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HAWAIIAN ELECTRIC CO INC - Quarter Report: 2020 September (Form 10-Q)


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 September 30, 2020
 OR
     ☐         TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Exact Name of Registrant as Specified in Its Charter Commission File Number I.R.S. Employer Identification No.
HAWAIIAN ELECTRIC INDUSTRIES, INC. 1-8503 99-0208097
and Principal Subsidiary
HAWAIIAN ELECTRIC COMPANY, INC. 1-4955 99-0040500
State of Hawaii
(State or other jurisdiction of incorporation or organization)
 
Hawaiian Electric Industries, Inc. – 1001 Bishop Street, Suite 2900, Honolulu, Hawaii  96813
Hawaiian Electric Company, Inc. – 1001 Bishop Street, Suite, 2500, Honolulu, Hawaii  96813
(Address of principal executive offices and zip code)
 
Hawaiian Electric Industries, Inc. – (808) 543-5662
Hawaiian Electric Company, Inc. – (808) 543-7771
(Registrant’s telephone number, including area code) 
Not applicable
(Former name, former address and former fiscal year, if changed since last report)
RegistrantTitle of each classTrading Symbol(s)Name of each exchange on which registered
Hawaiian Electric Industries, Inc. Common Stock, Without Par ValueHENew York Stock Exchange

Indicate by check mark whether the registrant (1) has 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 registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Hawaiian Electric Industries, Inc.Yes☒No☐ Hawaiian Electric Company, Inc. Yes☒No☐
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
Hawaiian Electric Industries, Inc.Yes☒No☐ Hawaiian Electric Company, Inc.Yes☒No☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.
Hawaiian Electric Industries, Inc.: Hawaiian Electric Company, Inc.:
Large accelerated filer☒Smaller reporting company☐Large accelerated filer☐Smaller reporting company☐
Accelerated filer☐Emerging growth company☐Accelerated filer☐Emerging growth company☐
Non-accelerated filer☐Non-accelerated filer☒
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.
Hawaiian Electric Industries, Inc.☐Hawaiian Electric Company, Inc.☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Hawaiian Electric Industries, Inc.Yes☐No☒Hawaiian Electric Company, Inc.Yes☐No☒
Securities registered pursuant to 12(b) of the Act:
APPLICABLE ONLY TO CORPORATE ISSUERS:
Indicate the number of shares outstanding of each of the issuers’ classes of common stock, as of the latest practicable date.
Class of Common Stock 
Outstanding October 23, 2020
Hawaiian Electric Industries, Inc. (Without Par Value) 109,181,124 Shares
Hawaiian Electric Company, Inc. ($6-2/3 Par Value) 17,048,783 Shares (not publicly traded)
Hawaiian Electric Industries, Inc. (HEI) is the sole holder of Hawaiian Electric Company, Inc. (Hawaiian Electric) common stock.
This combined Form 10-Q is separately filed by HEI and Hawaiian Electric. Information contained herein relating to any individual registrant is filed by such registrant on its own behalf. No registrant makes any representation as to information relating to the other registrant, except that information relating to Hawaiian Electric is also attributed to HEI.


Hawaiian Electric Industries, Inc. and Subsidiaries
Hawaiian Electric Company, Inc. and Subsidiaries
Form 10-Q—Quarter ended September 30, 2020
 
TABLE OF CONTENTS
 
Page No. 
  
 
  
 
three and nine months ended September 30, 2020 and 2019
 
three and nine months ended September 30, 2020 and 2019
 
 
three and nine months ended September 30, 2020 and 2019
 
nine months ended September 30, 2020 and 2019
  
 
three and nine months ended September 30, 2020 and 2019
 
three and nine months ended September 30, 2020 and 2019
 
 
three and nine months ended September 30, 2020 and 2019
 
nine months ended September 30, 2020 and 2019
 
 
 
 
  
