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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
FORM 10-Q

☒QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES 
 EXCHANGE ACT OF 1934 
 For the quarterly period ended
June 30, 2019March 31, 2020
  
 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 specifiedI.R.S. Employer
Commission Filein their charters, address of principalIdentification
Numberexecutive offices, zip code and telephone numberNumber
1-14465IDACORP, Inc.82-0505802
1-3198Idaho Power Company82-0130980
 1221 W. Idaho Street 
 Boise,Idaho83702-5627 
  (208)388-2200 
 State of Incorporation:Idaho  
     
None
Former name, former address and former fiscal year, if changed since last report.

Securities registered pursuant to Section 12(b) of the Securities Exchange Act of 1934
Title of each classTrading Symbol(s)Name of each exchange on which registered
Common StockIDANew York Stock Exchange

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 every Interactive Data File required to be submitted 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 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:

IDACORP, Inc.:                                
Large accelerated filer X Accelerated filer __ Non-accelerated  filer __
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. __

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Idaho Power Company:                                
Large accelerated filer __ Accelerated filer __ Non-accelerated Filer X
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. __
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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 classTrading Symbol(s)Name of each exchange on which registered
Common StockIDANew York Stock Exchange

Number of shares of common stock outstanding as of July 26, 2019:April 24, 2020:     
IDACORP, Inc.:        50,397,12150,453,936
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
32
 Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations
34
 Item 3. Quantitative and Qualitative Disclosures About Market Risk
55
 Item 4. Controls and Procedures
56
     
Part II. Other Information 
   
 Item 1. Legal Proceedings
57
 Item 1A. Risk Factors
57
 Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
57
 Item 3. Defaults Upon Senior Securities
5758
 Item 4. Mine Safety Disclosures
5758
 Item 5. Other Information
5758
 Item 6. Exhibits
58
   
Signatures
59

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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:
   
20182019 Annual Report-
IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended
December 31, 20182019
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
Jim Bridger plant-Jim Bridger generating plant
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-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, 2018,2019, 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 (SEC), and the following important factors:

the effect of decisions by the Idaho and Oregon public utilities commissions and the Federal Energy Regulatory Commission that impact Idaho Power's ability to recover costs and earn a return on investment;
changes to or the expense and risks associated with capital expenditures for utility infrastructure, and the timing and availabilityelimination of Idaho Power's cost recovery for such expenditures through customer rates,mechanisms;
the widespread impacts of the recent COVID-19 coronavirus outbreak on the global and regional economy and on Idaho Power's employees, customers, contractors, and suppliers, including on loads and revenues, uncollectible accounts, transmission revenues, and other aspects of the potential for the write-down or write-off of expenditures if not deemed prudent by regulators;companies' business;
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 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, credit quality of counterparties and suppliers, and the collection of receivables;
unseasonableabnormal or severe weather conditions, wildfires, droughts, and other natural phenomena and natural disasters, including conditions and events associated with climate change, wildfires, drought, earthquakes, and other natural phenomena and natural disasters, which affect customer demand,sales, hydropower generation levels, repair costs, service interruptions, 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, energy storage, grid-connected devices, and energy efficiency, alternative energy sources, and other technologies that may affect Idaho Power's sale or delivery of electric power or introduce operational or cyber-security vulnerability to the power grid;
acts or threats of terrorist incidents, other malicious acts, acts of war, cyber-attacks, the companies' failure to secure data or to comply with privacy laws or regulations, security breaches, or the disruption or damage to the companies' business, operations, or reputation resulting from such events and related litigation or penalties;
the expense and risks associated with capital expenditures for, and the permitting and construction of, utility infrastructure that Idaho Power may be unable or unwilling to complete or may not be deemed prudent by regulators;
variable hydrological conditions and over-appropriation of surface and groundwater in the Snake River Basin, which may impact the amount of power generated by Idaho Power's 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, climate change, or a credit downgrade;
disruptions or outages of Idaho Power's generation or transmission systems or of any interconnected transmission systems may constrain resources or cause Idaho Power to incur repair costs and purchase replacement power at increased costs;
accidents, fires (either affecting or caused by Idaho Power facilities or infrastructure), explosions, and mechanical breakdowns that may occur while operating and maintaining Idaho Power assets, which can cause unplanned outages, reduce generating output, damage company assets, operations, or reputation, subject Idaho Power 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 for which Idaho Power may have inadequate insurance coverage;
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the increased purchased power costs and operational challenges associated with purchasing and integrating intermittent renewable energy sources into Idaho Power's resource portfolio;
failure to comply with state and federal laws, regulations, and orders, including new cyber security risks;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;
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 associated increased costs through rates;
variable hydrological conditionsthe inability to obtain or cost of obtaining and over-appropriation of surfacecomplying with required governmental permits and groundwater in the Snake River Basin,approvals, licenses, rights-of-way, and siting for transmission and generation projects and hydropower facilities;
failure to comply with mandatory reliability and security requirements, which may impact result in penalties, reputational harm, and operational changes;
the amountcost and outcome of power generated by Idaho Power's hydropower facilities;
litigation, dispute resolution, and regulatory proceedings, and the ability to acquire fuel, power, and transmission capacity under reasonable terms, particularly inrecover those costs or the eventcosts of unanticipated power demands, lack of physical availability, transportation constraints,resulting operational changes through insurance or a credit downgrade;
accidents, fires (either affectingrates, or caused by Idaho Power facilities or infrastructure), explosions, and mechanical breakdowns that may occur while operating and maintaining Idaho 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 for which the companies may have inadequate insurance coverage;from third parties;
the increased purchased powerimpacts of economic conditions, including inflation, interest rates, supply costs, and operational challenges associated with purchasing and integrating intermittent renewable energy sources intopopulation growth or decline in Idaho Power's resource portfolio;
Tableservice area, changes in customer demand for electricity, revenue from sales of Contents

disruptions or outagesexcess power, credit quality of Idaho Power's generation or transmission systems orcounterparties and suppliers, and the collection of any interconnected transmission systems may constrain resources or cause Idaho Power to incur repair costs or purchase replacement power at increased costs;receivables;
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;
reductionschanges in the method for determining LIBOR and the potential replacement of LIBOR and the impact on interest rates for IDACORP's and Idaho Power's credit ratings, which could adversely impact access to debt and equity markets, increase borrowing costs, and require the posting of additional collateral to counterparties pursuant to credit and contractual arrangements;facilities;
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 and the companies' cash flows;
the assumptions underlying the coal mine reclamation obligations at Bridger Coal Company and related funding requirements;
the ability to continue to pay dividends based on financial performance and in light of credit rating considerations, contractual covenants and restrictions, and regulatory limitations;
Idaho Power's concentration in one industry and one region and the lack of diversification, and the resulting exposure to regional economic conditions and regional legislation and regulation;
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 third-party vendors, 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 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 companies' failure to secure data or to comply with privacy laws or regulations, security breaches, or the disruption or 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 CommissionSEC 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
March 31,
 2019 2018 2019 2018 2020 2019
 (in thousands, except per share amounts) (in thousands, except per share amounts)
Operating Revenues:            
Electric utility revenues $315,774
 $338,699
 $665,546
 $648,160
 $290,488
 $349,771
Other 1,121
 1,253
 1,668
 1,898
 520
 548
Total operating revenues 316,895
 339,952
 667,214
 650,058
 291,008
 350,319
            
Operating Expenses:            
Electric utility:            
Purchased power 58,063
 62,980
 120,894
 124,908
 61,201
 62,831
Fuel expense 20,826
 21,515
 72,696
 49,250
 30,015
 51,870
Power cost adjustment 16,122
 19,963
 42,347
 45,501
 (3,391) 26,225
Other operations and maintenance 87,007
 92,314
 175,913
 178,512
 89,808
 88,906
Energy efficiency programs 11,458
 8,802
 21,570
 16,399
 9,475
 10,112
Depreciation 41,172
 41,348
 83,406
 81,416
 42,526
 42,234
Taxes other than income taxes 9,377
 9,118
 18,237
 18,395
 8,683
 8,859
Total electric utility expenses 244,025
 256,040
 535,063
 514,381
 238,317
 291,037
Other 1,090
 1,077
 2,252
 2,253
 1,121
 1,163
Total operating expenses 245,115
 257,117
 537,315
 516,634
 239,438
 292,200
            
Operating Income 71,780
 82,835
 129,899
 133,424
 51,570
 58,119
            
Allowance for Equity Funds Used During Construction 6,699
 5,985
 13,054
 12,018
 7,272
 6,356
            
Earnings of Unconsolidated Equity-Method Investments 2,997
 1,537
 5,379
 5,552
 2,316
 2,381
            
Other Income (Expense), Net 1,060
 309
 3,173
 (150)
Other Income, Net 932
 2,114
            
Interest Expense:            
Interest on long-term debt 21,156
 21,412
 42,310
 42,099
 19,662
 21,154
Other interest 3,685
 2,162
 7,138
 5,121
 3,812
 3,453
Allowance for borrowed funds used during construction (2,733) (2,606) (5,324) (5,078) (2,730) (2,590)
Total interest expense, net 22,108
 20,968
 44,124
 42,142
 20,744
 22,017
            
Income Before Income Taxes 60,428
 69,698
 107,381
 108,702
 41,346
 46,953
            
Income Tax Expense 7,028
 7,105
 11,344
 9,998
 3,888
 4,316
            
Net Income 53,400
 62,593
 96,037
 98,704
 37,458
 42,637
Income attributable to noncontrolling interests (244) (305) (195) (274)
Loss attributable to noncontrolling interests 32
 49
Net Income Attributable to IDACORP, Inc. $53,156
 $62,288
 $95,842
 $98,430
 $37,490
 $42,686
Weighted Average Common Shares Outstanding - Basic 50,499
 50,435
 50,504
 50,430
 50,517
 50,509
Weighted Average Common Shares Outstanding - Diluted 50,507
 50,481
 50,512
 50,472
 50,527
 50,518
Earnings Per Share of Common Stock:            
Earnings Attributable to IDACORP, Inc. - Basic $1.05
 $1.24
 $1.90
 $1.95
 $0.74
 $0.85
Earnings Attributable to IDACORP, Inc. - Diluted $1.05
 $1.23
 $1.90
 $1.95
 $0.74
 $0.84

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
March 31,
 2019 2018 2019 2018 2020 2019
 (in thousands) (in thousands)
            
Net Income $53,400
 $62,593
 $96,037
 $98,704
 $37,458
 $42,637
Other Comprehensive Income:            
Unfunded pension liability adjustment, net of tax of $169, $250, $338, and $500, respectively 488
 722
 976
 1,443
Unfunded pension liability adjustment, net of tax of $259 and $169, respectively 747
 488
Total Comprehensive Income 53,888
 63,315
 97,013
 100,147
 38,205
 43,125
Income attributable to noncontrolling interests (244) (305) (195) (274)
Loss attributable to noncontrolling interests 32
 49
Comprehensive Income Attributable to IDACORP, Inc. $53,644
 $63,010
 $96,818
 $99,873
 $38,237
 $43,174

The accompanying notes are an integral part of these statements.
 
 
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IDACORP, Inc.
Condensed Consolidated Balance Sheets
(unaudited)
 
 June 30,
2019		 December 31,
2018		 March 31,
2020		 December 31,
2019
 (in thousands) (in thousands)
Assets        
        
Current Assets:        
Cash and cash equivalents $239,664
 $267,492
 $138,871
 $217,254
Receivables:        
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
Customer (net of allowance of $2,168 and $1,401, respectively) 67,895
 72,675
Other (net of allowance of $268 and $343, respectively) 14,062
 18,789
Income taxes receivable —
 4,356
 —
 3,106
Accrued unbilled revenues 73,226
 69,318
 53,973
 64,545
Materials and supplies (at average cost) 58,441
 54,987
 60,020
 56,660
Fuel stock (at average cost) 55,973
 47,979
 59,188
 57,448
Prepayments 17,023
 16,492
 22,093
 17,638
Current regulatory assets 53,660
 48,707
 56,826
 56,626
Other 4,285
 3,655
 14
 405
Total current assets 599,453
 597,640
 472,942
 565,146
Investments 94,503
 101,178
 117,286
 98,218
Property, Plant and Equipment:        
Utility plant in service 6,197,160
 6,103,856
 6,163,744
 6,113,567
Accumulated provision for depreciation (2,269,628) (2,210,781) (2,183,261) (2,155,783)
Utility plant in service - net 3,927,532
 3,893,075
 3,980,483
 3,957,784
Construction work in progress 501,550
 480,259
 556,498
 552,499
Utility plant held for future use 4,689
 4,751
 3,697
 3,872
Other property, net of accumulated depreciation 17,425
 17,650
 17,178
 17,299
Property, plant and equipment - net 4,451,196
 4,395,735
 4,557,856
 4,531,454
Other Assets:        
Company-owned life insurance 59,726
 59,852
 59,972
 58,922
Regulatory assets 1,195,079
 1,165,467
 1,341,052
 1,326,433
Other 60,896
 62,882
 60,842
 61,028
Total other assets 1,315,701
 1,288,201
 1,461,866
 1,446,383
Total $6,460,853
 $6,382,754
 $6,609,950
 $6,641,201

The accompanying notes are an integral part of these statements.
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IDACORP, Inc.
Condensed Consolidated Balance Sheets
(unaudited)
 
 June 30,
2019		 December 31,
2018		 March 31,
2020		 December 31,
2019
 (in thousands) (in thousands)
Liabilities and Equity        
        
Current Liabilities:        
Current maturities of long-term debt $—
 $100,000
Accounts payable $80,651
 $110,824
 67,662
 110,745
Taxes accrued 31,183
 12,009
 21,327
 11,501
Interest accrued 23,599
 23,622
 20,837
 20,999
Accrued compensation 39,564
 55,121
 39,818
 52,550
Current regulatory liabilities 67,458
 25,883
 46,009
 33,987
Advances from customers 37,401
 20,037
 32,668
 28,452
Other 15,726
 11,096
 19,533
 16,625
Total current liabilities 295,582
 258,592
 247,854
 374,859
Other Liabilities:        
Deferred income taxes 689,901
 699,878
 742,651
 746,231
Regulatory liabilities 750,811
 738,994
 741,141
 748,198
Pension and other postretirement benefits 433,725
 431,475
 515,626
 519,570
Other 45,862
 43,216
 52,397
 45,131
Total other liabilities 1,920,299
 1,913,563
 2,051,815
 2,059,130
Long-Term Debt 1,835,521
 1,834,788
 1,837,010
 1,736,659
Commitments and Contingencies 

 

 

 

Equity:        
IDACORP, Inc. shareholders’ equity:        
Common stock, no par value (120,000 shares authorized; 50,420 shares issued) 864,266
 863,593
Common stock, no par value (120,000 shares authorized; 50,454 and 50,420 shares issued, respectively) 864,850
 868,307
Retained earnings 1,563,399
 1,531,543
 1,638,065
 1,634,525
Accumulated other comprehensive loss (21,868) (22,844) (35,537) (36,284)
Treasury stock (23 shares and 27 shares, respectively, at cost) (1,992) (1,932)
Treasury stock (0 shares and 22 shares, respectively, at cost) —
 (1,920)
Total IDACORP, Inc. shareholders’ equity 2,403,805
 2,370,360
 2,467,378
 2,464,628
Noncontrolling interests 5,646
 5,451
 5,893
 5,925
Total equity 2,409,451
 2,375,811
 2,473,271
 2,470,553
Total $6,460,853
 $6,382,754
 $6,609,950
 $6,641,201
        
The accompanying notes are an integral part of these statements.

