Hemingway Transmission Line:The Boardman-to-Hemingway line, a proposed 300-mile, 500-kV transmission project between a station near Boardman, Oregon, and the Hemingway station near Boise, Idaho, would provide transmission service to meet future resource needs. In January 2012, Idaho Power entered into a joint funding agreement with PacifiCorp and the Bonneville Power Administration to pursue permitting of the project. The joint funding agreement provides that Idaho Power's interest in the permitting phase of the project would be approximately 21 percent, and that during future negotiations relating to construction of the transmission line, Idaho Power would seek to retain that percentage interest in the completed project. Total cost estimates for the project are between $1.0 billion and $1.2 billion, including Idaho Power's AFUDC. This cost estimate is preliminary and excludes the impacts of inflation and price changes of materials and labor resources that may occur following the date of the estimate.

Approximately ~~$97~~$103 million, including AFUDC, has been expended on the Boardman-to-Hemingway project through June 30, ~~2018.~~2019. Pursuant to the terms of the joint funding arrangements, Idaho Power has received ~~approximately $69~~$71 million as of June 30, ~~2018, including $20 million received in 2018, due~~2019, from project co-participants for their share of costs. As of the date of this report, no material co-participant reimbursements are outstanding. Joint permitting participants are obligated to reimburse Idaho Power for their share of any future project permitting expenditures incurred by Idaho Power.

The permitting phase of the Boardman-to-Hemingway project is subject to federal review and approval by the U.S. Bureau of Land Management (BLM), the U.S. Forest Service, the Department of the Navy, and certain other federal agencies. The BLM

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issued its record of decision for the project in November ~~2017.~~2017, approving a right-of-way grant for the project to cross approximately 86 miles of BLM-administered land. The U.S. Forest Service ~~released~~issued its ~~draft~~ record of decision in ~~June~~November 2018 ~~for~~authorizing the ~~6.8~~project to cross approximately 7 miles ~~across~~of National Forest ~~lands consistent with the preferred route in the BLM's final environmental impact statement.~~lands. Idaho Power also expects the Department of the Navy to issue its decision on whether to approve the project to cross approximately 7 miles of Department of the Navy lands in ~~2018.~~2019. In the separate Oregon state permitting process, in ~~June 2017, Idaho Power submitted its amended preliminary application for site certificate and expects~~May 2019, the Oregon Department of Energy issued a Draft Proposed Order that recommends approval of the project to the state's Energy Facility Siting Council. The Oregon Department of Energy is expected to issue a ~~draft proposed order on the application~~Proposed Order in ~~2018.~~late 2019 or early 2020. Given the status of ongoing permitting activities and the construction period, Idaho Power expects the in-service date for the transmission line to be in ~~2025~~2026 or beyond.

Gateway West Transmission Line: Idaho Power and PacifiCorp are pursuing the joint development of the Gateway West project, a 500-kV transmission project between a station located near Douglas, Wyoming and the Hemingway station located near Boise, Idaho. In January 2012, Idaho Power and PacifiCorp ~~have~~entered a joint funding agreement for permitting of the project. Idaho Power has expended approximately ~~$37~~$40 million, including Idaho Power's AFUDC, for its share of the permitting phase of the project through June 30, ~~2018.~~2019. As of the date of this report, Idaho Power estimates the total cost for its share of the project (including both permitting and construction) to be between $250 million and $450 million, including AFUDC.

The permitting phase of the Gateway West project is subject to review and approval of the BLM. The BLM released its record of decision in November 2013 for eight of the ten transmission line segments. In May 2017, a federal bill was signed into law that issued a right-of-way for certain portions of the remaining Gateway West segments. In April 2018, the BLM published its record of decision for the outstanding portions of the remaining segments. Idaho Power and PacifiCorp continue to coordinate the timing of next steps to best meet customer and system needs.

Defined Benefit Pension Plan Contributions

Idaho Power has no minimum contribution requirement to its defined benefit pension plan in ~~2018;~~2019; however, after evaluating market conditions and expected 2019 cash flows, Idaho Power contributed ~~$20~~$10 million to the plan during the first six months of ~~2018. Depending on market conditions and cash flow considerations during the remainder~~

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2019. Idaho Power ~~may~~expects it will contribute up to ~~an additional $20~~a total of $40 million to the pension plan during ~~2018.~~2019. Idaho Power's contributions are made in a continued effort to balance the regulatory collection of these expenditures with the amount and timing of contributions and to mitigate the cost of being in an underfunded position. The primary impact of pension contributions is on the timing of cash flows, as the timing of cost recovery lags behind contributions.

Contractual Obligations

During the six months ended June 30, ~~2018,~~2019, IDACORP's and Idaho Power's contractual obligations, outside the ordinary course of business, did not change materially from the amounts disclosed in ~~their~~the 2018 Annual Report, ~~on Form 10-K for the year ended December 31, 2017,~~ except that Idaho Power entered into four new replacement contracts for expiring power purchase agreements with ~~solar and biomass~~hydropower PURPA-qualifying facilities ~~that~~and one new agreement with a solar PURPA-qualifying facility, which increased Idaho Power's contractual ~~payment~~purchase obligations by approximately ~~$51~~$24 million over the 20-year terms of the contracts. Also, in March 2019, Idaho Power signed a 20-year power purchase agreement, subject to final regulatory approval, to purchase the output from a 120 MW solar facility proposed to be constructed by a third party. The agreement would increase contractual obligations by $136 million over the 20-year term.

Off-Balance Sheet Arrangements

IDACORP's and Idaho Power's off-balance sheet arrangements have not changed materially from those reported in MD&A in ~~IDACORP's and Idaho Power's~~the 2018 Annual ~~Report on Form 10-K for the year ended December 31, 2017.~~Report.

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REGULATORY MATTERS

Introduction

Idaho Power's development of regulatory filings takes into consideration short-term and long-term needs for rate relief and involves several factors that can affect the timing of ~~rate~~these filings. These factors include, among others, the in-service dates of major capital investments, the timing and magnitude of changes in major revenue and expense items, and customer growth rates. Idaho Power's most recent general rate cases in Idaho and Oregon were filed during 2011, and Idaho Power filed a large single-issue rate ~~case~~cases for the Langley Gulch power plant in Idaho and Oregon in 2012. These significant rate cases resulted in the resetting of base rates in both Idaho and Oregon during 2012. Idaho Power also reset its base-rate power supply expenses in the Idaho jurisdiction for purposes of updating the collection of costs through retail rates in 2014 but without a resulting net increase in rates. The IPUC and OPUC have also approved smaller base rate changes in single issue cases subsequent to 2014. Between general rate cases, Idaho Power relies upon customer growth, a fixed cost adjustment mechanism, power cost adjustment mechanisms, tariff riders, and other mechanisms to mitigate the impact of regulatory lag, which refers to the period of time between making an investment or incurring an expense and recovering that investment or expense and earning a return. Management's regulatory focus in recent years has been largely on regulatory settlement stipulations and the design of rate mechanisms. Idaho Power continues to assess the need and timing of filing a general rate case in its two retail jurisdictions, based on its consideration of factors such as those described above, but does not anticipate filing a general rate case in the next twelve months.