 
 
i

Hawaiian Electric Industries, Inc. and Subsidiaries
Hawaiian Electric Company, Inc. and Subsidiaries
Form 10-Q—Quarter ended September 30, 2020
GLOSSARY OF TERMS
Terms Definitions
ACLAllowance for credit losses, which is the current credit loss standard, requires recording the allowance based on the expected loss model
AES HawaiiAES Hawaii, Inc.
AFSAvailable for sale
AOCI Accumulated other comprehensive income/(loss)
ASB American Savings Bank, F.S.B., a wholly owned subsidiary of ASB Hawaii, Inc.
ASB Hawaii ASB Hawaii, Inc. (formerly American Savings Holdings, Inc.), a wholly owned subsidiary of Hawaiian Electric Industries, Inc. and the parent company of American Savings Bank, F.S.B.
ASU Accounting Standards Update
CARES ActThe Coronavirus Aid, Relief, and Economic Security Act enacted March 27, 2020
CBRECommunity-based renewable energy
Company Hawaiian Electric Industries, Inc. and its direct and indirect subsidiaries, including, without limitation, Hawaiian Electric Company, Inc. and its subsidiaries (listed under Hawaiian Electric); ASB Hawaii, Inc. and its subsidiary, American Savings Bank, F.S.B.; Pacific Current, LLC and its subsidiaries, Hamakua Holdings, LLC (and its subsidiary, Hamakua Energy, LLC), Mauo Holdings, LLC (and its subsidiary, Mauo, LLC) and Ka‘ie‘ie Waho Company, LLC; and The Old Oahu Tug Service, Inc. (formerly Hawaiian Tug & Barge Corp.)
Consumer Advocate Division of Consumer Advocacy, Department of Commerce and Consumer Affairs of the State of Hawaii
D&O Decision and order from the PUC
DERDistributed energy resources
Dodd-Frank Act Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010
DOH Department of Health of the State of Hawaii
DRIP HEI Dividend Reinvestment and Stock Purchase Plan
ECRCEnergy cost recovery clause
EIP 2010 Equity and Incentive Plan, as amended and restated
EPA Environmental Protection Agency — federal
EPS Earnings per share
ERP/EAMEnterprise Resource Planning/Enterprise Asset Management
ESGEnvironmental, Social & Governance
EVE Economic value of equity
Exchange Act Securities Exchange Act of 1934
FASB Financial Accounting Standards Board
FDIC Federal Deposit Insurance Corporation
federal U.S. Government
FHLB Federal Home Loan Bank
FHLMC Federal Home Loan Mortgage Corporation
FNMA Federal National Mortgage Association
FRB Federal Reserve Board
GAAP Accounting principles generally accepted in the United States of America
GNMA Government National Mortgage Association
Hamakua EnergyHamakua Energy, LLC, an indirect subsidiary of HEI
Hawaii Electric Light Hawaii Electric Light Company, Inc., an electric utility subsidiary of Hawaiian Electric Company, Inc.

ii
GLOSSARY OF TERMS, continued

Terms Definitions
Hawaiian Electric Hawaiian Electric Company, Inc., an electric utility subsidiary of Hawaiian Electric Industries, Inc. and parent company of Hawaii Electric Light Company, Inc., Maui Electric Company, Limited and Renewable Hawaii, Inc. Uluwehiokama Biofuels Corp. was dissolved effective as of July 14, 2020
HEI Hawaiian Electric Industries, Inc., direct parent company of Hawaiian Electric Company, Inc., ASB Hawaii, Inc., Pacific Current, LLC and The Old Oahu Tug Service, Inc. (formerly Hawaiian Tug & Barge Corp.)
HEIRSP Hawaiian Electric Industries Retirement Savings Plan
HELOCHome equity line of credit
HPOWER City and County of Honolulu with respect to a power purchase agreement for a refuse-fired plant
IPP Independent power producer
Kalaeloa Kalaeloa Partners, L.P.
kWh Kilowatthour/s (as applicable)
LTIP Long-term incentive plan
Maui Electric Maui Electric Company, Limited, an electric utility subsidiary of Hawaiian Electric Company, Inc.
MauoMauo, LLC, an indirect subsidiary of HEI
MPIRMajor Project Interim Recovery
MSRMortgage servicing right
MW Megawatt/s (as applicable)
NII Net interest income
NPBCNet periodic benefit costs
NPPCNet periodic pension costs
O&M Other operation and maintenance
OCC Office of the Comptroller of the Currency
OPEB Postretirement benefits other than pensions
Pacific CurrentPacific Current, LLC, a wholly owned subsidiary of HEI and parent company of Hamakua Holdings, LLC, Mauo Holdings, LLC, and Ka‘ie‘ie Waho Company, LLC
PBRPerformance-based regulation
PGVPuna Geothermal Venture
PIMsPerformance incentive mechanisms
PPA Power purchase agreement
PPAC Purchased power adjustment clause
PUC Public Utilities Commission of the State of Hawaii
PVPhotovoltaic
RAM Rate adjustment mechanism
RBA Revenue balancing account
RFP Request for proposals
ROACE Return on average common equity
RORB Return on rate base
RPS Renewable portfolio standards
SEC Securities and Exchange Commission
See Means the referenced material is incorporated by reference
Tax Act
2017 Tax Cuts and Jobs Act (H.R. 1, An Act to provide for reconciliation pursuant to titles II and V of the concurrent resolution on the budget for fiscal year 2018)
TDR Troubled debt restructuring
UtilitiesHawaiian Electric Company, Inc., Hawaii Electric Light Company, Inc. and Maui Electric Company, Limited
VIE Variable interest entity
 