Table of Contents

IDACORP, Inc.
Condensed Consolidated Statements of Cash Flows
(unaudited)
 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2020 2019
 (in thousands) (in thousands)
Operating Activities:        
Net income $96,037
 $98,704
 $37,458
 $42,637
Adjustments to reconcile net income to net cash provided by operating activities:  
  
  
  
Depreciation and amortization 85,655
 83,306
 43,666
 43,362
Deferred income taxes and investment tax credits (6,177) (9,708) (1,379) (4,291)
Changes in regulatory assets and liabilities 31,643
 45,691
 (9,672) 19,540
Pension and postretirement benefit plan expense 13,894
 14,038
 7,260
 6,965
Contributions to pension and postretirement benefit plans (14,633) (24,516) (12,270) (12,410)
Earnings of equity-method investments (5,379) (5,552) (2,316) (2,381)
Distributions from equity-method investments 11,800
 11,300
 2,000
 7,700
Allowance for equity funds used during construction (13,054) (12,018) (7,272) (6,356)
Other non-cash adjustments to net income, net 3,923
 5,185
 3,490
 2,913
Change in:  
  
  
  
Accounts receivable (9,333) (5,937) 5,102
 (25,235)
Accounts payable and other accrued liabilities (44,286) (13,010) (49,389) (44,733)
Taxes accrued/receivable 23,530
 22,950
 12,932
 16,757
Other current assets (16,454) (16,152) 1,268
 9,112
Other current liabilities 9,350
 9,054
 5,122
 3,737
Other assets (1,482) (5,439) (1,925) (957)
Other liabilities 1,039
 (1,472) (279) 639
Net cash provided by operating activities 166,073
 196,424
 33,796
 56,999
Investing Activities:  
  
  
  
Additions to property, plant and equipment (129,860) (133,598) (73,566) (61,330)
Payments received from transmission project joint funding partners 1,016
 20,323
 393
 695
Proceeds from the sale of emission allowances and renewable energy certificates 3,702
 1,650
Investments in affordable housing (2,687) —
 (1,936) —
Purchase of equity securities (470) (228) (3,230) (240)
Proceeds from the sale of equity securities 2,546
 2,450
 839
 1,313
Other 91
 495
 3,826
 2,830
Net cash used in investing activities (125,662) (108,908) (73,674) (56,732)
Financing Activities:  
  
  
  
Issuance of long-term debt —
 220,000
Retirement of long-term debt —
 (130,000)
Dividends on common stock (64,077) (59,941) (34,312) (32,290)
Acquisition of treasury stock (4,107) (3,551)
Make-whole premium on retirement of long-term debt —
 (4,607)
Tax withholdings on net settlements of share-based awards (4,183) (4,107)
Debt issuance costs and other (55) (2,925) (10) (20)
Net cash (used in) provided by financing activities (68,239) 18,976
Net (decrease) increase in cash and cash equivalents (27,828) 106,492
Net cash used in financing activities (38,505) (36,417)
Net decrease in cash and cash equivalents (78,383) (36,150)
Cash and cash equivalents at beginning of the period 267,492
 76,649
 217,254
 267,492
Cash and cash equivalents at end of the period $239,664
 $183,141
 $138,871
 $231,342
Supplemental Disclosure of Cash Flow Information:  
  
  
  
Cash paid during the period for:  
    
  
Income taxes $—
 $—
 $—
 $—
Interest (net of amount capitalized) 42,204
 39,494
 19,887
 22,889
Non-cash investing activities:        
Additions to property, plant and equipment in accounts payable $26,700
 $20,650
 $22,843
 $23,690

The accompanying notes are an integral part of these statements.
Table of Contents

IDACORP, Inc.
Condensed Consolidated Statements of Equity
(unaudited)
 
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
 (in thousands) (in thousands) (in thousands)
Common Stock            
Balance at beginning of period $863,425
 $857,533
 $863,593
 $857,207
 $868,307
 $863,593
Share-based compensation expense 1,830
 2,870
 4,667
 5,411
 2,624
 2,837
Tax withholdings on net settlements of share-based awards (4,183) —
Treasury shares issued (1,016) (770) (4,047) (3,007) (1,920) (3,031)
Other 27
 19
 53
 41
 22
 26
Balance at end of period 864,266
 859,652
 864,266
 859,652
 864,850
 863,425
Retained Earnings            
Balance at beginning of period 1,542,175
 1,432,584
 1,531,543
 1,426,528
 1,634,525
 1,531,543
Net income attributable to IDACORP, Inc. 53,156
 62,288
 95,842
 98,430
 37,490
 42,686
Common stock dividends ($0.63, $0.59, $1.26, and $1.18 per share, respectively) (31,932) (29,863) (63,986) (59,949)
Common stock dividends ($0.67 and $0.63 per share, respectively) (33,950) (32,054)
Balance at end of period 1,563,399
 1,465,009
 1,563,399
 1,465,009
 1,638,065
 1,542,175
Accumulated Other Comprehensive (Loss) Income            
Balance at beginning of period (22,356) (30,243) (22,844) (30,964) (36,284) (22,844)
Unfunded pension liability adjustment (net of tax) 488
 722
 976
 1,443
 747
 488
Balance at end of period (21,868) (29,521) (21,868) (29,521) (35,537) (22,356)
Treasury Stock            
Balance at beginning of period (3,008) (2,706) (1,932) (1,386) (1,920) (1,932)
Issued 1,016
 770
 4,047
 3,007
 1,920
 3,031
Acquired —
 —
 (4,107) (3,557)
Acquired for tax withholdings on net settlements of share-based awards —
 (4,107)
Balance at end of period (1,992) (1,936) (1,992) (1,936) —
 (3,008)
Total IDACORP, Inc. shareholders’ equity at end of period 2,403,805
 2,293,204
 2,403,805
 2,293,204
 2,467,378
 2,380,236
Noncontrolling Interests            
Balance at beginning of period 5,402
 4,698
 5,451
 4,729
 5,925
 5,451
Net income attributable to noncontrolling interests 244
 305
 195
 274
Net loss attributable to noncontrolling interests (32) (49)
Balance at end of period 5,646
 5,003
 5,646
 5,003
 5,893
 5,402
Total equity at end of period $2,409,451
 $2,298,207
 $2,409,451
 $2,298,207
 $2,473,271
 $2,385,638

The accompanying notes are an integral part of these statements.
Table of Contents


Idaho Power Company
Condensed Consolidated Statements of Income
(unaudited)
 
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
 (in thousands) (in thousands)
            
Operating Revenues $315,774
 $338,699
 $665,546
 $648,160
 $290,488
 $349,771
            
Operating Expenses:            
Operation:            
Purchased power 58,063
 62,980
 120,894
 124,908
 61,201
 62,831
Fuel expense 20,826
 21,515
 72,696
 49,250
 30,015
 51,870
Power cost adjustment 16,122
 19,963
 42,347
 45,501
 (3,391) 26,225
Other operations and maintenance 87,007
 92,314
 175,913
 178,512
 89,808
 88,906
Energy efficiency programs 11,458
 8,802
 21,570
 16,399
 9,475
 10,112
Depreciation 41,172
 41,348
 83,406
 81,416
 42,526
 42,234
Taxes other than income taxes 9,377
 9,118
 18,237
 18,395
 8,683
 8,859
Total operating expenses 244,025
 256,040
 535,063
 514,381
 238,317
 291,037
            
Income from Operations 71,749
 82,659
 130,483
 133,779
 52,171
 58,734
            
Other Income (Expense):        
Other Income:    
Allowance for equity funds used during construction 6,699
 5,985
 13,054
 12,018
 7,272
 6,356
Earnings of unconsolidated equity-method investments 2,034
 683
 4,265
 4,825
 2,453
 2,231
Other income (expense), net 165
 (391) 1,087
 (1,519)
Other income, net 11
 922
Total other income 8,898
 6,277
 18,406
 15,324
 9,736
 9,509
            
Interest Charges:            
Interest on long-term debt 21,156
 21,412
 42,310
 42,099
 19,662
 21,154
Other interest 3,677
 2,148
 7,106
 5,093
 3,813
 3,429
Allowance for borrowed funds used during construction (2,733) (2,606) (5,324) (5,078) (2,730) (2,590)
Total interest charges 22,100
 20,954
 44,092
 42,114
 20,745
 21,993
            
Income Before Income Taxes 58,547
 67,982
 104,797
 106,989
 41,162
 46,250
            
Income Tax Expense 7,371
 7,345
 12,037
 10,496
 4,386
 4,666
            
Net Income $51,176
 $60,637
 $92,760
 $96,493
 $36,776
 $41,584

The accompanying notes are an integral part of these statements.
Table of Contents

Idaho Power Company
Condensed Consolidated Statements of Comprehensive Income
(unaudited)
 
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
 (in thousands) (in thousands)
            
Net Income $51,176
 $60,637
 $92,760
 $96,493
 $36,776
 $41,584
Other Comprehensive Income:            
Unfunded pension liability adjustment, net of tax of $169, $250, $338, and $500, respectively 488
 722
 976
 1,443
Unfunded pension liability adjustment, net of tax of $259 and $169, respectively 747
 488
Total Comprehensive Income $51,664
 $61,359
 $93,736
 $97,936
 $37,523
 $42,072

The accompanying notes are an integral part of these statements.
 
 

Table of Contents

Idaho Power Company
Condensed Consolidated Balance Sheets
(unaudited)
 
 June 30,
2019		 December 31,
2018		 March 31,
2020		 December 31,
2019
 (in thousands) (in thousands)
Assets        
        
Electric Plant:        
In service (at original cost) $6,197,160
 $6,103,856
 $6,163,744
 $6,113,567
Accumulated provision for depreciation (2,269,628) (2,210,781) (2,183,261) (2,155,783)
In service - net 3,927,532
 3,893,075
 3,980,483
 3,957,784
Construction work in progress 501,550
 480,259
 556,498
 552,499
Held for future use 4,689
 4,751
 3,697
 3,872
Electric plant - net 4,433,771
 4,378,085
 4,540,678
 4,514,155
Investments and Other Property 80,792
 90,019
 89,662
 87,104
Current Assets:        
Cash and cash equivalents 140,130
 165,460
 32,420
 98,950
Receivables:        
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
Customer (net of allowance of $2,168 and $1,401, respectively) 67,895
 72,675
Other (net of allowance of $268 and $343, respectively) 13,860
 17,107
Income taxes receivable —
 11,829
 —
 9,279
Accrued unbilled revenues 73,226
 69,318
 53,973
 64,545
Materials and supplies (at average cost) 58,441
 54,987
 60,020
 56,660
Fuel stock (at average cost) 55,973
 47,979
 59,188
 57,448
Prepayments 16,898
 16,374
 21,946
 17,520
Current regulatory assets 53,660
 48,707
 56,826
 56,626
Other 4,285
 3,655
 14
 405
Total current assets 499,513
 502,693
 366,142
 451,215
Deferred Debits:        
Company-owned life insurance 59,726
 59,852
 59,972
 58,922
Regulatory assets 1,195,079
 1,165,467
 1,341,052
 1,326,433
Other 56,371
 58,284
 56,195
 56,330
Total deferred debits 1,311,176
 1,283,603
 1,457,219
 1,441,685
Total $6,325,252
 $6,254,400
 $6,453,701
 $6,494,159


The accompanying notes are an integral part of these statements.
Table of Contents

Idaho Power Company
Condensed Consolidated Balance Sheets
(unaudited)
 
 June 30,
2019		 December 31,
2018		 March 31,
2020		 December 31,
2019
 (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 1,438,019
 1,409,245
 1,506,629
 1,503,805
Accumulated other comprehensive loss (21,868) (22,844) (35,537) (36,284)
Total common stock equity 2,224,189
 2,194,439
 2,279,130
 2,275,559
Long-term debt 1,835,521
 1,834,788
 1,837,010
 1,736,659
Total capitalization 4,059,710
 4,029,227
 4,116,140
 4,012,218
Current Liabilities:        
Current maturities of long-term debt —
 100,000
Accounts payable 80,530
 110,597
 67,542
 110,581
Accounts payable to affiliates 2,315
 2,088
 2,605
 2,053
Taxes accrued 25,553
 11,750
 24,648
 11,481
Interest accrued 23,599
 23,622
 20,837
 20,999
Accrued compensation 39,435
 54,910
 31,736
 52,267
Current regulatory liabilities 67,458
 25,883
 46,009
 33,987
Advances from customers 37,401
 20,037
 32,668
 28,452
Other 14,971
 10,198
 18,920
 15,629
Total current liabilities 291,262
 259,085
 244,965
 375,449
Deferred Credits:        
Deferred income taxes 744,674
 753,239
 792,059
 794,402
Regulatory liabilities 750,811
 738,994
 741,141
 748,198
Pension and other postretirement benefits 433,725
 431,475
 515,626
 519,570
Other 45,070
 42,380
 43,770
 44,322
Total deferred credits 1,974,280
 1,966,088
 2,092,596
 2,106,492
        
Commitments and Contingencies 

 

 

 

        
Total $6,325,252
 $6,254,400
 $6,453,701
 $6,494,159
        
The accompanying notes are an integral part of these statements.
Table of Contents


Idaho Power Company
Condensed Consolidated Statements of Cash Flows
(unaudited)
 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2020 2019
 (in thousands) (in thousands)
Operating Activities:        
Net income $92,760
 $96,493
 $36,776
 $41,584
Adjustments to reconcile net income to net cash provided by operating activities:   
  
   
  
Depreciation and amortization 85,355
 83,007
 43,505
 43,212
Deferred income taxes and investment tax credits (5,919) (9,505) (1,207) (4,137)
Changes in regulatory assets and liabilities 31,643
 45,691
 (9,672) 19,540
Pension and postretirement benefit plan expense 13,894
 14,038
 7,260
 6,965
Contributions to pension and postretirement benefit plans (14,633) (24,516) (12,270) (12,410)
Earnings of equity-method investments (4,265) (4,825) (2,453) (2,231)
Distributions from equity-method investments 11,800
 11,300
 2,000
 7,700
Allowance for equity funds used during construction (13,054) (12,018) (7,272) (6,356)
Other non-cash adjustments to net income, net (744) (220) 867
 77
Change in:  
  
  
  
Accounts receivable (9,137) (4,884) 4,161
 (24,378)
Accounts payable (44,180) (27,256) (49,344) (44,631)
Taxes accrued/receivable 25,632
 37,472
 22,446
 16,802
Other current assets (16,447) (16,145) 1,297
 9,132
Other current liabilities 9,432
 9,099
 5,207
 3,843
Other assets (1,482) (5,439) (1,935) (957)
Other liabilities 1,083
 (1,363) (180) 692
Net cash provided by operating activities 161,738
 190,929
 39,186
 54,447
Investing Activities:  
  
  
  
Additions to utility plant (129,860) (133,584) (73,566) (61,330)
Payments received from transmission project joint funding partners 1,016
 20,323
 393
 695
Proceeds from the sale of emission allowances and renewable energy certificates 3,702
 1,650
Purchase of equity securities (470) (228) (3,230) (240)
Proceeds from the sale of equity securities 2,546
 2,450
 839
 1,313
Other (2) 440
 3,796
 2,830
Net cash used in investing activities (123,068) (108,949) (71,768) (56,732)
Financing Activities:  
  
  
  
Issuance of long-term debt —
 220,000
Retirement of long-term debt —
 (130,000)
Dividends on common stock (63,986) (59,949) (33,952) (32,054)
Make-whole premium on retirement of long-term debt —
 (4,607)
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
Other 4
 —
Net cash used in financing activities (33,948) (32,054)
Net decrease in cash and cash equivalents (66,530) (34,339)
Cash and cash equivalents at beginning of the period 165,460
 44,646
 98,950
 165,460
Cash and cash equivalents at end of the period $140,130
 $149,150
 $32,420
 $131,121
Supplemental Disclosure of Cash Flow Information:  
  
  
  
Cash received from IDACORP related to income taxes $2,244
 $—
 $(9,189) $—
Cash paid for interest (net of amount capitalized) 42,172
 39,467
 19,888
 22,866
Non-cash investing activities:        
Additions to property, plant and equipment in accounts payable $26,700
 $20,650
 $22,843
 $23,690

The accompanying notes are an integral part of these statements.
Table of Contents

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

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

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

Financial Statements
 
In the opinion of management of IDACORP and Idaho Power, the accompanying unaudited condensed consolidated financial statements contain all adjustments necessary to present fairly each company's consolidated financial position as of June 30, 2019,March 31, 2020, consolidated results of operations for the three and six months ended June 30,March 31, 2020 and 2019, and 2018, and consolidated cash flows for the sixthree months ended June 30, 2019March 31, 2020 and 2018.2019. These adjustments are of a normal and recurring nature. These financial statements do not contain the complete detail or note disclosures concerning accounting policies and other matters that would be included in full-year financial statements and should be read in conjunction with the audited consolidated financial statements included in IDACORP’s and Idaho Power’s Annual Report on Form 10-K for the year ended December 31, 2018 (20182019 (2019 Annual Report). The results of operations for the interim period are not necessarily indicative of the results to be expected for the full year. A change in management's estimates or assumptions could have a material impact on IDACORP's or Idaho Power's respective financial condition and results of operations during the period in which such change occurred.
 