The outcomes of significant proceedings are described in part in this report and further in ~~IDACORP's and Idaho Power's~~the 2018 Annual ~~Report on Form 10-K for the year ended December 31, 2017.~~Report. In addition to the discussion below, which includes notable regulatory developments since the discussion of these matters in ~~IDACORP's and Idaho Power's~~the 2018 Annual Report, ~~on Form 10-K for the year ended December 31, 2017,~~ refer to Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report for additional information relating to Idaho Power's regulatory matters and recent regulatory filings and orders.

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Notable Rate Changes During ~~2018~~2019

During ~~2018,~~2019, Idaho Power received orders authorizing the rate changes summarized in the table below.



Description	Status	Estimated Rate Impact⁽¹⁾	Notes
Power Cost Adjustment Mechanism - Idaho	New PCA rate became effective June 1, ~~2018~~2019	$~~22.6~~50.1 million PCA decrease for the period from June 1, ~~2018~~2019 to May 31, ~~2019~~2020	The potential revenue impact of rate increases and decreases associated with the Idaho PCA mechanism is largely offset by associated increases and decreases in actual power supply costs and amortization of deferred power supply costs. The decrease includes a $5.0 million credit to customers for sharing of 2018 earnings under the IPUC order approving the extension, with modifications, of the terms of the December 2011 Idaho settlement stipulation for the period from 2015 through 2019 (October 2014 Idaho Earnings Support and Sharing Settlement Stipulation) and a $2.7 million credit for income tax reform benefits related to Idaho Power's OATT rate under a May 2018 Idaho tax reform settlement stipulation as described below in this MD&A.
Fixed Cost Adjustment Mechanism - Idaho	New FCA rate became effective June 1, ~~2018~~2019	$~~19.4~~19.2 million FCA ~~decrease~~increase for the period from June 1, ~~2018~~2019 to May 31, ~~2019~~2020	The FCA is designed to remove a portion of Idaho Power’s financial disincentive to invest in energy efficiency programs by partially separating (or decoupling) the recovery of fixed costs from the volumetric kilowatt-hour charge and instead linking it to a set amount per customer.
~~Tax Cuts and Jobs Act Settlement Stipulation~~Valmy Plant Agreement - Idaho	New base rate became effective June 1, ~~2018~~2019	~~On an~~$1.2 million annual ~~basis, $18.7 million reduction of customer base rates, commencing on June 1, 2018~~increase	~~See "Income Tax Reform - Impact and Regulatory Treatment" below for more information.~~
~~Tax Cuts and Jobs Act Settlement Stipulation -~~In February 2019, Idaho	~~New PCA rate became effective June 1, 2018~~	~~One-time~~ ~~benefit~~ Power reached an agreement with NV Energy that facilitates the planned end of ~~a $7.8 million decrease to be provided through PCA mechanism rates for the period from June 1, 2018 through May 31, 2019~~	~~For the income tax benefits accrued from January 1, 2018 to May 31, 2018, and the income tax benefits related to~~ Idaho Power's ~~OATT. See "Income Tax Reform - Impact~~participation in coal-fired operations at units 1 and ~~Regulatory Treatment" below for more information.~~2 of its jointly-owned North Valmy coal-fired power plant (Valmy Plant) in 2019 and 2025, respectively. In May 2019, the IPUC issued an order approving the Valmy Plant agreement and allowing Idaho Power to recover through customer rates the $1.2 million incremental annual levelized revenue requirement associated with required Valmy Plant investments and other exit costs.

⁽¹⁾ The annual amount collected in rates is typically not recovered on a straight-line basis (i.e., 1/12th per month), and is instead recovered in proportion to retail sales volumes.

~~Customer-Owned Generation Filing~~

In July 2017, Idaho Power filed an application with the IPUC related to customers who install their own on-site generation, seeking the creation of two new classes of customers, with no request to change pricing or compensation. In May 2018, the IPUC issued an order authorizing the creation of the new customer classes. In that order, the IPUC also stated its intent to open

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an Idaho Power-specific docket to comprehensively study on-site generation and ordered Idaho Power to file a study with the IPUC exploring fixed-cost recovery prior to its next general rate case. In June 2018, the IPUC issued an order requiring further investigation to resolve eligibility issues for the new customer classes.

Idaho Earnings Support and Sharing from Idaho Settlement Stipulation

In October 2014, the IPUC issued an order ~~(October~~approving the October 2014 Idaho Earnings Support and Sharing Settlement ~~Stipulation) approving an extension,~~Stipulation extending, with modifications, of the terms of a December 2011 Idaho settlement stipulation for the period from 2015 through ~~2019, or until the terms are otherwise modified or terminated by order of the IPUC or the full $45 million of additional ADITC amortization contemplated by the~~2019. A May 2018 Idaho settlement stipulation ~~has been amortized. The more specific terms and conditions of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation are described in Note 3 - "Regulatory Matters"~~related to the condensed consolidated financial statements included in this report. IDACORP and Idaho Power believe that the terms allowing additional amortization of ADITC in the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation provide the companies with a greater degree of earnings stability than would be possible without the terms of the stipulation in effect.

Under the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation, during the second quarter of 2018, Idaho Power reversed the $0.5 million of additional ADITC amortization recorded during the first quarter of 2018, based on Idaho Power's then-current estimate of return on year-end equity in the Idaho jurisdiction (Idaho ROE) for the full-year 2018. During the second quarter of 2017, Idaho Power reversed $1.9 million of additional ADITC amortization recorded during the first quarter of 2017, as actual financial results exceeded Idaho Power's early estimates.

~~Income Tax Reform - Impact and Regulatory Treatment~~

In December 2017, the Tax Cuts and Jobs Act was signed into law, which, among other things, lowered the corporate federal income tax rate from 35 percent to 21 percent and modified or eliminated certain federal income tax deductions for corporations. In March 2018, Idaho House Bill 463 was signed into law reducing the Idaho state corporate income tax rate from 7.4 percent to 6.925 percent. In January 2018, the IPUC issued an order requiring utilities within its jurisdiction, including Idaho Power, to (1) record a regulatory liability for the estimated Idaho-jurisdictional share of financial benefits after January 1, 2018, from the changes in federal income tax law under the Tax Cuts and Jobs Act, and (2) file a report with the IPUC by March 30, 2018, identifying and quantifying the financial impact of the income tax changes on the utility, along with proposed tariff schedule changes that would adjust the utility's rates to reflect the utility's modified federal tax obligations under the Tax Cuts and Jobs Act. The IPUC order required Idaho Power to estimate the income tax reform ~~changes by comparing actual 2017 federal income tax components with what those federal income tax components would have been if the Tax Cuts and Jobs Act had been effective for the full year of 2017.~~

In March 2018, Idaho Power made a filing with the IPUC providing the results of its pro forma analysis indicating pro forma annual income tax reform expense reductions, composed of a current income tax expense reduction and a deferred income tax expense reduction. In May 2018, the IPUC ~~issued an order approving~~ ~~a settlement stipulation~~ (May 2018 Idaho Tax Reform Settlement Stipulation) related to income tax reform. Beginning June 1, 2018, the settlement stipulation provides an annual (a) $18.7 million reduction to Idaho customer base rates and (b) $7.4 million amortization of existing regulatory deferrals for specified items or future amortization of other existing or future unspecified regulatory deferrals that would otherwise be a future liability recoverable from Idaho customers. Additionally, a one-time ~~benefit~~ ~~of a $7.8 million rate reduction is being provided to Idaho customers through PCA mech~~anism rates for the period from June 1, 2018 through May 31, 2019, for the income tax reform benefits accrued from January 1, 2018 to May 31, 2018, and the income tax reform benefits related to Idaho Power's OATT. The amount provided via the PCA mechanism will decrease to $2.7 million on June 1, 2019, for income tax reform benefits related to Idaho Power's OATT and will cease on June 1, 2020, to reflect the impact of a full year of reduced OATT third-party transmission revenues.