iii

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS
This report and other presentations made by Hawaiian Electric Industries, Inc. (HEI) and Hawaiian Electric Company, Inc. (Hawaiian Electric) and their subsidiaries contain “forward-looking statements,” which include statements that are predictive in nature, depend upon or refer to future events or conditions and usually include words such as “will,” “expects,” “anticipates,” “intends,” “plans,” “believes,” “predicts,” “estimates” or similar expressions. In addition, any statements concerning future financial performance, ongoing business strategies or prospects or possible future actions are also forward-looking statements. Forward-looking statements are based on current expectations and projections about future events and are subject to risks, uncertainties and the accuracy of assumptions concerning HEI and its subsidiaries (collectively, the Company), the performance of the industries in which they do business and economic, political and market factors, among other things. These forward-looking statements are not guarantees of future performance and actual results and financial condition may differ materially from those indicated in the forward-looking statements.
Risks, uncertainties and other important factors that could cause actual results to differ materially from those described in forward-looking statements and from historical results include, but are not limited to, the following:
•international, national and local economic and political conditions—including the state of the Hawaii tourism, defense and construction industries; the strength or weakness of the Hawaii and continental U.S. real estate markets (including the fair value and/or the actual performance of collateral underlying loans held by ASB, which could result in higher loan loss provisions and write-offs); decisions concerning the extent of the presence of the federal government and military in Hawaii; the implications and potential impacts of future Federal government shutdowns, including the impact to our customers to pay their electric bills and/or bank loans and the impact on the state of Hawaii economy; the implications and potential impacts of U.S. and foreign capital and credit market conditions and federal, state and international responses to those conditions; the potential impacts of global and local developments (including global economic conditions and uncertainties, unrest, terrorist acts, wars, conflicts, political protests, deadly virus epidemic or other crisis); the effects of changes that have or may occur in U.S. policy, such as with respect to immigration and trade; and pandemics;
•the extent of the impact of the COVID-19 pandemic, including the duration, spread, severity and any recurrence of the COVID-19 pandemic, the duration and scope of related government orders and restrictions, the impact on our employees, customers and suppliers, and the impact of the COVID-19 pandemic on the overall demand for the Company’s goods and services;
•citizen activism, including civil unrest, especially in times of severe economic depression and social divisiveness, which could negatively impact customers and employees, impair the ability of the Company and the Utilities to operate and maintain its facilities in an effective and safe manner, and citizen activism could delay the construction, increase project costs or preclude the completion, of third-party or Utility projects that are required to meet electricity demand, reliability objectives and RPS goals;
•the effects of future actions or inaction of the U.S. government or related agencies, including those related to the U.S. debt ceiling or budget funding, monetary policy, trade policy and tariffs, energy and environmental policy, and other policy and regulatory changes advanced or proposed by President Trump and his administration, or resulting from the outcome of the U.S. presidential election;
•weather, natural disasters (e.g., hurricanes, earthquakes, tsunamis, lightning strikes, lava flows and the increasing effects of climate change, such as more severe storms, flooding, droughts, heat waves, and rising sea levels) and wildfires, including their impact on the Company’s and Utilities’ operations and the economy;
•the timing, speed and extent of changes in interest rates and the shape of the yield curve, which could result in lower portfolio yields and net interest margin;
•the ability of the Company and the Utilities to access the credit and capital markets (e.g., to obtain commercial paper and other short-term and long-term debt financing, including lines of credit, and, in the case of HEI, to issue common stock) under volatile and challenging market conditions, and the cost of such financings, if available;
•the risks inherent in changes in the value of the Company’s pension and other retirement plan assets and ASB’s securities available for sale, and the risks inherent in changes in the value of the Company’s pension liabilities, including changes driven by interest rates;
•changes in laws, regulations (including tax regulations), market conditions, interest rates and other factors that result in changes in assumptions used to calculate retirement benefits costs and funding requirements;
•the impact of the Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010 (Dodd-Frank Act) and of the rules and regulations that the Dodd-Frank Act requires to be promulgated, as amended by the Economic Growth, Regulatory Relief and Consumer Protection Act;
•increasing competition in the banking industry (e.g., increased price competition for deposits, or an outflow of deposits to alternative investments, which may have an adverse impact on ASB’s cost of funds);
•the potential delay by the Public Utilities Commission of the State of Hawaii (PUC) in considering (and potential disapproval of actual or proposed) renewable energy proposals and related costs; reliance by the Utilities on outside parties such as the state, independent power producers (IPPs) and developers; and uncertainties surrounding technologies, solar power, wind power,
iv