Management Estimates
 
Management makes estimates and assumptions when preparing financial statements in conformity with generally accepted accounting principles. These estimates and assumptions include those related to rate regulation, retirement benefits, contingencies, asset impairment, income taxes, unbilled revenues, and bad debt. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. These estimates involve judgments
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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 FebruaryJune 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2016-02,2016-13, LeasesFinancial Instruments-Credit Losses (Topic 842),326): Measurement of Credit Losses on Financial Instruments intended to improveprovide financial reportingstatement users with more information about expected credit losses on leasing transactions.financial instruments and other commitments. The ASU requires lessees to recognize a right-of-use asset and lease liability on the balance sheet for most leases. In addition, the ASU revises the definitionincurred loss impairment methodology to reflect current expected credit losses and requires consideration of a lease in regardsbroader range of information to when an arrangement conveys the right to control the use of the identified asset under the arrangement.estimate credit losses. IDACORP and Idaho Power adopted ASU 2016-022016-13 on January 1, 2019.2020. The adoption did not have a material impact on their respective financial statements. Neither IDACORP nor Idaho Power has material agreements that meetstatements but did result in the definition of a lease under ASU 2016-02.additional disclosure below.

Recent Accounting Pronouncements Not Yet AdoptedThe measurement of expected credit losses on Idaho Power accounts receivable is based upon historical experience, current conditions, and forecasted information that may affect collections on the outstanding balance. Generally, this includes adjustments based upon a combination of historical write-off experience, aging of accounts receivable, an analysis of specific customer accounts, and an evaluation of whether there are current or forecasted economic conditions that might cause variation in collection from the historical experience. In response to the COVID-19 public health crisis, Idaho Power provided certain relief to customers including temporarily suspending disconnections for homes and small businesses facing hardship because of the coronavirus pandemic and temporarily waiving late fees for residential and small business customers. Idaho Power currently anticipates that this relief as well as the economic conditions created by the response to the COVID-19 public health crisis will increase late payments and uncollectible account write-offs. As a result, Idaho Power increased its allowance for uncollectible accounts related to customer receivables at March 31, 2020. The allowance for uncollectible accounts increased to 3.1 percent of the total customer receivables balance at March 31, 2020, compared with 1.9 percent at December 31, 2019, and 2.1 percent at March 31, 2019.

The following table provides a rollforward of the allowance for uncollectible accounts related to customer receivables for the three months ended March 31, 2020 and 2019 (in thousands):
  Three months ended
March 31,
  2020 2019
Balance at beginning of period $1,401
 $1,725
Additions to the allowance 983
 1,012
Write-offs, net of recoveries (216) (646)
Balance at end of period $2,168
 $2,091
Allowance for uncollectible accounts as a percentage of customer receivables 3.1% 2.1%


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 forrecognition of such implementation costs with the guidance on capitalizingaccounting for costs associated with developing or obtainingincurred to implement an internal-use software. The new standardsoftware solution. However, the balance sheet line item for presentation of capitalized implementation costs for a cloud computing arrangement that is effectivea service contract should be the same as that for interimthe prepayment of fees related to the same arrangement, while capitalized implementation costs for internal-use software solutions are often included in property, plant, and annual reporting periods beginning after December 15, 2019, with early adoption permitted.equipment as an intangible asset. IDACORP and Idaho Power are evaluating the impact ofadopted ASU 2018-15 on January 1, 2020. The adoption did not have a material impact on their respective financial statements.

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
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benefit) for the period is computed as the difference between the year-to-date amount reported for the previous interim period and the current period's year-to-date amount.

Income Tax Expense

The following table provides a summary of income tax expense for the sixthree months ended June 30,March 31, 2020 and 2019 and 2018 (in thousands): 
 IDACORP Idaho Power IDACORP Idaho Power
 2019 2018 2019 2018 2020 2019 2020 2019
Income tax at statutory rates (federal and state) $27,590
 $27,909
 $26,975
 $27,539
 $10,651
 $12,098
 $10,595
 $11,905
First mortgage bond redemption costs —
 (1,261) —
 (1,261)
Excess deferred income tax reversal (3,262) (3,880) (3,262) (3,880) (1,481) (1,631) (1,481) (1,631)
Other(1)
 (12,984) (12,770) (11,676) (11,902) (5,282) (6,151) (4,728) (5,608)
Income tax expense $11,344
 $9,998
 $12,037
 $10,496
 $3,888
 $4,316
 $4,386
 $4,666
Effective tax rate 10.6% 9.2% 11.5% 9.8% 9.4% 9.2% 10.7% 10.1%
(1) "Other" is primarily comprised of the net tax effect of Idaho Power's regulatory flow-through tax adjustments.

The increasedecrease in income tax expense for the sixthree months ended June 30, 2019,March 31, 2020, compared with the same period in 2018,2019, was primarily due to the tax deductionlower pre-tax earnings for bond redemption costs incurred in the second quarter of 2018.Idaho Power. On a net basis, Idaho Power’s estimate of its annual 20192020 regulatory flow-through tax adjustments is comparable to 2018.2019.

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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 result from 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, as described in Idaho and Oregon were filed during 2011 and Idaho Power filed large single-issue rate 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 reset its base-rate power supply expenses in the Idaho jurisdiction for purposes of updating the collection of costs through retail rates, 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 the 20182019 Annual Report.

Idaho Settlement Stipulations

In October 2014, the IPUC issued an order approving an extension, with modifications, of the terms of a December 2011 Idaho settlement stipulation for the period from 2015 through 2019, or until the terms are otherwise modified or terminated by order of the IPUC (October 2014 Idaho Earnings Support and Sharing Settlement Stipulation). A May 2018 Idaho settlement stipulation related to tax reform (May 2018 Idaho Tax Reform Settlement Stipulation) provides for the extension of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation beyond the initial termination date of December 31, 2019, with modified terms that became effective beginning January 1, 2020, related to the accumulated deferred investment tax credits (ADITC) and revenue sharing mechanism to become effective beginning January 1, 2020.mechanism. The October 2014 Idaho Earnings Support and Sharing Settlement Stipulation and the May 2018 Idaho Tax Reform Settlement Stipulation are described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 20182019 Annual Report and include provisions for the accelerated amortization of ADITC to help achieve a minimum 9.59.4 percent (9.4(9.5 percent after 2019)prior to 2020) return on year-end equity in the Idaho jurisdiction (Idaho ROE). In addition, under the May 2018 Idaho Tax Reform Settlement Stipulation, minimum Idaho ROE would revert back to 95 percent of the allowed return on equity in the next rate case. The settlement stipulations also provide for the potential sharing between Idaho Power and Idaho customers of Idaho-jurisdictional earnings in excess of 10.0 percent of Idaho ROE.

Based on its estimate of full-year 20192020 Idaho ROE, in both the secondfirst quarter and first six months of 2019,2020, Idaho Power recorded no0 additional ADITC amortization or provision against current revenues for sharing of earnings with customers for 20192020 under the October 2014May 2018 Idaho Earnings Support and SharingTax Reform Settlement Stipulation. DuringAccordingly, at March 31, 2020, the second quarter of 2018, Idaho Power reversed the $0.5full $45 million of additional ADITC remains available for future use. Idaho Power recorded 0 additional ADITC amortization recordedor provision against revenues for sharing of earnings with customers during the first quarter of 2018, as actual financial results exceeded2019, based on its then-current estimate of full-year 2019 Idaho Power's early estimates.ROE.

Idaho Power Cost Adjustment Mechanisms

In both its Idaho and Oregon jurisdictions, Idaho Power's power cost adjustment mechanisms address the volatility of power supply costs and provide for annual adjustments to the rates charged to its retail customers. The power cost adjustment
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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.

InOn April 15, 2020, Idaho Power filed an application with the IPUC requesting a $58.7 million net increase in Idaho-jurisdiction power cost adjustment (PCA) revenues, effective for the 2020-2021 PCA collection period from June 1, 2020 to May 31, 2021. The net increase in PCA revenues reflects a return to a more normal level of power supply costs as wholesale market energy prices have come down from unusually high levels reflected in last year's PCA. The reduction in market energy prices results in Idaho Power forecasting lower wholesale energy sales, which serve as an offset to power supply costs. The net increase in PCA revenues also reflects a forecasted reduction in low-cost hydroelectric generation. The existing PCA for the 2019-2020 collection period also includes $7.7 million in one-time customer benefits associated with revenue sharing and income tax reform benefits, which will expire at the end of the current PCA year (May 2020). As of the date of this report, the IPUC has not yet issued an order on the application.

Previously, in May 2019, the IPUC approvedissued an order approving a $50.1 million net decrease in Idaho-jurisdiction power cost adjustment (PCA) revenues,PCA rates, effective for the 2019-2020 PCA collection period from June 1, 2019, to May 31, 2020. The net decrease in PCA revenues reflectsreflected 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 aincluded the $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 $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 included 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 hydropower available to reduce net power supply costs. 

Idaho Fixed Cost Adjustment Mechanism

The Idaho jurisdiction fixed cost adjustment (FCA) mechanism, applicable to Idaho residential and small general service customers, is designed to remove a portion of Idaho Power’s financial disincentive to invest in energy efficiency programs by separating (or decoupling) the recovery of fixed costs from the variable kilowatt-hour charge and linking it instead to a set amount per customer. Under Idaho Power's current rate design, Idaho Power recovers a portion of fixed costs through the variable kilowatt-hour charge, which may result in over-collection or under-collection of fixed costs. To return over-collection to customers or to collect under-collection from customers, the FCA mechanism allows Idaho Power to accrue, or defer, the difference between the authorized fixed-cost recovery amount per customer and the actual fixed costs per customer recovered by Idaho Power during the year. AnyThe IPUC has discretion to cap the 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 March 2020, Idaho Power filed its annual FCA update with the IPUC requesting an increase of $0.7 million in recovery from the FCA from $34.8 million to $35.5 million, with new rates effective for the period from June 1, 2020 to May 31, 2021. Previously, in May 2019, the IPUC approvedissued an order approving 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 rates effective for the period from June 1, 2018 to May 31, 2019.

Valmy Exit Agreement and Base Rate Adjustment Approval RequestDeferred Costs for COVID-19 Public Health Crisis

In February 2019,March and April 2020, Idaho Power reached an agreementsubmitted applications to the OPUC and IPUC, respectively, requesting authorization to defer any incremental costs associated with NV Energyits response to the COVID-19 public health crisis. Idaho Power may incur significant costs in its response to the public health emergency. These costs may include higher than average levels of write-offs of uncollectible accounts associated with its suspension of disconnects and late payment fees, and other additional costs that facilitatesIdaho Power cannot predict as of the planned enddate of this report given the unprecedented nature of this public health emergency. Revenues that are designed to recover Idaho Power's participationnormal business costs could be reduced significantly due to the impact of and response to the COVID-19 public health crisis, which has caused shutdowns or slowdowns of many commercial and industrial businesses throughout Idaho Power's service area in coal-fired operationspart due to state and local stay-in-place orders. Accordingly, Idaho Power requested authorization to establish a new regulatory asset to record the deferral of any incremental costs and, in the Idaho jurisdiction, unrecovered costs associated with the COVID-19 response. Both applications request only the authority to defer these costs and to determine ratemaking treatment at units 1a later date. Subsequent to Idaho Power's application and 2 of its jointly-owned North Valmy coal-fired power plant (Valmy Plant) in 2019 and 2025, respectively. In May 2019,other public utilities' similar applications, the IPUC staff 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, effective June 1, 2019 through December 31, 2028.

In July 2019, Idaho Power filed an application with the OPUC requestinga decision memorandum recommending that the OPUC approve the Valmy Plant agreementIPUC open a general docket to address whether and authorizeto what extent Idaho Powerpublic utilities should be authorized to adjust customer rates in Oregon, effective January 1, 2020, to reflectdefer incremental COVID-19-related expenses into a decrease in annual levelized revenue requirement of $3.2 million.regulatory asset for possible future recovery. As of the date of this report, the application remains pending.Idaho Power has not received authorization in either jurisdiction and has not deferred any such costs.
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4. REVENUES
 
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,March 31, 2020 and 2019 and 2018 (in thousands):
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Electric utility operating revenues:            
Revenue from contracts with customers $307,779
 $331,298
 $643,180
 $620,871
 $270,184
 $335,402
Alternative revenue programs and other revenues 7,995
 7,401
 22,366
 27,289
 20,304
 14,369
Total electric utility operating revenues $315,774
 $338,699
 $665,546
 $648,160
 $290,488
 $349,771


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Revenues from Contracts with Customers

The following table presents revenues from contracts with customers disaggregated by revenue source for the three and six months ended June 30,March 31, 2020 and 2019 and 2018 (in thousands):
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Revenues from contracts with customers:            
Retail revenues:            
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
Residential (includes $15,710 and $11,309, respectively, related to the FCA)(1)
 $144,887
 $150,219
Commercial (includes $484, and $342, respectively, related to the FCA)(1)
 69,513
 73,106
Industrial 45,602
 48,868
 91,100
 94,660
 42,760
 45,498
Irrigation 48,954
 65,065
 49,953
 65,471
 1,375
 999
Deferred revenue related to HCC relicensing AFUDC(2)
 (1,927) (1,462) (4,046) (4,046) (2,119) (2,119)
Total retail revenues 268,399
 298,591
 536,102
 563,114
 256,416
 267,703
Less: FCA mechanism revenues(1)
 (7,582) (5,799) (19,234) (19,704) (16,194) (11,651)
Wholesale energy sales 16,158
 8,919
 63,373
 22,685
 3,908
 47,215
Transmission wheeling-related revenues 12,518
 14,500
 28,246
 26,198
 10,363
 15,728
Energy efficiency program revenues 11,458
 8,802
 21,570
 16,399
 9,475
 10,112
Other revenues from contracts with customers 6,828
 6,285
 13,123
 12,179
 6,216
 6,295
Total revenues from contracts with customers $307,779
 $331,298
 $643,180
 $620,871
 $270,184
 $335,402
(1) The FCA mechanism is an alternative revenue program in the Idaho jurisdiction and does not represent revenue from contracts with customers.
(2) As part of its January 30, 2009, general rate case order, the IPUC is allowing Idaho Power to recover a portion of the allowance for funds used during construction (AFUDC) on construction work in progress related to the Hells Canyon Complex (HCC) relicensing process, even though the relicensing process is not yet complete and the costs have not been moved to electric plant in service. Idaho Power is collecting $8.8 million annually in the Idaho jurisdiction but is deferring revenue recognition of the amounts collected until the license is issued and the accumulated license costs approved for recovery are placed in service.

Alternative Revenue Programs and Other Revenues

While revenues from contracts with customers make up most of Idaho Power’s revenues, the IPUC has authorized the use of an additional regulatory mechanism, the Idaho FCA mechanism, which may increase or decrease tariff-based rates billed to customers.customer rates. The Idaho FCA mechanism is described in "NoteNote 3 - Regulatory"Regulatory Matters." The FCA mechanism revenues include only the initial recognition of FCA revenues when revenuesthey meet the regulator-specified conditions for recognition. Revenue from contracts with customers excludes the portion of the tariff price representing FCA revenues that Idaho Power initially recorded in prior periods when revenues met regulator-specified conditions. When Idaho Power includes those amounts in the price of utility service billed to customers, Idaho Power records such amounts as recovery of the associated regulatory asset or liability and not as revenues.

Derivative revenues include gains from settled electricity swaps and sales of electricity under forward sales contracts that are bundled with renewable energy credits. Related to these forward sales, Idaho Power simultaneously enters into forward
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purchases of electricity for the same quantity at the same location, which are recorded in purchased power on the condensed consolidated statements of income. For more information on settled electricity swaps, see Note 11 - "Derivative Financial Instruments."

The table below presents the FCA mechanism revenues and other revenues for the three and six months ended June 30,March 31, 2020 and 2019 and 2018 (in thousands):
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Alternative revenue programs and other revenues:            
FCA mechanism revenues $7,582
 5,799
 $19,234
 $19,704
 $16,194
 $11,651
Derivative revenues 413
 1,602
 3,132
 7,585
 4,110
 2,718
Total alternative revenue programs and other revenues $7,995
 $7,401
 $22,366
 $27,289
 $20,304
 $14,369


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5. LONG-TERM DEBT

5.In April 2020, Idaho Power issued $230 million in principal amount of its 4.20 percent first mortgage bonds, secured medium term notes, Series K, maturing March 1, 2048. The bonds were issued at a reoffer yield of 3.422 percent, which resulted in a net premium of 13.0 percent and net proceeds to Idaho Power of $259.9 million. After this offering the aggregate principal amount of the 4.20 percent first mortgage bonds is $450 million.

Idaho Power intends to use a portion of the net proceeds of the April 2020 sale of first mortgage bonds to satisfy its obligations at or prior to maturity of $100 million in principal amount of 3.40 percent first mortgage bonds due in November 2020. As a result, the $100 million in principal amount of 3.40 percent first mortgage bonds due in November 2020 are reported as long-term debt in the condensed consolidated balance sheets at March 31, 2020.

As of the date of this report, $270 million in principal amount of long-term debt securities remained available for issuance pursuant to state regulatory authority.