~~The May 2018 Idaho Tax Reform Settlement Stipulation~~ provides for the extension of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation ~~described above~~ beyond the initial termination date of December 31, 2019, with modified terms related to the ADITC and revenue sharing mechanism to become effective beginning January 1, 2020. ~~Neither~~The more specific terms and conditions of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation ~~nor~~and the May 2018 Idaho Tax Reform Settlement Stipulation ~~impose a moratorium on Idaho Power filing a general rate case or other form of rate proceeding~~are described in ~~Idaho during their respective terms.~~

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OPUC by December 31, 2019, to begin tracking tax reform benefits beginning January 1, 2020, at which time Idaho Power, the OPUC staff, and other interested parties will discuss the methodology to quantify potential future tax reform benefits. The settlement stipulation also deemed prudent Idaho Power's decision to pursue the end of its participation in coal-fired operations of Unit 1 at Idaho Power's jointly-owned North Valmy coal-fired plant and approved Idaho Power's request to recover $2.5 million of annual incremental accelerated depreciation relating to Unit 1, beginning June 1, 2018 and ending December 31, 2019.

~~For more information on the settlement stipulations and their impacts on results, see~~ Note 3 - "Regulatory Matters" to the ~~condensed~~ consolidated financial statements included in ~~this report.~~the 2018 Annual Report. IDACORP and Idaho Power believe that the terms allowing additional amortization of ADITC in the settlement stipulations provide the companies with a greater degree of earnings stability than would be possible without the terms of the stipulations in effect.

Based on its estimate of full-year 2019 Idaho ROE, in both the second quarter and first six months of 2019, Idaho Power recorded no additional ADITC amortization or provision against current revenues for sharing of earnings with customers for 2019 under the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation. During the second quarter of 2018, Idaho Power reversed the $0.5 million of additional ADITC amortization recorded during the first quarter of 2018, as actual financial results exceeded Idaho Power's early estimates.

Change in Deferred Net Power Supply Costs and the Power Cost Adjustment Mechanisms

Deferred (accrued) power supply costs represent certain differences between Idaho Power's actual net power supply costs and the costs included in its retail rates, the latter being based on annual forecasts of power supply costs. Deferred (accrued) power supply costs are recorded on the balance sheets for future recovery or refund through customer rates.

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The table that follows summarizes the change in deferred (accrued) net power supply costs during the six months ended June 30, ~~2018~~2019 (in ~~thousands)~~millions).

Idaho Oregon Total
Deferred net power supply costs at December 31, 2017 $ (2,201 ) $ (105 ) $ (2,306 )
Current period net power supply costs accrued (33,227 ) —
(33,227 )
Prior amounts recovered through rates (6,402 ) —
(6,402 )
Tax reform revenue accrual transferred to Idaho PCA mechanism (4,244 ) —
(4,244 )
SO₂ allowance and renewable energy certificate sales
(2,263 ) (93 ) (2,356 )
Interest and other (82 ) 4
(78 )
Deferred net power supply costs at June 30, 2018 $ (48,419 ) $ (194 ) $ (48,613 )



	Idaho			Oregon			Total
Deferred (accrued) net power supply costs at December 31, 2018	$	(42.1	)	$	(0.2	)	$	(42.3	)
Current period net power supply costs accrued	(55.5		)	(0.3		)	(55.8		)
Revenue sharing	(5.2		)	—			(5.2		)
Western EIM cost recovery to be collected through Idaho PCA	1.6			—			1.6
Prior amounts refunded through rates	15.1			0.1			15.2
SO₂ allowance and renewable energy certificate sales	(3.9		)	(0.2		)	(4.1		)
Interest and other	(0.6		)	—			(0.6		)
Deferred (accrued) net power supply costs at June 30, 2019	$	(90.6	)	$	(0.6	)	$	(91.2	)

Idaho Power's power cost adjustment mechanisms in its Idaho and Oregon jurisdictions address the volatility of power supply costs and provide for annual adjustments to the rates charged to retail customers. The power cost adjustment mechanisms and associated financial impacts are described in "Results of Operations" in this MD&A and in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report. With the exception of power supply expenses incurred under PURPA and certain demand response program costs that are passed through to customers substantially in full, the Idaho PCA mechanism allows Idaho Power to pass through to customers 95 percent of the differences in actual net power supply expenses as compared with base net power supply expenses, whether positive or negative. Thus, the primary financial statement impact of power supply cost deferrals or accruals is that the timing of when cash is paid out for power supply expenses differs from when those costs are recovered from customers, impacting operating cash flows from year to year.

Open Access Transmission Tariff Draft Posting

Idaho Power uses a formula rate for transmission service provided under its OATT, which allows transmission rates to be updated annually based primarily on financial and operational data Idaho Power files with the FERC. In ~~June 2018,~~May 2019, Idaho Power publicly posted its ~~2018~~2019 draft transmission rate, reflecting a transmission rate of ~~$31.26~~$27.32 per "kW-year," to be effective for the period from October 1, ~~2018~~2019 to September 30, ~~2019.~~2020. A "kW-year" is a unit of electrical capacity equivalent to 1 kilowatt of power used for 8,760 hours. Idaho Power's draft rate was based on a net annual transmission revenue requirement of ~~$123.1~~$107.0 million. The existing OATT rate in effect from October 1, ~~2017~~2018 to September 30, ~~2018,~~2019, is ~~$34.90~~$31.26 per kW-year based on a net annual transmission revenue requirement of ~~$130.4~~$123.1 million. The decrease in the OATT rate is largely attributable to ~~an increase in~~federal tax reform and increased short-term firm and non-firm transmission revenues in ~~2017,~~2018, which ~~serves~~serve as an offset to the transmission revenue requirement.

~~Western Energy Imbalance Market Costs~~2019 Integrated Resource Plan

Idaho Power filed its most recent IRP with the IPUC and OPUC in June 2019. The 2019 IRP assumes a forecasted annual growth in average energy demand of 1.0 percent and a forecasted annual growth in peak-hour demand of 1.2 percent over the 20-year period. The 2019 IRP identified a preferred resource portfolio and action plan, which includes the completion of the Boardman-to-Hemingway transmission line by 2026, the end to Idaho Power's participation in coal-fired operations at the ~~Western EIM commenced on April 4, 2018.~~ Valmy Plant units 1 and 2 in 2019 and 2025, respectively, and the early retirement of two Jim Bridger units in 2022 and 2026, respectively, and the acquisition of two solar resources in 2022 and 2023, respectively. However, as noted in the 2019 IRP, there is considerable uncertainty surrounding the resource sufficiency estimates and project completion dates, including uncertainty around the timing and extent of third party development of renewable resources, fuel commodity prices, the actual completion date of the Boardman-to-Hemingway transmission project, and the economics and logistics of plant retirements. These uncertainties, as well as others, could result in changes to the desirability of the preferred portfolio and adjustments to the timing and nature of anticipated and actual actions.

The ~~Western EIM is intended~~2019 IRP was Idaho Power's first IRP to ~~reduce~~use a long-term capacity expansion modeling system to identify economic resource portfolios under a range of future system conditions. This model simulates the ~~power supply costs~~entire western interconnection system to ~~serve customers through more efficient dispatch within~~find an optimized western-interconnection resource portfolio. Subsequent to filing the ~~hour of a larger and more diverse pool of resources, to integrate intermittent power from renewable generation sources more effectively, and to enhance reliability. In August 2016,~~2019 IRP, Idaho Power identified that the optimization method used by the modeling software did not also model an optimized Idaho Power-specific system. Idaho Power is conducting further analysis and simulations on resource optimization based on an Idaho Power-specific system and expects to supplement the currently filed ~~an application~~2019 IRP with additional information and modeling results by the ~~IPUC requesting specified regulatory accounting treatment~~end of October 2019. If Idaho Power identifies significant differences in the results associated with ~~its participation~~additional modeling, it could modify the preferred resource portfolio identified in the ~~Western EIM. In January 2017,~~2019 IRP, which could alter the ~~IPUC issued an order authorizing deferral accounting treatment for costs associated with joining the Western EIM. Idaho Power deferred $1.0 million~~anticipated timing of ~~incremental other O&M costs incurred through~~plant additions and retirements.

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April 1, 2018. In November 2017, Idaho Power filed an application with the IPUC requesting approval to establish an interim method of recovery for Western EIM-related costs. In July 2018, the IPUC issued an order approving a settlement stipulation that provides for a recovery mechanism administered through Idaho Power's PCA mechanism. For more information on the order and its impact on financial results, see Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report.

Renewable and Other Energy Contracts

Idaho Power has contracts for the purchase of electricity produced by third-party owned generation facilities, most of which produce energy with the use of renewable generation sources such as wind, solar, biomass, small ~~hydroelectric~~hydropower and geothermal. The majority of these contracts are entered into as mandatory purchases under PURPA. As of June 30, ~~2018,~~2019, Idaho Power had contracts to purchase energy from ~~128~~127 on-line PURPA projects. An additional three contracts are with on-line non-PURPA projects, including the Elkhorn Valley wind project with a 101-MW nameplate capacity.

The following table sets forth, as of June 30, ~~2018,~~2019, the resource type and nameplate capacity of Idaho Power's signed agreements for power purchases from PURPA and non-PURPA generating facilities. These agreements have original contract terms ranging from one to 35 years.


Resource Type	Total On-line mega-watts (MW)	Under Contract but not yet On-line (MW)	Total Projects under Contract (MW)	On-line megawatts (MW)	Under Contract but not yet On-line (MW)	Total Projects under Contract (MW)
PURPA:
Wind	627	—	627	627	—	627
Solar	290	27	317	290	30	320
Hydroelectric	147	2	149
Hydropower				147	2	149
Other	56	—	56	56	—	56
Total	1,120	29	1,149	1,120	32	1,152
Non-PURPA:
Wind	101	—	101	101	—	101
Geothermal	35	—	35	35	—	35
Solar				—	120	120
Total	136	—	136	136	120	256

~~Of the six~~The projects not yet on-line include one ~~hydroelectric~~hydropower PURPA project and five solar PURPA projects that are scheduled to be on-line in ~~2019.~~2019 and one solar PURPA project scheduled to be online in 2022. The non-PURPA solar project, subject to approval of the purchase agreement by the IPUC, is scheduled to be on-line in 2022.

Customer-Owned Generation Filings

In July 2017, Idaho Power filed an application with the IPUC related to residential and small commercial customers who install their own on-site generation, seeking the creation of two new classes of customers, with no request to change pricing or compensation. In May 2018, the IPUC issued an order authorizing the creation of the new customer classes. In that order, the IPUC also stated its intent to open an Idaho Power-specific docket to comprehensively study on-site generation and ordered Idaho Power to file a study with the IPUC exploring fixed-cost recovery prior to its next general rate case. In September 2018, the IPUC issued an order requiring further investigation to resolve eligibility issues for the new customer classes. In October 2018, Idaho Power filed petitions requesting that the IPUC open two new cases to study fixed-cost recovery, and the costs and benefits of and the proper rate design for on-site generation, respectively. In April 2019, Idaho Power filed an application with the IPUC requesting that the IPUC initiate a proceeding to explore modifications, for implementation by January 1, 2020, to the compensation structure and excess energy value applied to rates for large commercial, industrial, and irrigation customers who install their own on-site generation. In April 2019, the IPUC issued an order acknowledging Idaho Power's application and setting forth procedures for the case to be processed.

Relicensing of ~~Hydroelectric~~Hydropower Projects

In connection with Idaho Power's efforts to relicense the HCC, Idaho Power's largest ~~hydroelectric~~hydropower complex and a major relicensing effort, as described in more detail in ~~IDACORP's and Idaho Power's~~the 2018 Annual Report ~~on Form 10-K for the year ended December 31, 2017,~~ in Part II, Item 7 - "Regulatory Matters," Idaho Power ~~has~~ filed water quality certification applications, required under Section 401 of the Clean Water Act (CWA), with the states of Idaho and Oregon requesting that each state certify that any discharges from the project comply with applicable state water quality standards. Section 401 of the CWA requires that a state either approve or deny a Section 401 water quality certification application within one year of the filing of the application or the state may be considered to have waived its certification authority under the CWA. As a consequence, Idaho Power ~~has been filing and withdrawing its Section 401 certification applications with Oregon and Idaho on an annual basis while it~~ has been working with the states to identify measures that will provide reasonable assurance that discharges from the HCC will adequately address applicable water quality standards.