6. COMMON STOCK
 
IDACORP Common Stock
 
During the sixthree months ended June 30, 2019,March 31, 2020, IDACORP granted 70,41975,030 restricted stock unit awards to employees, and issued 6,3966,828 shares of common stock to directors, but made no original issuances ofand issued 33,919 shares of common stock using market purchases 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 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, 2019,March 31, 2020, the leverage ratios for IDACORP and Idaho Power were 43 percent and 45 percent, respectively. Based on these restrictions, IDACORP’s and Idaho Power’s dividends were limited to $1.4$1.5 billion and $1.2$1.3 billion, respectively, at June 30, 2019.March 31, 2020. There are additional facility covenants, subject to exceptions, that prohibit or restrict the sale or disposition of property without consent and any agreements restricting dividend payments to IDACORP and Idaho Power from any material subsidiary. At June 30, 2019,March 31, 2020, IDACORP and Idaho Power were in compliance with those financial covenants.
 
Idaho Power’s Revised Code of Conduct relating to transactions between and among Idaho Power, IDACORP, and other affiliates, which was approved by the IPUC in April 2008, provides that Idaho Power will not pay any dividends to IDACORP that will reduce Idaho Power’s common equity capital below 35 percent of its total adjusted capital without IPUC approval. At June 30, 2019,March 31, 2020, Idaho Power's common equity capital was 55 percent of its total adjusted capital. Further, Idaho Power must
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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 no0 preferred stock outstanding.

In addition to contractual restrictions on the amount and payment of dividends, the Federal Power Act (FPA) prohibits the payment of dividends from "capital accounts." The term "capital account" is undefined in the FPA or its regulations, but Idaho Power does not believe the restriction would limit Idaho Power's ability to pay dividends out of current year earnings or retained earnings.
 
6.7. 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,March 31, 2020 and 2019 and 2018 (in thousands, except for per share amounts).
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Numerator:  
  
  
  
  
  
Net income attributable to IDACORP, Inc. $53,156
 $62,288
 $95,842
 $98,430
 $37,490
 $42,686
Denominator:  
  
      
  
Weighted-average common shares outstanding - basic 50,499
 50,435
 50,504
 50,430
 50,517
 50,509
Effect of dilutive securities 8
 46
 8
 42
 10
 9
Weighted-average common shares outstanding - diluted 50,507
 50,481
 50,512
 50,472
 50,527
 50,518
Basic earnings per share $1.05
 $1.24
 $1.90
 $1.95
 $0.74
 $0.85
Diluted earnings per share $1.05
 $1.23
 $1.90
 $1.95
 $0.74
 $0.84


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7.8. COMMITMENTS
 
Purchase Obligations
 
During the sixthree months ended June 30, 2019,March 31, 2020, IDACORP's and Idaho Power's contractual obligations, outside the ordinary course of business, did not change materially from the amounts disclosed in the notes to the consolidated financial statements in the 20182019 Annual Report, except that Idaho Power entered into foureight new replacement contracts for expiring power purchase agreements with hydropower and cogeneration PURPA-qualifying facilities, and one new agreement with a solar PURPA-qualifying facility, which increased Idaho Power's contractual purchase obligations by approximately $24$22 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 $58.3 million at June 30, 2019,March 31, 2020, representing IERCo's one-third share of BCC's total reclamation obligation of $175.0 million. BCC has a reclamation trust fund set aside specifically for the purpose of paying these reclamation costs. At June 30, 2019,March 31, 2020, the value of BCC's reclamation trust fund was $125.9$119.5 million. During the sixthree months ended June 30, 2019,March 31, 2020, the reclamation trust fund made no0 distributions for reclamation activity costs associated with the BCC surface mine. BCC periodically assesses the adequacy of the reclamation trust fund and its estimate of future reclamation costs. To ensure that the reclamation trust fund maintains adequate reserves, BCC has the ability to, and does, add a per-ton surcharge to coal sales, all of which are made to the Jim Bridger plant. Because of the existence of the fund and the ability to apply a per-ton surcharge, the estimated fair value of this guarantee is minimal.

In May 2019, the state of Wyoming enacted legislation that limits a mine operator's maximum amount of self-bonding. Idaho Power and the co-owners of BCC have 18 monthsuntil December 2020 to comply with the new regulations, which would reduce the portion of Idaho Power's guarantee of reclamation activities and obligations at BCC that Idaho Power is allowed to self-bond. 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.
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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, 2019,March 31, 2020, 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.

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

9.
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10. 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,(together, SMSP). Idaho Power also has a nonqualified defined benefit pension plan for directors that was frozen in 2002. Remaining vested benefits from that plan are included with the SMSP in the disclosures below. The benefits under the pension plan are based on years of service and the employee’s final average earnings. Idaho Power also maintains a defined benefit postretirement benefit plan (consisting of health care and death benefits) that covers all employees who were enrolled in the active-employee group plan at the time of retirement as well as their spouses and qualifying dependents. The table below shows the components of net periodic benefit costs for the pension, SMSP, and postretirement benefits plans for the three months ended June 30,March 31, 2020 and 2019 and 2018 (in thousands).
 Pension Plan SMSP Postretirement
Benefits		 Total Pension Plan SMSP Postretirement
Benefits		 Total

2019
2018
2019
2018
2019
2018 2019 2018
2020
2019
2020
2019
2020
2019 2020 2019
Service cost
$8,316

$9,742

$(45)
$(79)
$196

$242
 $8,467
 $9,905

$10,915

$8,714

$53

$(45)
$274

$231
 $11,242
 $8,900
Interest cost
10,560

9,683

1,145

1,061

762

656
 12,467
 11,400

10,018

10,596

1,088

1,143

614

732
 11,720
 12,471
Expected return on plan assets
(12,187)
(13,056)
—

—

(557)
(605) (12,744) (13,661)
(14,030)
(12,124)
—

—

(605)
(553) (14,635) (12,677)
Amortization of prior service cost
2

2

24

25

12

12
 38
 39

2

1

72

24

12

12
 86
 37
Amortization of net loss
3,302

3,394

633

947

—

—
 3,935
 4,341

4,367

3,480

934

633

—

—
 5,301
 4,113
Net periodic benefit cost
9,993

9,765

1,757

1,954

413

305
 12,163
 12,024

11,272

10,667

2,147

1,755

295

422
 13,714
 12,844
Regulatory deferral of net periodic benefit cost(1)

(9,523)
(9,309)
—
 —
 —
 —
 (9,523) (9,309)
(10,742)
(10,167)
—
 —
 —
 —
 (10,742) (10,167)
Previously deferred pension costs recognized(1)
 4,289
 4,289
 —
 —
 —
 —
 4,289
 4,289
 4,288
 4,288
 —
 —
 —
 —
 4,288
 4,288
Net periodic benefit cost recognized for financial reporting(1)(2)

$4,759

$4,745

$1,757

$1,954

$413

$305
 $6,929
 $7,004

$4,818

$4,788

$2,147

$1,755

$295

$422
 $7,260
 $6,965
 (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$4.3 million and $4.1$4.2 million, respectively, were recognized in "Other operations and maintenance" and $2.7$3.0 million and $2.9$2.8 million, respectively, were recognized in "Other expense, net" on the condensed consolidated statements of income of the companies for the three months ended June 30, 2019March 31, 2020 and 2018.

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The 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, 2019 and 2018 (in thousands).
  Pension Plan SMSP Postretirement
Benefits		 Total
  2019 2018 2019 2018 2019 2018 2019 2018
Service cost $17,030
 $19,485
 $(90) $(158) $427
 $526
 $17,367
 $19,853
Interest cost 21,156
 19,365
 2,288
 2,124
 1,494
 1,322
 24,938
 22,811
Expected return on plan assets (24,311) (26,111) —
 —
 (1,110) (1,234) (25,421) (27,345)
Amortization of prior service cost 3
 3
 48
 49
 24
 24
 75
 76
Amortization of net loss 6,782
 6,788
 1,266
 1,894
 —
 —
 8,048
 8,682
Net periodic benefit cost 20,660
 19,530
 3,512
 3,909
 835
 638
 25,007
 24,077
Regulatory deferral of net periodic benefit cost(1)
 (19,690) (18,616) —
 —
 —
 —
 (19,690) (18,616)
Previously deferred pension costs recognized(1)
 8,577
 8,577
 —
 —
 —
 —
 8,577
 8,577
Net periodic benefit cost recognized for financial reporting(1)(2) $9,547
 $9,491
 $3,512
 $3,909
 $835
 $638
 $13,894
 $14,038
 (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, $8.4 million and $8.2 million, respectively, were recognized in "Other operations and maintenance" and $5.5 million and $5.8 million, respectively, were recognized in "Other expense, net" on the condensed consolidated statements of income of the companies for the six months ended June 30, 2019 and 2018.2019.

Idaho Power has noa $14 million minimum contribution requirement to its defined benefit pension plan in 2019. However, during2020. During the sixthree months ended June 30, 2019,March 31, 2020, Idaho Power made $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.

10.11. 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
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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,March 31, 2020 and 2019 and 2018 (in thousands).
 
Gain/(Loss) on Derivatives Recognized in Income(1)
 
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,		 Location of Realized Gain/(Loss) on Derivatives Recognized in Income Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Financial swaps Operating revenues $414
 $27
 $(2,789) $266
 Operating revenues $826
 $(3,203)
Financial swaps Purchased power (56) 13
 687
 (189) Purchased power (190) 743
Financial swaps Fuel expense 7
 (112) 12,402
 (800) Fuel expense (2,848) 12,395
Financial swaps Other operations and maintenance —
 31
 —
 38
Forward contracts Operating revenues —
 —
 64
 2
 Operating revenues 79
 64
Forward contracts Purchased power —
 (7) (64) (20) Purchased power (76) (64)
Forward contracts Fuel expense —
 10
 416
 24
 Fuel expense (19) 416

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

Settlement gains and losses on electricity swap contracts are recorded on the income statement in operating revenues or purchased power depending on the forecasted position being economically hedged by the derivative contract. Settlement gains and losses on contracts for natural gas are reflected in fuel expense. Settlement gains and losses on diesel derivatives are recorded in other operations and maintenance expense. See Note 1112 - "Fair Value Measurements" for additional information concerning the determination of fair value for Idaho Power’s assets and liabilities from price risk management activities.

Credit Risk
 
At June 30, 2019,March 31, 2020, Idaho Power did not have material credit risk exposure from financial instruments, including derivatives. Idaho Power monitors credit risk exposure through reviews of counterparty credit quality, corporate-wide counterparty credit exposure, and corporate-wide counterparty concentration levels. Idaho Power manages these risks by establishing credit and concentration limits on transactions with counterparties and requiring contractual guarantees, cash deposits, or letters of credit from counterparties or their affiliates, as deemed necessary. Idaho Power’s physical power, 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 usuallygenerally under International Swaps and Derivatives Association, Inc.standardized industry contracts. These contracts contain adequate assurance clauses requiring collateralization if a counterparty has debt that is downgraded below investment grade by at least one rating agency.

Credit-Contingent Features
 
Certain Idaho Power derivative instruments contain provisions that require Idaho Power's unsecured debt to maintain an investment grade credit rating from Moody's Investors Service and Standard & Poor's Ratings Services. If Idaho Power's unsecured debt were to fall below investment grade, it would be in violation of these provisions, and the counterparties to the derivative instruments could request immediate payment or demand immediate and ongoing full overnight collateralization on derivative instruments in net liability positions. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position at June 30, 2019,March 31, 2020, was $4.6$4.8 million. Idaho Power posted $1.8$3.6 million cash collateral related to this amount. If the credit-risk-related contingent features underlying these agreements were triggered on June 30, 2019,March 31, 2020, Idaho Power would have been required to pay or post collateral to its counterparties up to an additional $4.6$3.5 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

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, 2019,March 31, 2020, and December 31, 20182019 (in thousands).
 Asset Derivatives Liability Derivatives 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            
March 31, 2020            
Current:    
      
    
    
      
    
Financial swaps Other current assets $5,003
 $(915) $4,088
 $915
 $(915) $—
 Other current assets $14
 $—
 $14
 $—
 $—
 $—
Financial swaps Other current liabilities 173
 (173) —
 2,940
 (173) 2,767
 Other current liabilities 891
 (891) —
 4,812
 (2,868)
(1) 
1,944
Forward contracts Other current assets 197
 —
 197
 —
 —
 —
 Other current liabilities —
 —
 —
 1
 —
 1
Long-term:    
              
          
Financial swaps Other liabilities 71
 (71) —
 746
 (71) 675
 Other assets 407
 —
 407
 —
 —
 —
Total   $5,444
 $(1,159) $4,285
 $4,601
 $(1,159) $3,442
   $1,312
 $(891) $421
 $4,813
 $(2,868) $1,945
       
             
      
December 31, 2018     

      
December 31, 2019     

      
Current:          
              
    
Financial swaps Other current assets $4,639
 $(984)
(1) 
$3,655
 $938
 $(938) $—
 Other current assets $2,426
 $(2,034) $392
 $2,034
 $(2,034) $—
Financial swaps Other current liabilities —
 —
 —
 806
 —
 806
 Other current liabilities 134
 (134) —
 924
 (134) 790
Forward contracts Other current liabilities —
 —
 —
 104
 —
 104
 Other current assets 13
 —
 13
 —
 —
 —
Forward contracts Other current liabilities —
 —
 —
 32
 —
 32
Long-term:    
      
        
      
    
Financial swaps Other assets —
 —
 —
 64
 —
 64
 Other assets 3
 (3) —
 27
 (3) 24
Total   $4,639
 $(984) $3,655
 $1,912
 $(938) $974
   $2,576
 $(2,171) $405
 $3,017
 $(2,171) $846

(1) Current assetliability derivative amounts offset include $45 thousand$2.0 million of collateral payablereceivable for the period ending Decemberended March 31, 2018.2020.

The table below presents the volumes of derivative commodity forward contracts and swaps outstanding at June 30,March 31, 2020 and 2019 and 2018 (in thousands of units).
 June 30, March 31,
Commodity Units 2019 2018 Units 2020 2019
Electricity purchases MWh 216
 323
 MWh 136
 194
Electricity sales MWh 106
 58
 MWh 125
 116
Natural gas purchases MMBtu 13,980
 12,371
 MMBtu 12,220
 9,596
Natural gas sales MMBtu 308
 233
 MMBtu 375
 338
Diesel purchases Gallons —
 451


11.12. 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.
 
•      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 no0 transfers between levels or material changes in valuation techniques or inputs during the sixthree months ended June 30, 2019.March 31, 2020.

The table below presents information about IDACORP’s and Idaho Power’s assets and liabilities measured at fair value on a recurring basis as of June 30, 2019,March 31, 2020, and December 31, 20182019 (in thousands).
 June 30, 2019 December 31, 2018 March 31, 2020 December 31, 2019
 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total 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
 $52,745
 $—
 $—
 $52,745
 $64,173
 $—
 $—
 $64,173
Idaho Power 30,981
 —
 —
 30,981
 79,228
 —
 —
 79,228
 13,275
 —
 —
 13,275
 26,510
 —
 —
 26,510
Derivatives 4,088
 197
 —
 4,285
 3,655
 —
 —
 3,655
 421
 —
 —
 421
 392
 13
 —
 405
Equity securities 34,795
 —
 —
 34,795
 36,488
 —
 —
 36,488
 44,843
 —
 —
 44,843
 42,738
 —
 —
 42,738
Liabilities:                                
Derivatives 3,442
 —
 —
 3,442
 870
 104
 —
 974
 1,944
 1
 —
 1,945
 814
 32
 —
 846

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

Idaho Power’s derivatives are contracts entered into as part of its management of loads and resources. Electricity derivatives are valued on the Intercontinental Exchange (ICE) with quoted prices in an active market. Natural gas and diesel derivatives are valued using New York Mercantile Exchange (NYMEX) and Intercontinental Exchange (ICE)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, 2019,March 31, 2020, and December 31, 2018,2019, using available market information and appropriate valuation methodologies (in thousands).
 June 30, 2019 December 31, 2018 March 31, 2020 December 31, 2019
 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value
IDACORP  
  
  
  
  
  
  
  
Assets:  
  
  
  
  
  
  
  
Notes receivable(1)
 $3,804
 $3,804
 $3,804
 $3,804
 $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
 1,837,010
 2,153,743
 1,836,659
 2,083,931
Idaho Power  
  
  
  
  
  
  
  
Liabilities:  
  
  
  
  
  
  
  
Long-term debt(1)
 1,835,521
 2,024,566
 1,834,788
 1,942,773
 1,837,010
 2,153,743
 1,836,659
 2,083,931

(1) Notes receivable and long-term debt are categorized as Level 3 and Level 2, respectively, of the fair value hierarchy, as defined earlier in this Note 1112 - "Fair Value Measurements."