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In April 2019, the ~~2016 Section 401 certification application process,~~states of Idaho and Oregon, ~~required~~along with Idaho Power, to comply with fish passage and reintroduction conditions. Idaho's water quality certification, however, provides that Idaho Power shall take no action that may result in the reintroduction or establishment of spawning populations of any fish species into Idaho's waters without consultation with and express approval of the State of Idaho. In November 2016, Idaho Power filedreached a petition with the FERC requesting that the FERC resolve the conflict between Oregon's and Idaho's conditions and declare that the Federal Power Act pre-empts the Oregon state law. In January 2017, the FERC issued an order denying Idaho Power’s petition, stating that the petition for a declaratory order was premature, cannot realistically be considered separately from the issue of the states’ certification authority undersettlement pertaining to the CWA Section 401 ~~and raises issues~~certification that ~~are beyond the FERC’s authority to decide. In February 2017,~~requires Idaho Power ~~sought rehearing before~~to increase the ~~FERC on the January 2017 order, which the FERC denied. In February 2018,~~number of Chinook salmon it releases each year through expanded hatchery production. Additionally, Idaho Power ~~filed an appeal~~is required to fund a total of $12 million of research and water quality improvements in the HCC, over a 20-year period following the issuance of the ~~FERC's January 2017 order with~~license. These measures are in exchange for Oregon removing the ~~D.C. Circuit Court, which~~fish passage requirement from the Oregon Section 401 certification for at least the first 20 years after final license issuance. Idaho Power estimates that the combined cost of the mandated water quality improvements and expanded hatchery production is ~~pending.~~

~~Table~~$20 million over the first 20 years of ~~Contents~~

the new license term. In ~~April 2017, the governors of~~May 2019, Oregon and Idaho ~~jointly requested that Idaho Power withdraw and resubmit its~~issued final CWA Section 401 certifications. These certifications have been submitted to the FERC as part of the relicensing process. In July 2019, several third-parties filed lawsuits against the Oregon Department of Environmental Quality in Oregon state court challenging the Oregon CWA Section 401 certification ~~applications in both states to allow~~based on fish passage, water temperature, and mercury issues associated with the ~~states additional time to negotiate a potential resolution of~~Snake River and HCC. No parties challenged the ~~disputed issues.~~Idaho CWA 401 certification by the applicable deadline. Idaho Power ~~subsequently withdrew its Section 401 certification applications in both states and since that time~~continues to expect the ~~states have been negotiating towards a mutually agreeable solution. Idaho Power most recently resubmitted its application~~FERC to ~~both states in June 2018 with the intent to allow additional time for the states to continue negotiating.~~issue an HCC license no earlier than 2022.

Costs for the relicensing of Idaho Power's ~~hydroelectric~~hydropower projects are recorded in construction work in progress until new multi-year licenses are issued by the FERC, at which time the charges are transferred to electric plant in service. Idaho Power expects to seek timely recovery of relicensing costs and costs related to a new long-term license through the ratemaking process. Relicensing costs of ~~$282~~$311 million (including AFUDC) for the HCC were included in construction work in progress at June 30, ~~2018.~~2019. As of the date of this report, the IPUC authorizes Idaho Power to include in its Idaho jurisdiction rates $8.8 million of AFUDC annually relating to the HCC relicensing project. ~~Prior to the May 2018 Idaho Tax Reform Settlement Stipulation described in Note 3 - "Regulatory Matters," Idaho Power was collecting $10.7 million annually.~~ Collecting these amounts currently will reduce future collections when HCC relicensing costs are approved for recovery in base rates. As of June 30, ~~2018,~~2019, Idaho Power's regulatory liability for collection of AFUDC relating to the HCC was approximately ~~$127~~$143 million.

When the FERC issues a new long-term license, Idaho Power will begin operating under the requirements contained in the new license. Idaho Power expects those requirements to increase both other O&M expenditures and capital expenditures. Because Idaho Power is uncertain when the FERC will issue a new license, it has not included the expected capital expenditure increases in the “Capital Requirements” section of “Liquidity and Capital Resources” of this MD&A. As Idaho and Oregon issued final Section 401 certifications in May 2019, Idaho Power is updating its capital expenditure forecasts and expects to begin including the estimated capital expenditure increases in its disclosures as it refines the estimates in future periods. Idaho Power is unable to predict the exact timing of issuance of a new license for the HCC, or the ultimate financial or operational requirements of a new license.

In December 2016, Idaho Power filed an application with the IPUC requesting a determination that Idaho Power's expenditures of $220.8 million through year-end 2015 on relicensing of the HCC were prudently incurred, and thus eligible for future inclusion in retail rates in a future regulatory proceeding. In December 2017, Idaho Power filed with the IPUC a settlement stipulation signed by Idaho Power, the IPUC staff, and a third party intervenor, recognizing that a total of $216.5 million in expenditures were reasonably incurred, and therefore should be eligible for inclusion in customer rates at a later date. As a result of filing the settlement stipulation, Idaho Power recorded a $5.0 million pre-tax charge in the fourth quarter of 2017, which included $4.3 million for costs incurred through 2015, as well as $0.7 million related to associated costs incurred in 2016 and 2017. In April 2018, the IPUC issued an order approving the settlement stipulation as filed with the IPUC and determined the associated costs to be reasonably and prudently incurred.

ENVIRONMENTAL MATTERS

Overview

Idaho Power is subject to a broad range of federal, state, regional, and local laws and regulations designed to protect, restore, and enhance the environment, including the Affordable Clean Energy (ACE) rule and other Clean Air Act (CAA) requirements, the CWA, the Resource Conservation and Recovery Act, the Toxic Substances Control Act, the Comprehensive Environmental Response, Compensation and Liability Act, and the Endangered Species Act, among other laws. These laws are administered by a number of federal, state, and local agencies. In addition to imposing continuing compliance obligations and associated costs, these laws and regulations provide authority to regulators to levy substantial penalties for noncompliance, injunctive relief, and other sanctions. Idaho Power's three coal-fired power plants and three natural gas-fired combustion turbine power plants are subject to many of these regulations. Idaho Power's 17 ~~hydroelectric~~hydropower projects are also subject to a number of water discharge standards and other environmental requirements.

Compliance with current and future environmental laws and regulations may:

increase the operating costs of generating plants;

increase the construction costs and lead time for new facilities;

require the modification of existing generation plants, which could result in additional costs;

require the curtailment or shut-down of existing generating plants; or

reduce the output from current generating facilities.

Current and future environmental laws and regulations may increase the cost of operating fossil fuel-fired generation plants and constructing new generation and transmission facilities, in large part through the substantial cost of permitting activities and the required installation of additional pollution control devices. In many parts of the United States, some higher-cost, high-emission coal-fired plants have ceased operation or the plant owners have announced a near-term cessation of operation, as the cost of compliance makes the plants uneconomical to operate. Beyond increasing costs generally, these environmental laws and regulations could affect IDACORP's and Idaho Power's results of operations and financial condition if the costs associated with

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these environmental requirements and early plant retirements cannot be fully recovered in rates on a timely basis. Part I - "Business - Environmental Regulation and Costs" in ~~IDACORP's and Idaho Power's~~the 2018 Annual Report, ~~on Form 10-K for the year ended December 31, 2017,~~ includes a summary of Idaho Power's expected capital and operating expenditures for environmental matters during the period from ~~2018~~2019 to ~~2020.~~2021. Given the uncertainty of future environmental regulations, Idaho Power is unable to predict its environmental-related expenditures beyond that time, though they could be substantial.

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A summary of notable environmental matters impacting, or expected to potentially impact, IDACORP and Idaho Power, is included in Part II, Item 7 - "MD&A - Environmental Issues" and "MD&A - Liquidity and Capital Resources - Capital Requirements - Environmental Regulation Costs" in ~~IDACORP's and Idaho Power's~~the 2018 Annual ~~Report on Form 10-K for the year ended December 31, 2017.~~

~~Endangered Species Act Matters~~

~~Overview:~~ ~~The listing of a species of fish, wildlife, or plants as threatened or endangered under the ESA may have an adverse impact on Idaho Power's ability~~Report. Developments in certain environmental matters relevant to construct generation, transmission, or distribution facilities or relicense or operate its hydroelectric facilities. When a species is added to the federal list of threatened and endangered species, it is protected from “take,” which is defined to include harming the species. The ESA directs that, concurrent with a designation of a threatened or endangered species, and where prudent and determinable, the applicable agencies also designate “any habitat of such species which is then considered to be critical habitat.” The ESA also provides that each federal agency must ensure that any action they authorize, fund, or carry out is not likely to jeopardize the continued existence of a listed species or result in the destruction or adverse modification of its critical habitat. If an action is determined to result in adverse modification of critical habitat, the federal agency must adopt changes to the proposed action to avoid the adverse modification. These changes are often quite extensive and can affect the size, scope, and even the feasibility of a project moving forward. In February 2016, the U.S. Fish and Wildlife Service (USFWS) and the NMFS issued a set of regulatory and policy changes relating to critical habitat and adverse modification determinations under the ESA (2016 ESA Rules). While the ultimate impact of implementation of those changes is yet to be determined, taken as a whole, Idaho Power believes that the 2016 ESA Rules could result in the applicable agencies having greater authority in making designations of critical habitat and could increase the likelihood of adverse modification determinations.are described below.

On July 19, 2018, the USFWS and the NMFS issued three proposals to revise ESA regulations (2018 ESA Regulations) related to the process and standards for listing species and designating critical habitat, the process for consultations with federal agencies under Section 7 of the ESA (including the definition of "destructive or adverse modification" of designated critical habitat), and the scope of protection of threatened species. Idaho Power believes that if the 2018 ESA Regulations are enacted, the regulations could reduce Idaho Power’s obligations for mitigation under the ESA related to various construction and relicensing projects.

The construction of generation, transmission, or distribution facilities and the relicensing of Idaho Power's hydroelectric projects can be federally authorized actions that fall under the ESA. There are a number of threatened or endangered species within Idaho Power's service area and within or near proposed transmission line routes, including the slickspot peppergrass. Further, there are a number of ESA-listed fish and other aquatic species located in waterways in which Idaho Power has hydroelectric facilities, including fall Chinook salmon, bull trout, Bliss Rapids snail, and Snake River physa snail. To date, efforts to protect these and other listed species have not significantly affected generation levels or operating costs at any of Idaho Power's hydroelectric facilities. However, the ongoing relicensing of the HCC presents endangered species and fisheries issues that may require operational adjustments and could adversely impact the amount of output from hydroelectric dams, potentially causing Idaho Power to rely on more expensive sources for power generation or market purchases.

~~Developments in Regulation of Sage Grouse Habitat:~~ In February 2016, a lawsuit was filed in the U.S. District Court of Idaho challenging the BLM's sage grouse resource management and land use plan revisions that became effective in 2015 under the Federal Land Policy and Management Act. The lawsuit challenges the plans and associated environmental impact statements across the sage grouse range and alleges that the plans fail to ensure that sage grouse populations and habitats will be protected and restored in accordance with the best available science and legal mandates. Further, the complaint challenges certain exemptions provided for the Boardman-to-Hemingway and Gateway West transmission line projects. Idaho Power has intervened in the proceedings in an effort to support the exemptions provided for in the BLM's plans. If the exemptions are overturned, Idaho Power may be required to re-route the projects, which could lead to substantially higher construction and permitting costs and could delay construction.

In May 2016, a separate lawsuit was filed in the U.S. District Court of North Dakota, challenging the BLM's sage grouse resource management and land use plan revisions, including the exemptions provided for the Boardman-to-Hemingway and Gateway West transmission line projects. In October 2016, the plaintiffs amended their complaint to no longer challenge the exemptions; however, in December 2016, the North Dakota court transferred claims challenging certain Idaho land use plan amendments to the U.S. District Court for the District of Columbia. Idaho Power is participating in the proceedings in an effort to protect its interests.

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In June 2017, the Secretary of the Interior issued an order directing the BLM to review the 2015 sage grouse resource management and land use plan revisions and to identify provisions that may require modification or rescission to address energy and other development of public lands. In October 2017, the Secretary of the Interior issued a notice of intent declaring the Department of the Interior’s intent to consider amending the 2015 sage grouse resource management and land use plan revisions. In May 2018, the BLM issued draft resource management plan amendments and draft environmental impact statements to modify the 2015 sage grouse plans to better align the plans with state plans, conservation measures and the Department of the Interior and BLM policy. The public comment period runs through August 2, 2018. As of the date of this report, the above lawsuits are stayed as the parties and the courts consider the Department of the Interior’s review of the sage grouse resource management and land use plan revisions.

~~Clean Water Act Matters~~

Definition of “Waters of the United States” Under the ~~CWA: On~~CWA: In August ~~28,~~ 2015, the ~~EPA's~~U.S. Environmental Protection Agency's (EPA) and U.S. Army Corps of Engineers' final rule defining the phrase "waters of the United States" (WOTUS) under the CWA became effective (WOTUS Rule). Idaho Power believes that the ~~final~~2015 rule potentially expanded federal jurisdiction under the CWA beyond traditional navigable waters, interstate waters, territorial seas, tributaries, and adjacent wetlands, to a number of other waters, including waters with a "significant nexus" to those traditional waters. The WOTUS Rule was widely challenged in both federal district and circuit courts. The ~~State of~~WOTUS Rule does not currently apply in twenty-eight states, including Idaho, and ~~several other parties, challenged the rule in North Dakota federal court. That court held that it had jurisdiction and enjoined the implementation of~~litigation regarding the WOTUS ~~Rule.~~Rule continues. In February ~~2017, President Trump issued an executive order directing~~2019, the EPA and the U.S. Army Corps of Engineers ~~to rescind the WOTUS Rule. In July 2017, the EPA and the U.S. Army Corps of Engineers issued~~published a ~~notice of their intent to rescind and replace the~~revised definition of ~~"waters of the United States" under the CWA,~~WOTUS, which ~~Idaho Power expects~~ would reduce the number of waters in Idaho Power's service area subject to the WOTUS Rule. In November 2017, the EPA issued a notice that it will delay the effectiveness of the WOTUS Rule until 2020 while the U.S. Army Corps of Engineers considers a replacement rule. In January 2018, the U.S. Supreme Court issued a unanimous ruling that challenges to the WOTUS Rule must begin with the federal district courts, effectively negating a nationwide stay issued by the Sixth Circuit in 2016. However, because the State of Idaho remains a party to the federal court action in North Dakota, that court’s enjoinder remains in effect, meaning the WOTUS Rule currently does not apply to actions brought in Idaho. On July 12, 2018, the EPA and the U.S. Army Corps of Engineers issued a supplemental notice seeking additional comment on their 2017 proposal to repeal the definition of the term WOTUS Rule under the CWA.