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

12.13. SEGMENT INFORMATION
 
IDACORP’s only reportable segment is utility operations. The utility operations segment’s primary source of revenue is the regulated operations of Idaho Power. Idaho Power’s regulated operations include the generation, transmission, distribution, purchase, and sale of electricity. This segment also includes income from IERCo, a wholly-owned subsidiary of Idaho Power that is also subject to regulation and is a one-third owner of BCC, an unconsolidated joint venture.
 
IDACORP’s other operating segments are below the quantitative and qualitative thresholds for reportable segments and are included in the "All Other" category in the table below. This category is comprised of IFS’s investments in affordable housing developments and historic rehabilitation projects, Ida-West’s joint venture investments in small hydropower generation projects, and IDACORP’s holding company expenses.
 
The table below summarizes the segment information for IDACORP’s utility operations and the total of all other segments, and reconciles this information to total enterprise amounts (in thousands). 
 
Utility
Operations
 
All
Other
 Eliminations 
Consolidated
Total
 
Utility
Operations
 
All
Other
 Eliminations 
Consolidated
Total
Three months ended June 30, 2019:        
Three months ended March 31, 2020:        
Revenues $315,774
 $1,121
 $—
 $316,895
 $290,488
 $520
 $—
 $291,008
Net income attributable to IDACORP, Inc. 51,176
 1,980
 —
 53,156
 36,776
 714
 —
 37,490
Total assets as of June 30, 2019 6,325,252
 170,610
 (35,009) 6,460,853
Three months ended June 30, 2018:        
Total assets as of March 31, 2020 6,453,701
 229,440
 (73,191) 6,609,950
Three months ended March 31, 2019:        
Revenues $338,699
 $1,253
 $—
 $339,952
 $349,771
 $548
 $—
 $350,319
Net income attributable to IDACORP, Inc. 60,637
 1,651
 —
 62,288
 41,584
 1,102
 —
 42,686
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


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13.14. 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,March 31, 2020 and 2019 and 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
March 31,
 2019 2018 2019 2018 2020 2019
Balance at beginning of period $(22,356) $(30,243) $(22,844) $(30,964) $(36,284) $(22,844)
Amounts reclassified out of AOCI 488
 722
 976
 1,443
 747
 488
Balance at end of period $(21,868) $(29,521) $(21,868) $(29,521) $(35,537) $(22,356)

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,March 31, 2020 and 2019 and 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
March 31,
 2019 2018 2019 2018 2020 2019
Amortization of defined benefit pension items(1)
            
Prior service cost $24
 $25
 $48
 $49
 $72
 $24
Net loss 633
 947
 1,266
 1,894
 934
 633
Total before tax 657
 972
 1,314
 1,943
 1,006
 657
Tax benefit(2)
 (169) (250) (338) (500) (259) (169)
Total reclassification for the period, net of tax $488
 $722
 $976
 $1,443
 $747
 $488
(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.

14.15. 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,March 31, 2020 and 2019 and 2018 (in thousands).
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Balance at beginning of period $1,418,775
 $1,314,472
 $1,409,245
 $1,308,702
 $1,503,805
 $1,409,245
Net income 51,176
 60,637
 92,760
 96,493
 36,776
 41,584
Dividends to parent (31,932) (29,863) (63,986) (59,949) (33,952) (32,054)
Balance at end of period $1,438,019
 $1,345,246
 $1,438,019
 $1,345,246
 $1,506,629
 $1,418,775


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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, 2019March 31, 2020, the related condensed consolidated statements of income, comprehensive income, and equity, for the three-month and six-month periods ended June 30, 2019 and 2018, and of cash flows, for the six-monththree-month periods ended June 30,March 31, 2020 and 2019, and 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, 20182019, 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 21, 2019,20, 2020, 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, 20182019, 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 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 1, 2019April 30, 2020
 
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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, 2019,March 31, 2020, 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 of cash flows, for the six-monththree-month periods ended June 30,March 31, 2020 and 2019, and 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, 2018,2019, 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 21, 2019,20, 2020, 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, 2018,2019, 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 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 1, 2019April 30, 2020
 
 
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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 IDACORP's and Idaho Power's Annual Report on Form 10-K for the year ended December 31, 2018 (20182019 (2019 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 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,areas, 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 (Jim Bridger plant) owned in part by Idaho Power (Jim Bridger plant).Power. IDACORP’s other significant subsidiaries include IDACORP Financial Services, Inc., an investor in affordable housing and other real estate investments, and Ida-West Energy Company, an operator of small 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 20182019 Annual Report, IDACORP's and Idaho Power's management included a brief overview of their business strategies for the companies for 20192020 and beyond, under the heading "Executive 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 sixthree months of 2019,2020, Idaho Power's customer count grew by nearly 6,800over 3,100 customers, and for the twelve months ended June 30, 2019,March 31, 2020, the customer growth rate was 2.52.6 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$1.6 billion over the five-year period from 20192020 (including the expenditures incurred so far in 2019)2020) through 2023.2024.
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 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 properlymore closely reflect the cost to provide electric service.

In February 2019,April 2020, Idaho Power reached an agreement with NV Energy that facilitatesissued $230 million in principal amount of 4.20 percent first mortgage bonds due 2048. The bonds were issued at a reoffer yield of 3.422 percent, which resulted in a net premium of 13.0 percent and net proceeds to Idaho Power of approximately $260 million. Idaho Power intends to use a portion of the planned endbond proceeds for the redemption of $100 million of 3.40 percent first mortgage bonds due in November 2020. Idaho Power's participation in coal-firedPower believes the issuance helps maintain its strong liquidity position enabling it to fund its ongoing operations, at units 1capital expenditures, and 2dividend payments.
As of its jointly-owned North Valmy coal-fired power plant (Valmy Plant) in 2019April 24, 2020, based on available cash on hand and 2025, respectively. In May 2019, the IPUC issued an order approving the Valmy Plant agreementcredit facilities recently extended through 2024, IDACORP and allowing Idaho Power have approximately $200 million and $570 million of respective liquidity available for ongoing operations.

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Coronavirus (COVID-19) Response and Impacts

In response to the COVID-19 public health crisis, in the first quarter of 2020, Idaho Power implemented its emergency management, business continuity, and enterprise pandemic plans. Idaho Power's internal emergency management team responded in accordance with the plans in an effort to recoverensure Idaho Power continues to provide reliable service to its customers during the pandemic. In March 2020, the states of Oregon and Idaho declared that electric utilities are considered an "essential business," and Idaho Power's provision of electricity to customers through customer rates,its power supply, transmission, and distribution operations, as of the date of this report, continues largely uninterrupted. On April 23, 2020, the Governor of Idaho announced Idaho's plan to reopen its economy in stages provided that criteria are met as established by the Idaho Division of Public Health and the Governor's coronavirus working group. While the Governor of Oregon has announced a framework to reopen the state’s economy, Oregon has not announced final detailed timelines or plans as of the date of this report.

Idaho Power has taken proactive steps to protect employees, customers, the general public, and Idaho Power's electrical system. Idaho Power closed all of its operating facilities to the public, closed most Idaho Power recreation sites, upgraded information technology capabilities to facilitate remote working for over half of its workforce, eliminated substantially all in-person meetings and non-essential work travel, reviewed its supply chain for critical items, continued monitoring of cyber and physical security threats, tested critical information technology systems for business continuity purposes, enhanced cleaning procedures at all facilities, and encouraged employees to practice responsible social distancing and other effective June 1,prevention and safety measures. Idaho Power has a small number of highly specialized employees who are trained to operate the power grid and critical generation facilities. Idaho Power has been taking actions to help ensure the health and availability of those essential employees, including performing health screenings, alternating schedules, segregating employees into separate facilities, and limiting interaction. If the COVID-19 pandemic were to worsen, Idaho Power is preparing for the potential sequestration of those employees as a further measure for ensuring their health and safety and ability to perform their specialized functions.

Idaho Power has temporarily suspended disconnections and late fees for late payment or non-payment to provide temporary relief to residential and small commercial customers who may experience financial hardship related to the public health crisis. Commercial customers may be particularly impacted by stay-at-home orders in the service area, as the orders have temporarily disrupted operations of many of those customers, whereas Idaho Power expects that irrigation customers will be impacted to a lesser extent. As many of Idaho Power's larger commercial and industrial customers are in the agriculture and food-processing industry, COVID-19 could have a smaller impact on those customers given the importance of the food that they produce, and thus mitigate in part the overall energy usage decline from those customers. Further, to the extent other states have imposed stay-at-home and similar orders, transmission wheeling revenues could decrease due to overall decreases in energy loads in the western region, impacting energy prices and overall market activity regionally. Overall, Idaho Power anticipates that the stay-at-home orders and the disruption of economic activities in its service area and global economic conditions created by the response to the COVID-19 public health crisis will decrease energy usage and associated revenues, and also increase late payments and uncollectible account write-offs. In anticipation of the economic impact, Idaho Power increased its allowance for uncollectible receivables from $1.4 million at Decembers 31, 2019, to $2.2 million at March 31, 2020, based on Idaho Power's normal allowance estimation process combined with its estimate of the $1.2 millionvarious impacts of the health crisis.

In March and April 2020, Idaho Power submitted applications to the OPUC and IPUC, respectively, requesting authorization to defer any incremental annual levelized revenue requirementcosts and, in the Idaho jurisdiction, unrecovered costs associated with required Valmy Plant planned and actual investmentsits response to the COVID-19 public health crisis. Idaho Power may incur significant costs in its response to the public health emergency, which are described in Note 3 - "Regulatory Matters" to the condensed consolidated financial statements included in this report. Subsequent to Idaho Power's application and other exit costs.public utilities' similar applications, the IPUC staff issued a decision memorandum recommending that the IPUC open a general docket to address whether and to what extent Idaho public utilities should be authorized to defer incremental COVID-19-related expenses into a regulatory asset for possible future recovery.

In March 2020, President Trump signed into law the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) that provides numerous economic assistance and stimulus measures for individuals and businesses. Idaho Power does not expect the CARES Act to have a material effect on its financial results or liquidity.

As noted above, in April 2020, Idaho Power issued $230 million in principal amount of 4.20 percent first mortgage bonds due 2048. The bonds were issued at a reoffer yield of 3.422 percent, which resulted in a net premium of 13.0 percent and net proceeds to Idaho Power of approximately $260 million. While Idaho Power expected to issue debt securities during 2020 unrelated and prior to the COVID-19 public health crisis, the net proceeds from the issuance provide Idaho Power with additional liquidity should the financial impacts of the COVID-19 public health crisis worsen in the coming months or be prolonged.

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As of the date of this report, Idaho Power is uncertain how significantly the COVID-19 public health crisis will ultimately impact its business operations, results of operations, cash flows, financial condition, or capital resources. For a discussion of certain risks IDACORP and Idaho Power are confronting as a result of the public health crisis, see Part II - Item 1A - "Risk Factors" in this report.

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,March 31, 2020 and 2019 and 2018 (in thousands, except earnings per share amounts):
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Idaho Power net income $51,176
 $60,637
 $92,760
 $96,493
 $36,776
 $41,584
Net income attributable to IDACORP, Inc. $53,156
 $62,288
 $95,842
 $98,430
 $37,490
 $42,686
Average outstanding shares – diluted 50,507
 50,481
 50,512
 50,472
 50,527
 50,518
IDACORP, Inc. earnings per diluted share $1.05
 $1.23
 $1.90
 $1.95
 $0.74
 $0.84

The table below provides a reconciliation of net income attributable to IDACORP for the three and six months ended June 30, 2019,March 31, 2020, from the same period in 20182019 (items are in millions and are before related income tax impact unless otherwise noted).
 Three months ended Six months ended Three months ended
Net income attributable to IDACORP, Inc. - June 30, 2018   $62.3
   $98.4
Net income attributable to IDACORP, Inc. - March 31, 2019   $42.7
Increase (decrease) in Idaho Power net income:    
        
Customer growth, net of associated power supply costs and power cost adjustment mechanisms 4.2
  
 8.2
   3.6
  
Usage per retail customer, net of associated power supply costs and power cost adjustment mechanisms (13.4)   (10.4)   (6.1)  
Idaho fixed cost adjustment (FCA) revenues 1.8
   (0.5)   4.5
  
Retail revenues per MWh, net of associated power supply costs and power cost adjustment mechanisms (7.0)   (4.3)  
Retail revenues per megawatt-hour (MWh), net of associated power supply costs and power cost adjustment mechanisms
 (2.1)  
Transmission wheeling-related revenues (2.0)   2.0
   (5.4)  
Other operations and maintenance (O&M) expenses 5.3
   2.6
   (0.9)  
Other changes in operating revenues and expenses, net 0.2
   (0.9)   (0.2)  
Decrease in Idaho Power operating income (10.9)   (3.3)   (6.6)  
Earnings of equity-method investments 1.4
   (0.6)  
Non-operating income and expenses —
   1.7
   1.5
  
Income tax expense —
   (1.5)   0.3
  
Total decrease in Idaho Power net income   (9.5)   (3.7) 
 (4.8)
Other IDACORP changes (net of tax)   0.4
   1.1
 
 (0.4)
Net income attributable to IDACORP, Inc. - June 30, 2019   $53.2
   $95.8
Net income attributable to IDACORP, Inc. - March 31, 2020   $37.5

Net Income - Second Quarter 2019
IDACORP's net income decreased $9.1$5.2 million for the secondfirst quarter of 20192020 compared with the secondfirst quarter of 2018,2019, primarily due to lower net income at Idaho Power.
Customer growth increased operating income by $4.2$3.6 million in the secondfirst quarter of 20192020 compared with the secondfirst quarter of 2018,2019, as the number of Idaho Power customers grew by 2.5approximately 14,400, or 2.6 percent, during the twelve months ended June 30, 2019. SalesMarch 31, 2020. Lower sales volumes on a per-customer basis decreased operating income by $13.4$6.1 million in the secondfirst quarter of 2020 compared with the first quarter of 2019, compared with the second quarter of 2018. Greater precipitationas more moderate weather in Idaho Power's service area led agricultural irrigationresidential and commercial customers to use 20less energy for heating. Also, some Idaho Power commercial customers were negatively impacted by the COVID-19 public health crisis which, combined with the more moderate weather, caused commercial customers to use 5 percent less energy per customer to operate irrigation pumps. Also, residential andin March 2020 compared with March 2019. Idaho Power estimates that the effect on retail revenues of the lower usage per commercial customers used less energy per customer for cooling purposes, primarily due to cooler temperatures.the COVID-19 public health crisis was less than $1 million in the first quarter of 2020. The decrease in residential sales volumes per customer was mostly offset by the FCA mechanism (applicable to residential and small general service customers), which increased revenues in the first quarter by $1.8$4.5 million.
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The net decrease in retail revenues per megawatt-hour (MWh) decreased operating income by $7.0 million in the second quarter of 2019 compared with the second quarter of 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 of 2019 more significantly than in the second quarter of 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 lesser portion of the customer sales mix than industrial customers 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.

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.

Net Income - Year-to-Date 2019

IDACORP's net income decreased $2.6 million for the first half of 2019 compared with the same period of 2018, primarily due to lower net income at Idaho Power.
Customer growth increased operating income by $8.2 million in the first half of 2019 compared with the first half of 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 quarter of 2019 compared with the first quarter of 2018, as colder temperatures led residential customers to use more energy for heating.
The net decrease in retail revenues per MWh decreased operating income by $4.3$2.1 million in the first halfquarter of 20192020 compared with the first halfquarter of 2018, due primarily2019, partially caused by changes in customer mix, as volumes sold to residential customers in the effectsfirst quarter of 2020 made up a lesser portion of the settlement stipulations approvedcustomer sales mix compared with the first quarter of 2019. Residential customers generally pay a higher per-MWh rate than other customers. Also, the Idaho-jurisdiction PCA mechanism includes a cost or benefit ratio that allocates the deviations in certain net power supply expenses between customers (95 percent) and Idaho Power (5 percent). In the first quarter of 2019, net power supply expenses were reduced by the IPUCa significant amount of wholesale energy sales due to regional wholesale energy market conditions. Regional wholesale energy prices were elevated due to below normal regional temperatures, lack of energy imports due to equipment maintenance, and OPUCnatural gas pipeline disruptions. The higher wholesale energy prices during the secondfirst quarter of 2018 related2019 led to income tax reform noted above.greater wholesale energy sales by Idaho Power, of which 5 percent benefited Idaho Power.

During the first halfquarter of 2019, Idaho Power benefited from a $2.0 million increase in2020, transmission wheeling-related revenue,revenues decreased $5.4 million compared with the first halfquarter of 2018. This change2019. Idaho Power's open access transmission tariff (OATT) rates decreased approximately 13 percent in October 2019 and there was largely due to an increase in wheeling-related volumes driven byless regional wholesale energy market activity in the first quarter of 2020 compared with the first quarter of 2019 partially offset by a decrease in Idaho Power's OATT rates that became effective in October 2018.due to the market conditions noted above.

Other O&M expenses were $2.6$0.9 million lowerhigher in the first halfquarter of 20192020 compared with the first halfquarter of 2018. Other O&M expenses related2019, primarily due to Idaho Power's hydropower generation decreased $2.3 million, due primarily to fewer maintenance projects at hydropower locationsa slight increase in the first half of 2019. As provided by the settlement stipulation approved by the IPUC in 2018 related to income tax reform, O&M expenses in the first 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.labor and benefit costs.

Based on its estimate of full-year 20192020 return on year-end equity in the Idaho jurisdiction (Idaho ROE), in the first halfquarter of 2019,2020 Idaho Power recorded no additional accumulated deferred investment tax credits (ADITC) amortization or any provision against revenues for sharing of earnings with customers under the Idaho regulatory settlement stipulation approved in October 2014.May 2018.

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:

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as follows:

•
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 a regulatory settlement stipulationsstipulation in Idaho that includeincludes provisions for the accelerated amortization of certain tax credits to help achieve a minimum 9.59.4 percent (9.4 percent after 2019) Idaho ROE. The settlement stipulationsstipulation also provideprovides 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 andstipulation has no expiration date but the indefinite extensionminimum Idaho ROE would revert back to 95 percent of the mechanism beyondallowed return on equity in the original termination date of December 31, 2019.next rate case. The specific terms of thesethe settlement stipulations arestipulation is described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 20182019 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.

•
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 12twelve months ended June 30, 2019,March 31, 2020, Idaho Power's customer count grew by 2.52.6 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 duringfuture, unless the twelve months ended June 30, 2019, based on Idaho Department of Labor preliminary June 2019 data.COVID-19 public health crisis adversely impacts customer growth. As noted above, Idaho Power hasis considered an "essential business" by the state governments of Idaho and Oregon and its provision of electricity to customers through its power supply, transmission, and distribution operations continues largely uninterrupted. Despite the Oregon and Idaho stay-at-home orders not going into effect until March 23 and 25, 2020, respectively, in recent years supported StateMarch 2020, Idaho Power experienced a 5 percent decrease in usage per commercial customer, likely due to the impacts of Idaho-coordinated effortsCOVID-19 and more moderate weather. Lower commercial customer usage could continue, and potentially worsen, particularly if overall economic conditions deteriorate over a sustained period as a result of COVID-19. While the volume of retail sales to promote economic development with an emphasis on attracting industrial customers was the same in the first quarters of 2019 and commercial customers to its service area.2020, Idaho Power could
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also see notable usage declines from industrial customers if the negative economic impacts of the COVID-19 public health crisis continue.
    
In June 2019, Idaho Power released its 2019 Integrated Resource Plan (IRP)., which was amended in January 2020. The load forecast assumptions Idaho Power used in the 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 Forecasted Annual Growth Rate 20-Year Forecasted Annual Growth Rate
 
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)
 
Retail Sales
(Billed MWh)
 
Annual Peak
(Peak Demand)
 
Retail Sales
(Billed MWh)
 
Annual Peak
(Peak Demand)
2019 IRP 1.3% 1.4% 1.0% 1.2% 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 1.5% 1.8% 1.2% 1.5% 1.5% 1.8% 1.2% 1.5%

•
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.

Further, as Idaho Power's 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 hydropower generation is reduced, Idaho Power must rely on more expensive generation sources and purchased power. When favorable hydropower generating conditions exist for Idaho Power, they also may exist for other Pacific Northwest hydropower facility operators, lowering regional wholesale market prices and impacting the revenue Idaho Power receives from wholesale energy sales. Much of the adverse or favorable impact of this volatility is addressed through the Idaho and Oregon power cost adjustment mechanisms. For 2019,2020, Idaho Power expects generation from its hydropower resources to be in the range of 8.06.0 to 9.08.0 million MWh, compared with 20-year average annual hydropower generation of 7.57.3 million MWh.

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•
Rate Base Growth and Infrastructure Investment: As noted above, the rates established by the IPUC and OPUC are determined so aswith the intent to provide an opportunity for Idaho Power to recover authorized operating expenses and depreciation 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 timely inclusion of any significant completed capital projects into rate base as part of a future general rate case or other appropriate regulatory proceeding.

•
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.

•
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.
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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 jointly-owned coal-fired generating plants.
 
•
Water Management and Relicensing of the Hells Canyon Hydropower Project:Projects: 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 licenselicenses for the HCC, its largest hydropower generation source, and for American Falls, its second 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.licenses.

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, 2019.March 31, 2020. In this analysis, the results for the three and six months ended June 30, 2019,March 31, 2020, are compared with the same periodsperiod in 2018.

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2019.

The table below presents Idaho Power’s energy sales and supply (in thousands of MWh) for the three and six months ended June 30, 2019March 31, 2020 and 2018.2019. 
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Retail energy sales 3,409
 3,576
 6,780
 6,822
 3,319
 3,371
Wholesale energy sales 1,042
 821
 1,902
 1,681
 183
 860
Bundled energy sales —
 73
 146
 297
 162
 146
Total energy sales 4,451
 4,470
 8,828
 8,800
 3,664
 4,377
Hydroelectric generation 3,032
 2,847
 5,132
 5,571
Hydropower generation 1,606
 2,100
Coal generation 422
 459
 1,554
 1,067
 462
 1,132
Natural gas and other generation 137
 124
 564
 228
 638
 427
Total system generation 3,591
 3,430
 7,250
 6,866
 2,706
 3,659
Purchased power 1,195
 1,404
 2,256
 2,594
 1,222
 1,061
Line losses (335) (364) (678) (660) (264) (343)
Total energy supply 4,451
 4,470
 8,828
 8,800
 3,664
 4,377

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Weather-related information for Boise, Idaho for the three and six months ended June 30,March 31, 2020 and 2019, and 2018, is presented in the table below. 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 and is included for illustrative purposes.
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 Normal 2019 2018 
Normal (2)
 2020 2019 
Normal (2)
Heating degree-days(1)
 583
 486
 298
 3,020
 2,783
 2,778
 2,238
 2,437
 2,480
Cooling degree-days(1)
 159
 192
 183
 159
 192
 183
 —
 —
 —
Precipitation (inches) 6.0
 3.1
 3.3
 12.1
 6.9
 6.9
 5.3
 6.1
 3.6
(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 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 degree-day, and each degree of temperature below 65 degrees is counted as one heating degree-day.
(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.

Sales Volume and Generation: Retail sales volumes decreased 5 percent and 12 percent in the second quarter and first six months of 2019, respectively, compared with the same periods of 2018. During the second quarter of 2019, usage per irrigation customer was approximately 20 percent lower2020, compared with the same period in 2018. Precipitation2019. The sales decrease was primarily due to more moderate weather in the Idaho Power service area increased significantly during thefirst three months ended June 30, 2019,of 2020 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 quarterfirst three months of 2019, which decreased the use of electricity for coolingheating purposes. CoolingHeating degree-days in Boise, Idaho, were 178 percent lower duringin the first three months ended June 30, 2019,of 2020 compared with the first three months ended June 30, 2018,of 2019 and 1310 percent below normal. Residential usage per customer was 4.8 percent lower and usage per commercial customer was 2.8 percent lower than the same period of 2019. Some Idaho Power commercial customers were negatively impacted by the COVID-19 public health crisis which, combined with the more moderate weather, caused commercial customers to use 5 percent less energy per customer in March 2020 compared with March 2019. Customer growth partially offset the decrease in sales volumes per customer during the three and six months ended June 30, 2019,March 31, 2020, compared with the same periodsperiod in 2018,2019, with the number of Idaho Power's customers growing by 2.52.6 percent over the prior twelve months.

Total system generation increased 5decreased 26 percent and 6 percent, respectively, duringfor the secondfirst quarter and first six months of 20192020, compared with the same periodsperiod in 2018. In2019. During the secondfirst quarter andof 2020, natural gas generation increased 49 percent compared to the first six monthsquarter of 2019, due mostly to Idaho Power's economic-based decisions to use the Danskin and Bennett Mountain gas-fired power plants as baseload resources and to increase generation at the Langley Gulch plant. Purchased power during the first quarter of 2020 increased 15 percent compared to the first quarter of 2019, due to the lower regional wholesale energy prices. Hydropower and coal generation during the first quarter of 2020 decreased 24 percent and 59 percent, respectively, compared to the first quarter of 2019, due primarily to decreased wholesale energy sales. During the first quarter of 2019, regional wholesale energy prices were elevated due to below-normal temperatures in the Northwest, lack of energy imports due to equipment maintenance, limited production from the federal hydroelectric system due to freezing temperatures and low water flow, and reduced capacity of Pacific Northwest and Western Canada region natural gas pipelines due to a natural gas pipeline that ruptured in British Columbia, Canada, during the fourth quarter of 2018. The higher regional wholesale energy market prices resulted in a 15 percent and 13 percent decrease, respectively, in purchased power volumes compared withduring the same periodsfirst quarter of 2018 as2019 led to higher Idaho Power used its own generation resources to meet customer demand.opportunistic wholesale energy sales.

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,March 31, 2020 and 2019, and 2018, and the number of customers as of June 30, 2019March 31, 2020 and 2018.2019.
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Retail revenues:  
  
      
  
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
Residential (includes $15,710 and $11,309, respectively, related to the FCA)(1)
 $144,887
 $150,219
Commercial (includes $484, and $342, respectively, related to the FCA)(1)
 69,513
 73,106
Industrial 45,602
 48,868
 91,100
 94,660
 42,760
 45,498
Irrigation 48,954
 65,065
 49,953
 65,471
 1,375
 999
Deferred revenue related to HCC relicensing AFUDC(2)
 (1,927) (1,462) (4,046) (4,046) (2,119) (2,119)
Total retail revenues $268,399
 $298,591
 $536,102
 $563,114
 $256,416
 $267,703
Volume of retail sales (MWh)  
  
      
  
Residential 1,032
 1,036
 2,522
 2,439
 1,448
 1,490
Commercial 945
 969
 1,964
 1,970
 1,005
 1,019
Industrial 830
 815
 1,682
 1,648
 852
 852
Irrigation 602
 756
 612
 765
 14
 10
Total retail MWh sales 3,409
 3,576
 6,780
 6,822
 3,319
 3,371
Number of retail customers at period end  
  
      
  
Residential 470,609
 458,448
     480,166
 467,252
Commercial 72,318
 71,074
     73,180
 71,911
Industrial 128
 116
     126
 127
Irrigation 21,370
 21,165
     21,407
 21,202
Total customers 564,425
 550,803
     574,879
 560,492
(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.

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 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.

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Retail revenues decreased $30.2 million during the second quarter of 2019, and decreased $27.0$11.3 million during the first six monthsquarter of 2019,2020 compared with the same periodsperiod in 2018.2019. 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 millionwere flat for the three and six months ended June 30, 2019, respectively,March 31, 2020, compared with the same periodsperiod in 2018. The settlement stipulations approved2019. Customer rates also include the return to customers of amounts related to the power cost adjustment mechanism, which decreased revenues by $11.1 million in the IPUC and OPUC during the secondfirst quarter of 2018 relating2020 compared with the same period of 2019. The amount returned to customers in rates under the power cost adjustment mechanism has relatively little effect on operating income tax reform reduced revenues in the second quarter and first six monthsas a corresponding amount is recorded as a reduction of 2019 more significantly thanexpense 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.period it is returned through rates.
Customer rates also include the 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 second quarter and first six months of 2019, respectively, compared with the same periods of 2018. The amount returned to customers in rates under the power cost adjustment mechanism has no effect on operating income as a corresponding amount is recorded as expense in the same period it is returned through rates. Also, during the second quarter and first six months of 2019, residential and commercial customers used less energy per customer for cooling purposes, primarily due to cooler temperatures compared with the same periods of 2018.
•
Customers: Customer growth of 2.52.6 percent during the twelve months ended March 31, 2020, increased retail revenues by $5.6 million and $11.7$5.1 million in the secondfirst quarter and first six months of 2019, respectively,2020 compared with the same periodsperiod of 2018.2019.
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•
Usage: DecreasedLower usage (on a per customer basis), primarily by irrigationresidential and commercial customers, decreased retail revenues by $19.6 million and $15.3$9.8 million for the secondfirst quarter and first six months of 2019, respectively,2020 compared with the same periodsperiod of 2018. Decreased usage by irrigation customers was primarily the result of higher precipitation2019. More moderate weather in Idaho Power's service area duringled residential customers to use less energy for heating. Also, some Idaho Power commercial customers were negatively impacted by the second quarter and first six months of 2019COVID-19 public health crisis which, combined with the more moderate weather, caused commercial customers to use 5 percent less energy per customer in March 2020 compared with March 2019. Idaho Power expects lower commercial customer usage could continue, and potentially worsen, particularly if overall economic conditions deteriorate over a sustained period as a result of COVID-19. Idaho Power could also see greater usage declines from industrial customers if the same periodsnegative economic impacts of 2018.the COVID-19 public health crisis continue.
•
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 2019three months ended March 31, 2020, 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$4.5 million compared with the same period in 2018.2019.

Wholesale Energy Sales: Wholesale energy sales consist primarily of long-term sales contracts, opportunityopportunistic sales of surplus system energy and sales into the 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,March 31, 2020 and 2019 and 2018 (in thousands, except for per MWh amounts). 
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Wholesale energy revenues $16,158
 $8,919
 $63,373
 $22,685
 $3,908
 $47,215
Wholesale MWh sold 1,042
 821
 1,902
 1,681
 183
 860
Average wholesale energy revenues per MWh $15.51
 $10.86
 $33.32
 $13.49
 $21.36
 $54.90
 
In the secondfirst quarter and first six months of 2019,2020, wholesale energy revenues increased by $7.2decreased $43.3 million and $40.7 million, respectively,compared with the first quarter of 2019. The average wholesale energy prices for the first quarter of 2020 were 61 percent lower compared with the same periods of 2018. Wholesale energyperiod in 2019. The higher prices and sales volumes increased 27 percent and 13 percent in the secondfirst quarter and first six months of 2019 respectively, compared with the same periods of 2018. Below-normalwere due to below-normal temperatures in the Northwest, a decrease inlack of energy imports due to equipment maintenance, and limited production from the federal hydroelectric system due to freezing temperatures and low water flow, increasedand reduced capacity of Pacific Northwest and Western Canada region natural gas pipelines due to a natural gas pipeline that ruptured in British Columbia, Canada, during the fourth quarter of 2018. The higher regional wholesale energy prices during the first quarter and to a lesser extent, the second quarter of 2019 compared with the same periods of 2018. During the fourth quarter of 2018, a natural gas pipeline ruptured in British Columbia, Canada, disrupting natural gas flowsled to the Pacific Northwest and Western Canada, driving uphigher Idaho Power opportunity wholesale energy and natural gas prices in the region. During the first quarter and the beginning of 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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sales.

Transmission Wheeling-Related Revenues: Transmission wheeling-related revenues decreased $2.0$5.4 million, or 1434 percent, during the second quarter of 2019 compared with the second quarter of 2018, primarily due to a decrease in Idaho Power's OATT rates that became effective in October 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 in2020 compared with the first three months of 2019. Idaho Power's OATT rates that became effectivedecreased approximately 13 percent in October 2018. Regional2019 and there was less regional wholesale energy market activity increased wheeling-related volumesdue to the regional market conditions described above in this MD&A in the first quarter of 2020 compared with 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, 2019,March 31, 2020, Idaho Power's energy efficiency rider balances were a $1.6$2.9 million regulatory liabilityasset in the Idaho jurisdiction and a $1.2$1.0 million regulatory asset in the Oregon jurisdiction.

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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,March 31, 2020 and 2019 and 2018 (in thousands, except for per MWh amounts).
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Expense            
PURPA contracts $45,906
 $47,867
 $86,989
 $89,805
 $42,289
 $41,082
Other purchased power (including wheeling) 12,157
 15,113
 33,905
 35,103
 18,912
 21,749
Total purchased power expense $58,063
 $62,980
 $120,894
 $124,908
 $61,201
 $62,831
MWh purchased            
PURPA contracts 881
 908
 1,559
 1,619
 707
 678
Other purchased power 314
 496
 697
 975
 515
 383
Total MWh purchased 1,195
 1,404
 2,256
 2,594
 1,222
 1,061
Average cost per MWh from PURPA contracts $52.11
 $52.72
 $55.80
 $55.47
 $59.81
 $60.59
Average cost per MWh from other sources $38.72
 $30.47
 $48.64
 $36.00
 $36.72
 $56.79
Weighted average - all sources $48.59
 $44.86
 $53.59
 $48.15
 $50.08
 $59.22
 
Purchased power expense decreased $4.9 million, or 8 percent, and $4.0$1.6 million, or 3 percent, induring the secondfirst quarter and first six months of 20192020 compared with the same periodsperiod of 2018.2019. The 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 a 37 percent and 2936 percent decrease respectively, in costs per MWh of purchased power from sources other than PURPA contracts as Idaho Power used its own generationdue to meet customer demand.
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wholesale energy market conditions described earlier in this MD&A.