Idaho Power has analyzed the WOTUS Rule and expects that, even if the WOTUS Rule is reinstated in Idaho and should the revised definition take effect in Idaho, while it may cause Idaho Power to incur additional permitting, regulatory requirements, and other costs associated with the rule, the aggregate amount of increased costs is unlikely to have a material adverse effect on Idaho Power's operations or financial condition, in part due to the relatively arid climate of Idaho Power's service area. Similarly, because the CWA, as interpreted even prior to the WOTUS Rule, applies to most of Idaho Power's facilities, including its ~~hydroelectric~~hydropower plants, Idaho Power does not expect ~~that the repeal of the WOTUS Rule will~~this proposal to have a material ~~benefit to~~impact on Idaho Power's operations or financial condition.

Clean Power Plan Repealed; Affordable Clean Energy Rule Adopted: In June 2014, the EPA released, under Section 111(d) of the CAA, a proposed rule for addressing GHG from existing fossil fuel-fired electric generating units (EGUs). The proposed rule was intended to achieve a 30 percent reduction in CO₂ emissions from the power sector by 2030. In August 2015, the EPA released the final rule under Section 111(d) of the CAA, referred to as the Clean Power Plan (CPP), which required states to adopt plans to collectively reduce 2005 levels of power sector CO₂ emissions by 32 percent by the year 2030. On June 19, 2019, the EPA released the ACE rule to replace the CPP under Section 111(d) of the CAA for existing electric utility generating units. The new rule provides states with new emissions guidelines that inform the state development of standards of performance to reduce CO₂emissions from existing generation facilities and is limited to reduction and compliance measures that occur at the physical location of each plant, removing the proposal to require reductions outside the boundaries of plants. The ACE rule also provides for more state-specific control over implementation of the rule to address greenhouse gas emissions from existing coal-fired power plants, with a focus on state evaluation of improvement potential, technical feasibility, applicability, and remaining useful life of each unit. States are required to submit their compliance plans to the EPA by July 2022.

Because the rule is premised on state implementation plans, the terms of which Idaho Power does not control, as of the date of this report, Idaho Power is uncertain whether and to what extent the ACE rule may impact its operations in the near term. Idaho Power's preliminary review of the rule indicates that it may not have substantial impacts on Idaho Power's operation of existing thermal generation units due to its planned retirements and other planned upgrades at each generating facility.

OTHER MATTERS

Critical Accounting Policies and Estimates

IDACORP's and Idaho Power's discussion and analysis of their financial condition and results of operations are based upon their condensed consolidated financial statements, which have been prepared in accordance with generally accepted accounting principles. The preparation of these financial statements requires IDACORP and Idaho Power to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues, and expenses and related disclosure of contingent assets and liabilities. On an ongoing basis, IDACORP and Idaho Power evaluate these estimates, including those estimates related to rate regulation, retirement benefits, contingencies, asset impairment, income taxes, unbilled revenues, and bad debt. These estimates are based on historical experience and on other assumptions and factors that are believed to be reasonable under the circumstances, and are the basis for making judgments about the carrying values of assets and liabilities that are not readily

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apparent from other sources. IDACORP and Idaho Power, based on their ongoing reviews, make adjustments when facts and circumstances dictate.

IDACORP’s and Idaho Power’s critical accounting policies are reviewed by the audit committees of the boards of directors. These policies have not changed materially from the discussion of those policies included under "Critical Accounting Policies and Estimates" in ~~IDACORP's and Idaho Power's~~the 2018 Annual ~~Report on Form 10-K for the year ended December 31, 2017.~~Report.

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Recently Issued Accounting Pronouncements

For a listing of new and recently adopted accounting standards, see Note 1 - "Summary of Significant Accounting Policies" to the notes to the condensed consolidated financial statements included in this report.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

IDACORP is exposed to market risks, including changes in interest rates, changes in commodity prices, credit risk, and equity price risk. The following discussion summarizes material changes in these risks since December 31, ~~2017,~~2018, and the financial instruments, derivative instruments, and derivative commodity instruments sensitive to changes in interest rates, commodity prices, and equity prices that were held at June 30, ~~2018.~~2019. IDACORP has not entered into any of these market-risk-sensitive instruments for trading purposes.

Interest Rate Risk

IDACORP manages interest expense and short- and long-term liquidity through a combination of fixed rate and variable rate debt. Generally, the amount of each type of debt is managed through market issuance, but interest rate swap and cap agreements with highly-rated financial institutions may be used to achieve the desired combination.

Variable Rate Debt: As of June 30, ~~2018,~~2019, IDACORP had no net floating rate debt, as the carrying value of short-term investments exceeded the carrying value of outstanding variable-rate debt.

Fixed Rate Debt: As of June 30, ~~2018,~~2019, IDACORP had $1.8 billion in fixed rate debt, with a fair market value of approximately ~~$1.9~~$2.0 billion. These instruments are fixed rate and, therefore, do not expose the companies to a loss in earnings due to changes in market interest rates. However, the fair value of these instruments would increase by approximately ~~$281.2~~$301 million if market interest rates were to decline by one percentage point from their June 30, ~~2018~~2019 levels.

Commodity Price Risk

IDACORP's exposure to changes in commodity prices is related to Idaho Power's ongoing utility operations that produce electricity to meet the demand of its retail electric customers. These changes in commodity prices are mitigated in large part by Idaho Power's Idaho and Oregon power cost adjustment mechanisms. To supplement its generation resources and balance its supply of power with the demand of its retail customers, Idaho Power participates in the wholesale marketplace. IDACORP's commodity price risk as of June 30, ~~2018,~~2019, had not changed materially from that reported in Item 7A of IDACORP's Annual Report on Form 10-K for the year ended December 31, ~~2017.~~2018 (2018 Annual Report). Information regarding Idaho Power’s use of derivative instruments to manage commodity price risk can be found in Note 1110 - "Derivative Financial Instruments" to the condensed consolidated financial statements included in this report.

Credit Risk

IDACORP is subject to credit risk based on Idaho Power's activity with market counterparties. Idaho Power is exposed to this risk to the extent that a counterparty may fail to fulfill a contractual obligation to provide energy, purchase energy, or complete financial settlement for market activities. Idaho Power mitigates this exposure by actively establishing credit limits; measuring, monitoring, and reporting credit ~~risk~~risk; using appropriate contractual arrangements; and transferring of credit risk through the use of financial guarantees, cash, or letters of credit. Idaho Power maintains a current list of acceptable counterparties and credit limits.