Fuel Expense: The table below presents Idaho Power’s fuel expenses and thermal generation for the three and six months ended June 30,March 31, 2020 and 2019 and 2018 (in thousands, except for per MWh amounts).
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Expense  
  
        
Coal $16,687
 $18,092
 $55,310
 $41,373
 $15,774
 $38,623
Natural gas 4,139
 3,423
 17,386
 7,877
 14,241
 13,247
Total fuel expense $20,826
 $21,515
 $72,696
 $49,250
 $30,015
 $51,870
MWh generated  
  
        
Coal 422
 459
 1,554
 1,067
 462
 1,132
Natural gas 137
 124
 564
 228
 638
 427
Total MWh generated 559
 583
 2,118
 1,295
 1,100
 1,559
Average cost per MWh - Coal $39.54
 $39.42
 $35.59
 $38.78
 $34.14
 $34.12
Average cost per MWh - Natural gas $30.21
 $27.60
 $30.83
 $34.55
 $22.32
 $31.02
Weighted average, all sources $37.26
 $36.90
 $34.32
 $38.03
 $27.29
 $33.27

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 decreased $0.7$21.9 million, or 3 percent, in the second quarter of 2019, but increased $23.4 million, or 4842 percent, in the first six monthsquarter of 2019,2020 compared with the same periodsfirst quarter of 2018. The2019, due to a 59 percent decrease in coal generation, partially offset by a 49 percent increase in natural gas generation and lower average costs per MWh for natural gas. Coal generation decreased as Idaho Power's participation in unit 1 at the North Valmy plant ended in December 2019 and elevated regional wholesale energy sales prices in the first quarter of 2019 led Idaho Power to
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increase coal generation for opportunistic wholesale energy sales. Higher gas generation in the first quarter of 2020 compared with the first quarter of 2019 was mostly due to economic-based decisions to use the Danskin and Bennett Mountain gas-fired power plants as baseload resources and to increase generation at the Langley Gulch plant. Included in fuel expense in the second quarter of 2019 compared with the second quarter of 2018 was due to a 7 percent increase in hydroelectric generation, which reduced Idaho Power's utilization of gasare losses and coal generation. The increase in fuel expense in the first six months of 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 naturalgains on settled financial gas hedges entered into duringin accordance with Idaho Power's energy risk management policies. In the first sixthree months of 2019. Increased thermal generation2020, losses on financial gas hedges of $2.8 million increased natural gas fuel expense, while 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 energy in the wholesale energy market. In the first sixthree months of 2019, gains on financial gas hedges of $12.4 million entered into in accordance with Idaho Power's energy risk management policies, reduced natural gas fuel expense. Most of these realized hedging gains and losses are providing a benefitpassed on to 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 hydroelectrichydropower 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 or accrued 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, one of 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,March 31, 2020 and 2019 and 2018 (in thousands).
 Three months ended
June 30,		 Six months ended
June 30,		 Three months ended
March 31,
 2019 2018 2019 2018 2020 2019
Power supply cost accrual $24,811
 $16,353
 $55,752
 $33,899
 $10,957
 $30,940
Amortization of prior year authorized balances (8,689) 3,610
 (13,405) 11,602
 (14,348) (4,715)
Total power cost adjustment expense $16,122
 $19,963
 $42,347
 $45,501
 $(3,391) $26,225
 
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 decreased $5.3 million, or 6 percent, and $2.6increased $0.9 million, or 1 percent higher in the secondfirst quarter and first six months of 20192020 compared with the same periods of 2018. Other O&M expenses related to Idaho Power's hydropower generation decreased $1.1 million and $2.3 million for the second quarter and first six months of 2019, respectively, compared with the same periods in 2018, due primarily to more costly maintenance projects at hydropower locations in the first half of 2018. For the second quarter of 2019, primarily due to a slight increase in 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 income tax reform, O&M expenses in the second quarter and first six months of 2018 included $1.1 million of non-cash amortization expense of regulatory deferrals that would otherwise be a future liability of Idaho customers.

Income Taxes

IDACORP's and Idaho Power's income tax expense increased $1.3 million and $1.5 million, respectively,were relatively flat for the sixthree months ended June 30, 2019,March 31, 2020, when compared with the same period in 2018, primarily due to the tax deduction for bond redemption costs incurred in the second quarter of 2018.2019. For information relating to IDACORP's and Idaho Power's computation of income tax expense and estimated annual effective income tax rate,rates, 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 hydropower and thermal generation facilities also require continuing upgrades and component replacement. Idaho Power anticipates these
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substantial capital expenditures towill continue, with expected total capital expenditures of approximately $1.5$1.6 billion over the five-year period from 20192020 (including expenditures incurred to-date in 2019)2020) through 2023.2024.

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 sixthree months of 2019,2020, 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 26, 2019,April 24, 2020, IDACORP's and Idaho Power's access to debt, equity, and credit arrangements included:

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 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 17, 2019, which may be used for the issuance of first mortgage bonds and debt securities; $500$270 million remains available for issuance pursuant to state regulatory authority; and
IDACORP's and Idaho Power's 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 April 2020, Idaho Power issued $230 million in principal amount of 4.20 percent first mortgage bonds, secured medium term notes, Series K, maturing March 1, 2048. The bonds had a maturity date, interest rate, and payment terms consistent with the Series K medium-term notes that Idaho Power issued in March 2018. The bonds were issued at a reoffer yield of 3.422 percent, which resulted in a net premium of 13.0 percent and net proceeds to Idaho Power of approximately $260 million. Idaho Power intends to use a portion of the net proceeds of this April 2020 sale of first mortgage bonds to satisfy its obligations at or prior to maturity of $100 million in principal amount of 3.40 percent first mortgage bonds due in November 2020.

As of the date of this report, Idaho Power is uncertain how significantly the COVID-19 public health crisis will ultimately impact Idaho Power's operations, results of operations, cash flows, financial condition, or capital resources. The net proceeds from the April 2020 debt issuance, noted above, provided Idaho Power with additional liquidity should the financial impacts of the COVID-19 public health crisis worsen in the coming months or be prolonged. 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, 2019,March 31, 2020, IDACORP's and Idaho Power's capital structures, as calculated for purposes of applicable debt covenants, were as follows:
  IDACORP Idaho Power
Debt 43% 45%
Equity 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.

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Operating Cash Flows
 
IDACORP’s and Idaho Power’s operating cash inflows for the sixthree months ended June 30, 2019,March 31, 2020, were $166$34 million and $162$39 million, respectively, a decrease of $30$23 million for IDACORP and $29$15 million for Idaho Power, compared with the same period in 2018.2019. 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 sixthree months of 20192020 compared with the same period in 20182019 were as follows:

decreased net income;
changes in deferred taxes and in taxes accrued and receivable combined to decrease cash flows by $1 million at IDACORP and increase cash flows by $4 million at IDACORP and decrease cash flows by $8$9 million at Idaho Power;
changes in regulatory assets and liabilities, mostly related to the relative amounts of costs deferred and collected under the Idaho FCAPCA mechanism, and demand-side management program, decreased operating cash flows by $14$29 million;
Idaho Power made $15received $2 million of benefit plan contributions duringdistributions from IERCO's investment in BCC for 2020, compared with $8 million in 2019; changes in distributions from year to year are primarily driven by changes in the first six monthstiming of 2019, while it made contributions of $25 million for the same period in 2018;cash needs associated with BCC; and
changes in working capital balances due primarily to timing, including fluctuations in accounts receivable and accounts payable,other current assets, as follows:
◦timing of collections of accounts receivable balances decreasedincreased operating cash flows by $3 million and $4$30 million for IDACORP and $29 million for Idaho Power, respectively;Power; and
◦timing of accounts payable paymentsthe changes in other current assets decreased operating cash flows by $31 million and $17$8 million for IDACORP and Idaho Power, respectively,which was primarily due to fluctuations in accrued unbilled revenues and the timing of which $14 million of the difference between IDACORP and Idaho Power related to intercompany estimated income tax payments.prepayments.

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 sixthree months ended June 30, 2019,March 31, 2020, were $126$74 million and $123$72 million, respectively. Investing cash outflows for 20192020 and 20182019 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.
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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 outflows for the sixthree months ended June 30, 2019,March 31, 2020, were $68$39 million and $64$34 million, respectively. In the first sixthree months of 2019,2020, IDACORP and Idaho Power paid cash dividends of $64$34 million.

Financing Programs and Available Liquidity

IDACORP Equity Programs: In recent years, IDACORP has entered into sales agency agreements under which 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. IDACORP has no current plans to issue equity securities other than under its equity compensation plans during 2019,2020, 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 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. Following the April 2020 issuance of Series K medium-term notes described above, $270 million remains available. Authority from the IPUC is effective through May 31, 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.

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In May 2019, Idaho Power filed a shelf registration statement with the SEC, which became effective upon filing, for the offer and sale of an unspecified principal amount of its first mortgage bonds. The issuance of first mortgage bonds requires that Idaho 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). Future issuances of first mortgage bonds are subject to satisfaction of covenants and security provisions set forth in the Indenture, market conditions, regulatory authorizations, and covenants contained in other financing agreements.

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, 2019March 31, 2020 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, 2019,March 31, 2020, Idaho Power could issue approximately $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,December 2019, 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$50 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.December 6, 2024, though IDACORP and Idaho Power may request up to two-one-year extensions of the credit agreements, subject to certain conditions. Other terms and conditions of the credit facilities are described in the 20182019 Annual Report, 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, 2019,March 31, 2020, the leverage ratios for IDACORP and Idaho Power were 43 percent and 45 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, 2019,March 31, 2020, 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 2019.2020.

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,IPUC, the OPUC, and Wyomingthe WPSC for the issuance of short-term borrowings through November 2022.December 2026.

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.

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Available Short-Term Borrowing Liquidity

The table below outlines available short-term borrowing liquidity as of the dates specified (in thousands).
 June 30, 2019 December 31, 2018 March 31, 2020 December 31, 2019
 
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.
 
At July 26, 2019,April 24, 2020, IDACORP had no loans outstanding under its credit facilities and had no commercial paper outstanding. Idaho Power had no loans outstanding under its credit facilities and no commercial paper outstanding. During the three and six months ended June 30, 2019,March 31, 2020, IDACORP and Idaho Power borrowed no short-term commercial 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 20182019 Annual 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, 2019,March 31, 2020, Idaho Power had posted $1.8$3.6 million 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, 2019,March 31, 2020, the amount of additional collateral that could be requested upon a downgrade to below investment grade is approximately $5.4$4.7 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 $125$71 million during the sixthree months ended June 30, 2019.March 31, 2020. The cash expenditure amount excludes net costs of removing assets from service. The table below presents Idaho Power's estimated accrual-basis expendituresadditions to electric plant for construction for 20192020 (including amounts incurred to-date) through 20232024 (in 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.
  2019 2020 2021-2023
Expected capital expenditures (excluding AFUDC) $280-290 $285-300 $875-925
  2020 2021 2022-2024
Expected capital expenditures (excluding AFUDC) $300-$310 $305-$315 $1,000-$1,050

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 the 20182019 Annual 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-kVhigh-voltage transmission project between a stationsubstation near Boardman, Oregon, and the Hemingway stationsubstation near Boise, Idaho, would provide transmission service to meet future resource needs. In January 2012, Idaho Power entered into a joint funding
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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 at least 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 $103$108 million, including AFUDC, has been expended on the Boardman-to-Hemingway project through June 30, 2019.March 31, 2020. Pursuant to the terms of the joint funding arrangements, Idaho Power has received $71$72 million as of June 30, 2019,March 31, 2020, 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 issued its record of decision for the project in November 2017, approving a right-of-way grant for the project to cross approximately 86 miles of BLM-administered land. The U.S. Forest Service issued its record of decision in November 2018 authorizing the project to cross approximately 7seven miles of National Forest lands. Idaho Power also expectsIn September 2019, the Department of the Navy to issueissued its record of decision on whether to approveauthorizing the project to cross approximately 7seven miles of Department of the Navy landslands. In November, 2019, third parties filed a lawsuit in 2019. the federal district court of Oregon challenging the BLM and U.S. Forest Service records of decision for the Boardman-to-Hemingway project. In February 2020, Idaho Power filed a motion to intervene in the legal proceeding, and the motion was granted on April 2, 2020. The litigation is in its initial phases and remains pending as of the date of this report.

In the separate Oregon state permitting process, in May 2019, the Oregon Department of Energy (ODOE) issued a Draft Proposed Order in May 2019 that recommends approval of the project to the state's Energy Facility Siting Council.Council (EFSC). The Oregon Department of EnergyODOE is expected to issue a Proposed Order in late 2019 or earlythe first half of 2020. Idaho Power currently expects the EFSC to issue a final order and site certificate in 2021. 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 2026 or beyond.some time thereafter.

Gateway West Transmission Line: Idaho Power and PacifiCorp are pursuing the joint development of the Gateway West project, a 500-kVhigh-voltage transmission lines project between a stationsubstation located near Douglas, Wyoming and the Hemingway stationsubstation located near Boise, Idaho. In January 2012, Idaho Power and PacifiCorp entered a joint funding agreement for permitting of the project. Idaho Power has expended approximately $40$42 million, including Idaho Power's AFUDC, for its share of the permitting phase of the project through June 30, 2019.March 31, 2020. 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. 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 noPower's minimum required contribution requirementto be made to its defined benefit pension plan in 2019; however, after evaluating market conditions and expected 2019 cash flows,during 2020 is estimated to be $14 million. Idaho Power contributed $10 million to the plan during the first six monthsquarter of
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2019.the COVID-19 health crisis, during the remainder of 2020 Idaho Power expects it will contributeis considering contributing up to a total of $40an additional $30 million to the pension plan during 2019.plan. 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 sixthree months ended June 30, 2019,March 31, 2020, IDACORP's and Idaho Power's contractual obligations, outside the ordinary course of business, did not change materially from the amounts disclosed in the 20182019 Annual Report, except that Idaho Power entered into foureight new replacement contracts for expiring power purchase agreements with hydropower and cogeneration PURPA-qualifying facilities, and one new agreement with a solar PURPA-qualifying facility, which increased Idaho Power's contractual purchase obligations by approximately $24$22 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.

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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 the 20182019 Annual Report.

REGULATORY MATTERS
 
Introduction

Idaho Power is under the jurisdiction (as to rates, service, accounting, and other general matters of utility operation) of the IPUC, the OPUC, and the FERC. The IPUC and OPUC determine the rates that Idaho Power is authorized to charge to its retail customers. Idaho Power is also under the regulatory jurisdiction of the IPUC, the OPUC, and the WPSC as to the issuance of debt and equity securities. As a public utility under the Federal Power Act (FPA), Idaho Power has authority to charge market-based rates for wholesale energy sales under its FERC tariff and to provide transmission services under its OATT. Additionally, the FERC has jurisdiction over Idaho Power's sales of transmission capacity and wholesale electricity, hydropower project relicensing, and system reliability, among other items.

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 these regulatory 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 filed2011. In 2012, large single-issue rate 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.Oregon. 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 the 20182019 Annual Report. In addition to the discussion below, which includes notable regulatory developments since the discussion of these matters in the 20182019 Annual Report, 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 Pending Retail Rate Changes During 20192020

During 2019,2020, Idaho Power received orders authorizing thehas filed rate changeschange applications in notable pending regulatory matters summarized in the table below.
Description Status 
Estimated Rate Impact(1)
 Notes
Power Cost Adjustment Mechanism - Idaho New PCA rate became effective June 1, 2019Filed April 15, 2020; Pending $50.158.7 million PCA decreaseincrease for the period from June 1, 20192020 to May 31, 20202021 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 includesincrease reflects the return to a $5.0 million credit to customers for sharingmore normal level of 2018 earnings under the IPUC order approving the extension, with modifications, of the terms of the December 2011 Idaho settlement stipulation for the periodpower supply costs as wholesale market prices have come down 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 belowunusually high levels reflected in this MD&A.last year's PCA.
Fixed Cost Adjustment Mechanism - Idaho New FCA rate became effective June 1, 2019Filed March 13, 2020; Pending $19.20.7 million FCA increase for the period from June 1, 20192020 to May 31, 20202021 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.
Valmy Plant Agreement - IdahoNew base rate became effective June 1, 2019$1.2 million annual increaseIn 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 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.

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Idaho Earnings Support and Sharing from Idaho Settlement Stipulation

In October 2014, the IPUC issued an order approving the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation extending, with modifications, the terms of a December 2011 Idaho settlement stipulation for the period from 2015 through 2019. 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 ADITC and revenue sharing mechanism to becomethat became effective beginning January 1, 2020. The more specific terms and conditions of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation and the May 2018 Idaho Tax Reform Settlement Stipulation are described in Note 3 - "Regulatory Matters" to the consolidated financial statements included in the 20182019 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 20192020 Idaho ROE, in both the secondfirst quarter and first six months of 2019,2020, Idaho Power recorded no additional ADITC amortization or provision against current revenues for sharing of earnings with customers for 20192020 under the October 2014May 2018 Idaho Earnings Support and SharingTax Reform Settlement Stipulation. DuringAccordingly, at March 31, 2020, the second quarter of 2018, Idaho Power reversed the $0.5full $45 million of additional ADITC remains available for future use. Idaho Power also recorded $0.0 million additional ADITC amortization recordedor provision against revenues for sharing of earnings with customers during the first quarter of 2018, as actual financial results exceeded2019, based on its then-current estimate of full-year 2019 Idaho Power's early estimates.ROE.

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 sixthree months ended June 30, 2019March 31, 2020 (in millions).
  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 Oregon Total
Deferred (accrued) net power supply costs at December 31, 2019 $(48.2) $(0.3) $(48.5)
Current period net power supply costs (deferred) accrued (11.0) —
 (11.0)
Prior amounts refunded through rates 15.5
 —
 15.5
SO2 allowance and renewable energy certificate sales
 (2.5) (0.1) (2.6)
Interest and other 0.5
 —
 0.5
Deferred (accrued) net power supply costs at March 31, 2020 $(45.7) $(0.4) $(46.1)

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 PostingDeferred Costs for COVID-19 Public Health Crisis

In March and April 2020, Idaho Power uses a formula rate for transmission service provided undersubmitted applications to the OPUC and IPUC, respectively, requesting authorization to defer any incremental costs and, in the Idaho jurisdiction, unrecovered costs associated with its OATT, which allows transmission ratesresponse to be updated annually based primarily on financial and operational datathe COVID-19 public health crisis. Idaho Power files with the FERC. In May 2019, Idaho Power publicly postedmay incur significant costs in its 2019 draft transmission rate, reflecting a transmission rate of $27.32 per "kW-year," to be effective for the period from October 1, 2019 to September 30, 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 $107.0 million. The existing OATT rate in effect from October 1, 2018 to September 30, 2019, is $31.26 per kW-year based on a net annual transmission revenue requirement of $123.1 million. The decrease in the OATT rate is largely attributable to federal tax reform and increased short-term firm and non-firm transmission revenues in 2018, which serve as an offsetresponse to the transmission revenue requirement.

2019 Integrated Resource Plan

Idaho Power filed its most recent IRP withpublic health emergency, which are described in Note 3 - "Regulatory Matters" to the IPUC and OPUCcondensed consolidated financial statements included 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 endthis report. Subsequent to Idaho Power's participation in coal-fired operations atapplication and other public utilities' similar applications, the Valmy Plant units 1IPUC staff issued a decision memorandum recommending that the IPUC open a general docket to address whether and 2 in 2019 and 2025, respectively, andto what extent Idaho public utilities should be authorized to defer incremental COVID-19-related expenses into a regulatory asset for possible future recovery. As of 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 2019 IRP was Idaho Power's first IRP to use a long-term capacity expansion modeling system to identify economic resource portfolios under a range of future system conditions. This model simulates the entire western interconnection system to find an optimized western-interconnection resource portfolio. Subsequent to filing the 2019 IRP,this report, Idaho Power identified that the optimization method used by the modeling software didhas not also model an optimized Idaho Power-specific system. Idaho Power is conducting further analysisreceived authorization in either jurisdiction and simulations on resource optimization based on an Idaho Power-specific system and expects to supplement the currently filed 2019 IRP with additional information and modeling results by the end of October 2019. If Idaho Power identifies significant differences in the results associated with additional modeling, it could modify the preferred resource portfolio identified in the 2019 IRP, which could alter the anticipated timing of plant additions and retirements.has not deferred any such costs.

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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 hydropower, and geothermal. The majority of these contracts are entered into as mandatory purchases under PURPA. As of June 30, 2019,March 31, 2020, Idaho Power had contracts to purchase energy from 127130 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, 2019,March 31, 2020, 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 On-line megawatts (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
 30
 320
  313
 6
 319
Hydropower 147
 2
 149
  147
 2
 149
Other 56
 —
 56
  52
 —
 52
Total 1,120
 32
 1,152
  1,139
 8
 1,147
Non-PURPA:             
Wind 101
 —
 101
  101
 —
 101
Geothermal 35
 —
 35
  35
 —
 35
Solar —
 120
 120
  —
 120
 120
Total 136
 120
 256
  136
 120
 256

The projects not yet on-line include one hydropower PURPA project and fiveone solar PURPA projectsproject that are scheduled to be on-line in 20192020 and one solar PURPA project scheduled to be onlineon-line 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,September 2019, the FERC issued a Notice of Proposed Rulemaking that, if adopted, could affect how states determine PURPA project avoided cost rates for purchases of power generated from qualified facilities (QF), which facilities are eligible for QF status, whether and when certain QFs can enter into purchase agreements with utilities, and how parties can contest the eligibility of a generation facility seeking QF status. As of the date of this report, Idaho Power filed an application withis unable to determine the IPUC relatedimpact of these potential changes on the company's future obligations for new PURPA power purchase contracts, as it would require further action by the state public utility commissions 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 creationimplement many of the new customer classes. In that order,changes. While the IPUC also stated its intentultimate impact of implementation of those changes is yet to open an Idaho Power-specific docket to comprehensively study on-site generation and orderedbe determined, taken as a whole, 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 requestingbelieves that the IPUC open two new cases to study fixed-cost recovery,changes could reduce the number of future PURPA generation projects, which could reduce purchased power costs for Idaho Power. Substantially all PURPA power purchase costs are recovered through base rates 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.power cost adjustment mechanisms.

Relicensing of Hydropower Projects

HCC Relicensing: In connection with Idaho Power's efforts to relicense the HCC, Idaho Power's largest hydropower complex and a major relicensing effort, as described in more detail in the 20182019 Annual Report in Part II, Item 7 - "Regulatory Matters," Idaho Power 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. Idaho Power 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 states of Idaho and Oregon, along with Idaho Power, reached a settlement pertaining to the CWA Section 401 certification that requires Idaho Power to increase the number of Chinook salmon it releases each year through expanded hatchery production. Additionally, Idaho Power 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 license. These measures are in exchange for Oregon removing the 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 $20 million over the first 20 years of the
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new license term. In May 2019, Oregon and Idaho issued final CWA Section 401 certifications. These certifications have been submitted to the FERC as part of the relicensing process. In July 2019, severalthree third-parties filed lawsuits against the Oregon Department of Environmental Quality in Oregon state court challenging the Oregon CWA Section 401 certification based on fish passage, water temperature, and mercury issues associated with the Snake River and the HCC. Idaho Power has intervened in one of the third-party lawsuits and is closely monitoring the other two. No parties challenged the Idaho CWA 401 certification bycertification. In December 2019, Idaho Power filed an Offer of Settlement with the applicable deadline.FERC requesting specific language be included in the new HCC license based upon the settlement among Idaho, Oregon, and Idaho Power. During the first quarter of 2020, the FERC received several comments opposing the Offer of Settlement and its decision relating to the Offer of Settlement is pending as of the date of this report. Idaho Power continues to expect the FERC to issue ana license for the HCC license no earlier than 2022.

Costs for the relicensing of Idaho Power's 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 $311$333 million (including AFUDC) for the HCC were included in construction work in progress at June 30, 2019.March 31, 2020. 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. Collecting these amounts currently will reduce future collections when HCC relicensing costs are approved for recovery in base rates. As of June 30, 2019,March 31, 2020, Idaho Power's regulatory liability for collection of AFUDC relating to the HCC was approximately $143$156 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.

American Falls Relicensing: In April 2020, the FERC formally initiated the relicensing proceeding for the American Falls hydropower facility, which is Idaho Power's largest hydropower facility outside of the HCC, with a generating capacity of 92.3 MW. Idaho Power owns the generation facility but not the structural dam itself, which is owned by the U.S. Bureau of Reclamation. The FERC recognized Idaho Power’s pre-application document, including a proposed process plan and schedule, and recognized Idaho Power’s intent to file an application for a license. The relicensing proceeding will begin the process of informal Endangered Species Act (ESA) Section 7 consultation with Fish and Wildlife Service and Section 106 of the National Historic Preservation Act consultation with the Idaho State Historic Preservation Office. American Falls' current license expires in 2025, and as of the date of this report, Idaho Power expects the FERC to issue a license for this facility prior to the expiration.

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,ESA, among other laws. These laws are administered by a number ofvarious 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 jointly-owned coal-fired power plants and three wholly-owned natural gas-fired combustion turbine power plants are subject to many of these regulations. Idaho Power's 17 hydropower projects are also subject to a number ofnumerous 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.

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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 the 20182019 Annual Report, includes a summary of Idaho Power's expected capital and operating expenditures for environmental matters during the period from 20192020 to 2021.2022. 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.

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 the 20182019 Annual Report. Developments in certain environmental matters relevant to Idaho Power are described below.

Clean Water Act Matters

Definition of “Waters of the United States” Under the CWA:CWA: In August 2015, the U.S. Environmental Protection Agency's (EPA)EPA and U.S. Army Corps of Engineers' (USACE) final rule defining the phrase "waters of the United States" (WOTUS) under the CWA became effective (WOTUS Rule). Idaho Power believes that the 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 WOTUS Rule does not currently apply in twenty-eight states, including Idaho,In January 2020, the EPA and litigation regardingUSACE finalized the first of a two-part rule to repeal the WOTUS Rule continues. In February 2019,and set new and more expansive standards for determining which waters are subject to the CWA, which substantially restored the definitions and guidance used prior to the WOTUS Rule. On April 21, 2020, the EPA and USACE published the U.S. Army Corpssecond part of Engineers publishedthe final rule to replace the WOTUS Rule with the "Navigable Waters Protection Rule" that provides a revisedfinal definition of WOTUS,"waters of the United States," which would reduceultimately narrows the numberscope of waters in Idaho Power's service area subject to federal regulation under the WOTUS Rule.CWA. The Navigable Waters Protection Rule becomes effective on June 22, 2020.

Idaho Power has analyzedbelieves the repeal rule, the WOTUS Rule, and the Navigable Waters Protection Rule will continue to be challenged in court, but 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 hydropower plants, Idaho Power does not expect this proposal toreinstatement would have a material 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 CO2 emissions 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 the 20182019 Annual 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, 2018,2019, 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, 2019.March 31, 2020. 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, 2019,March 31, 2020, 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, 2019,March 31, 2020, IDACORP had $1.8 billion in fixed rate debt, with a fair market value of approximately $2.0$2.1 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 $301$269 million if market interest rates were to decline by one percentage point from their June 30, 2019March 31, 2020, 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, 2019,March 31, 2020, 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, 2018 (20182019 (2019 Annual Report). Information regarding Idaho Power’s use of derivative instruments to manage commodity price risk can be found in Note 1011 - "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; using appropriate contractual arrangements; and transferring 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, 2019,March 31, 2020, Idaho Power had posted $1.8$3.6 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, 2019,March 31, 2020, the amount of collateral that could be requested upon a downgrade to below investment grade was approximately $5.4$4.7 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, 2019,March 31, 2020, had not changed materially from that reported in Item 7A of the 20182019 Annual Report.Report, except as disclosed in Note 1 - "Summary of Significant Accounting Policies" to the condensed consolidated financial statements included in this report. Additional information regarding Idaho Power’s management of credit risk and credit contingent features can be found in Note 1011 - "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 1210 - "Benefit Plans" to the consolidated financial statements included in the 20182019 Annual Report.
 
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, 2019,March 31, 2020, 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, 2019,March 31, 2020, 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, 2019,March 31, 2020, 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, 2018,2019, could materially affect IDACORP’s and Idaho Power's business, financial condition, or future results. In addition to those risk factors, the risk factor set forth below, 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.

The recent COVID-19 coronavirus outbreak could adversely affect IDACORP's and Idaho Power's business functions, financial condition and results of operations. The recent COVID-19 coronavirus outbreak has resulted in widespread impacts on the global economy and on Idaho Power's employees, customers, contractors, and suppliers. There is considerable uncertainty regarding the extent to which the coronavirus will spread and the extent and duration of measures to try to contain the virus, such as travel bans and restrictions, quarantines, shelter-in-place orders (including those in effect in Idaho Power's service area in the states of Idaho and Oregon), and business and government shutdowns. Restrictions of this nature may cause Idaho Power or its contractors to miss milestones on construction projects and experience operational delays, delay the delivery of electrical infrastructure and other supplies that it sources from around the globe, delay the connection of electric service to new customers, prolong the time period necessary to perform maintenance of our infrastructure, and significantly reduce the use of electricity by commercial and industrial customers.

Further, while Idaho Power has modified certain business and workforce practices (including employee travel, employee work locations, and cancellation of physical participation in meetings, events, and conferences) to conform to government restrictions and best practices encouraged by government and regulatory authorities, Idaho Power has a limited number of highly skilled operators for some of its critical power plants and its grid operations centers. If a large proportion of Idaho Power's employees in those critical facilities were to contract COVID-19 at the same time, it would rely upon its business continuity plans in an effort to continue operations at those facilities, but there is no certainty that such measures will be sufficient to mitigate the adverse impact to its operations.

Additionally, the effects of COVID-19 on the U.S. capital markets may significantly impact Idaho Power. For example, the costs related to the noncontributory defined benefit pension plan we provide to Idaho Power employees, as well as a defined benefit postretirement benefit plan (consisting of health care and death benefits) that covers eligible retirees, are based in part on the value of the plans’ assets and, therefore, adverse investment performance for these assets or the failure to maintain sustained growth in pension investments over time could increase its plan costs and funding requirements related to the plans. Similarly, Idaho Power relies on access to the capital markets to fund its capital requirements. To the extent that access to the capital markets is adversely affected by COVID-19, Idaho Power may need to consider alternative sources of funding for its operations and for working capital, which may increase its cost of, as well as adversely impact its access to, capital. These uncertain economic conditions may also result in the inability of Idaho Power's customers to pay for electric service, which could affect the collectability of its revenues and adversely affect its financial results.

The degree to which COVID-19 may impact IDACORP's and Idaho Power's liquidity, financial condition and results of operations is unknown at this time and will depend on future developments, including the ultimate geographic spread of the virus, the severity of the disease, the duration of the outbreak, actions that may be taken by governmental authorities, and to what extent normal economic and operating conditions can resume.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
 
Restrictions on Dividends

See Note 56 - "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.

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Issuer Purchases of Equity Securities

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

March 31, 2020.

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, 2019:March 31, 2020:
  Incorporated by Reference 
Exhibit No.Exhibit DescriptionFormFile No.Exhibit No.DateIncluded Herewith
       
10.1 (1)
IDACORP, Inc. and/or Idaho Power Company Executive Officers with Amended and Restated Change in Control Agreements chart, as of April 30, 2020
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.SCHInline XBRL Taxonomy Extension Schema Document    X
101.CALInline XBRL Taxonomy Extension Calculation Linkbase Document    X
101.LABInline XBRL Taxonomy Extension Label Linkbase Document    X
101.PREInline XBRL Taxonomy Extension Presentation Linkbase Document    X
101.DEFInline XBRL Taxonomy Extension Definition Linkbase Document    X
104Cover 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 1, 2019April 30, 2020By: /s/ Darrel T. Anderson
   Darrel T. Anderson
   President and Chief Executive Officer
    
Date:August 1, 2019April 30, 2020By: /s/ Steven R. Keen
   Steven R. Keen
   Senior Vice President and Chief Financial Officer
   Officer, and Treasurer
    
   
   
   
   
  IDAHO POWER COMPANY
  (Registrant)
    
    
    
Date:August 1, 2019April 30, 2020By: /s/ Darrel T. Anderson
   Darrel T. Anderson
   President and Chief Executive Officer
    
Date:August 1, 2019April 30, 2020By: /s/ Steven R. Keen
   Steven R. Keen
   Senior Vice President and Chief Financial Officer
   Officer, and Treasurer
    


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