The use of performance assurance collateral in the form of cash, letters of credit, or guarantees is common industry practice. Idaho Power maintains margin agreements relating to its wholesale commodity contracts that allow performance assurance collateral to be requested of and/or posted with certain counterparties. As of June 30, ~~2018,~~2019, Idaho Power had posted ~~$0.8~~$1.8 million performance assurance collateral related to these contracts. Should Idaho Power experience a reduction in its credit rating on Idaho Power's unsecured debt to below investment grade Idaho Power could be subject to requests by its wholesale

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counterparties to post additional performance assurance collateral. Counterparties to derivative instruments and other forward contracts could request immediate payment or demand immediate ongoing full daily collateralization on derivative instruments and contracts in net liability positions. Based upon Idaho Power's energy and fuel portfolio and market conditions as of June 30, ~~2018,~~2019, the amount of collateral that could be requested upon a downgrade to below investment grade was approximately ~~$4.2~~$5.4 million. To minimize capital requirements, Idaho Power actively monitors the portfolio exposure and the potential exposure to additional requests for performance assurance collateral calls through sensitivity analysis.

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IDACORP's credit risk related to uncollectible accounts, net of amounts reserved, as of June 30, ~~2018,~~2019, had not changed materially from that reported in Item 7A of ~~IDACORP's~~the 2018 Annual ~~Report on Form 10-K for the year ended December 31, 2017.~~Report. Additional information regarding Idaho Power’s management of credit risk and credit contingent features can be found in Note 1110 - "Derivative Financial Instruments" to the condensed consolidated financial statements included in this report.

Equity Price Risk

IDACORP is exposed to price fluctuations in equity markets, primarily through Idaho Power's defined benefit pension plan assets, a mine reclamation trust fund owned by an equity-method investment of Idaho Power, and other equity security investments at Idaho Power. The equity securities held by the pension plan and in such accounts are diversified to achieve broad market participation and reduce the impact of any single investment, sector, or geographic region. Idaho Power has established asset allocation targets for the pension plan holdings, which are described in Note 1012 - "Benefit Plans" to the consolidated financial statements included in ~~IDACORP's~~the 2018 Annual ~~Report on Form 10-K for the year ended December 31, 2017.~~Report.

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ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

IDACORP: The Chief Executive Officer and the Chief Financial Officer of IDACORP, based on their evaluation of IDACORP’s disclosure controls and procedures (pursuant to Rule 13a-15(b) of the Securities Exchange Act of 1934 (Exchange Act)) as of June 30, ~~2018,~~2019, have concluded that IDACORP’s disclosure controls and procedures (as defined in Rule 13a-15(e) of the Exchange Act) are effective as of that date.

Idaho Power: The Chief Executive Officer and the Chief Financial Officer of Idaho Power, based on their evaluation of Idaho Power’s disclosure controls and procedures (pursuant to Rule 13a-15(b) of the Exchange Act) as of June 30, ~~2018,~~2019, have concluded that Idaho Power’s disclosure controls and procedures (as defined in Rule 13a-15(e) of the Exchange Act) are effective as of that date.

Changes in Internal Control over Financial Reporting

There have been no changes in IDACORP's or Idaho Power's internal control over financial reporting during the quarter ended June 30, ~~2018,~~2019, that have materially affected, or are reasonably likely to materially affect, IDACORP's or Idaho Power's internal control over financial reporting.

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PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

None

ITEM 1A. RISK FACTORS

The factors discussed in Part I - Item 1A - "Risk Factors" in IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, ~~2017,~~2018, could materially affect IDACORP’s and Idaho Power's business, financial condition, or future results. In addition to those risk factors and other risks discussed in this report, see "Cautionary Note Regarding Forward-Looking Statements" in this report for additional factors that could have a significant impact on IDACORP's or Idaho Power's operations, results of operations, or financial condition and could cause actual results to differ materially from those anticipated in forward-looking statements.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Restrictions on Dividends

See Note 65 - "Common Stock" to the condensed consolidated financial statements included in this report for a description of restrictions on IDACORP's and Idaho Power's payment of dividends.

Issuer Purchases of Equity Securities

IDACORP did not repurchase any shares of its common stock during the quarter ended June 30, ~~2018.~~2019.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None

ITEM 4. MINE SAFETY DISCLOSURES

Information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.104) is included in Exhibit 95.1 of this report, which is incorporated herein by reference.

ITEM 5. OTHER INFORMATION

None

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ITEM 6. EXHIBITS

The following exhibits are filed or furnished, as applicable, with the Quarterly Report on Form 10-Q for the quarter ended June 30, ~~2018:~~2019:



		Incorporated by Reference
Exhibit No.	Exhibit Description	Form	File No.	Exhibit No.	Date	Included Herewith

~~10.1~~ ⁽¹⁾	~~Third Amendment to the Idaho Power Company Employee Savings Plan, executed April 26, 2018 and effective January 1, 2018~~	~~10-Q~~	~~1-14465; 1-3198~~	~~10.4~~	~~5/3/2018~~
~~12.1~~	~~IDACORP, Inc. Computation of Ratio of Earnings to Fixed Charges and Supplemental Ratio of Earnings to Fixed Charges~~					X
~~12.2~~	~~Idaho Power Company Computation of Ratio of Earnings to Fixed Charges and Supplemental Ratio of Earnings to Fixed Charges~~					X
15.1	Letter Re: Unaudited Interim Financial Information					X
15.2	Letter Re: Unaudited Interim Financial Information					X
31.1	Certification of IDACORP, Inc. Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002					X
31.2	Certification of IDACORP, Inc. Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002					X
31.3	Certification of Idaho Power Company Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002					X
31.4	Certification of Idaho Power Company Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002					X
32.1	Certification of IDACORP, Inc. Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002					X
32.2	Certification of IDACORP, Inc. Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002					X
32.3	Certification of Idaho Power Company Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002					X
32.4	Certification of Idaho Power Company Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002					X
95.1	Mine Safety Disclosures					X
~~101.INS~~	~~XBRL Instance Document~~					X
101.SCH	XBRL Taxonomy Extension Schema Document					X
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document					X
101.LAB	XBRL Taxonomy Extension Label Linkbase Document					X
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document					X
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document					X
104	Cover Page Interactive Data File (formatted as inline XBRL with applicable taxonomy extension information contained in Exhibits 101.*)					X

⁽¹⁾ ~~Management contract or compensatory plan or arrangement.~~

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.



		IDACORP, INC.
		(Registrant)



Date:	August ~~2, 2018~~1, 2019	By:	/s/ Darrel T. Anderson
			Darrel T. Anderson
			President and Chief Executive Officer

Date:	August ~~2, 2018~~1, 2019	By:	/s/ Steven R. Keen
			Steven R. Keen
			Senior Vice President, Chief Financial
			Officer, and Treasurer





		IDAHO POWER COMPANY
		(Registrant)



Date:	August ~~2, 2018~~1, 2019	By:	/s/ Darrel T. Anderson
			Darrel T. Anderson
			President and Chief Executive Officer

Date:	August ~~2, 2018~~1, 2019	By:	/s/ Steven R. Keen
			Steven R. Keen
			Senior Vice President, Chief Financial
			Officer, and Treasurer

6959

Expected capital expenditures (excluding AFUDC)