biofuels, environmental assessments required to meet renewable portfolio standards (RPS) goals and the impacts of implementation of the renewable energy proposals on future costs of electricity;
•the ability of the Utilities to develop, implement and recover the costs of implementing the Utilities’ action plans included in their updated Power Supply Improvement Plans, Demand Response Portfolio Plan, Distributed Generation Interconnection Plan, Grid Modernization Plans, and business model changes, which have been and are continuing to be developed and updated in response to the orders issued by the PUC, the PUC’s April 2014 statement of its inclinations on the future of Hawaii’s electric utilities and the vision, business strategies and regulatory policy changes required to align the Utilities’ business model with customer interests and the state’s public policy goals, and subsequent orders of the PUC;
•capacity and supply constraints or difficulties, especially if generating units (utility-owned or IPP-owned) fail or measures such as demand-side management, distributed generation (DG), combined heat and power or other firm capacity supply-side resources fall short of achieving their forecasted benefits or are otherwise insufficient to reduce or meet peak demand;
•fuel oil price changes, delivery of adequate fuel by suppliers and the continued availability to the electric utilities of their energy cost recovery clauses (ECRCs);
•the continued availability to the electric utilities or modifications of other cost recovery mechanisms, including the purchased power adjustment clauses (PPACs), rate adjustment mechanisms (RAMs) and pension and postretirement benefits other than pensions (OPEB) tracking mechanisms, and the continued decoupling of revenues from sales to mitigate the effects of declining kilowatthour sales;
•the ability of the Utilities to recover increasing costs and earn a reasonable return on capital investments not covered by RAMs;
•the ability of the Utilities to achieve performance incentive goals currently in place;
•the impact from the PUC’s implementation of performance-based ratemaking for the Utilities pursuant to Act 005, Session Laws 2018, including the potential addition of new performance incentive mechanisms (PIMs), third-party proposals adopted by the PUC in its implementation of performance-based regulation (PBR), and the implications of not achieving performance incentive goals;
•the impact of fuel price levels and volatility on customer satisfaction and political and regulatory support for the Utilities;
•the risks associated with increasing reliance on renewable energy, including the availability and cost of non-fossil fuel supplies for renewable energy generation and the operational impacts of adding intermittent sources of renewable energy to the electric grid;
•the growing risk that energy production from renewable generating resources may be curtailed and the interconnection of additional resources will be constrained as more generating resources are added to the Utilities’ electric systems and as customers reduce their energy usage;
•the ability of IPPs to deliver the firm capacity anticipated in their power purchase agreements (PPAs);
•the potential that, as IPP contracts near the end of their terms, there may be less economic incentive for the IPPs to make investments in their units to ensure the availability of their units;
•the ability of the Utilities to negotiate, periodically, favorable agreements for significant resources such as fuel supply contracts and collective bargaining agreements and avoid or mitigate labor disputes and work stoppages;
•new technological developments that could affect the operations and prospects of the Utilities and ASB or their competitors such as the commercial development of energy storage and microgrids and banking through alternative channels;
•cybersecurity risks and the potential for cyber incidents, including potential incidents at HEI, its third-party vendors, and its subsidiaries (including at ASB branches and electric utility plants) and incidents at data processing centers used, to the extent not prevented by intrusion detection and prevention systems, anti-virus software, firewalls and other general IT controls;
•failure to achieve cost savings consistent with the minimum $246 million in Enterprise Resource Planning/Enterprise Asset Management (ERP/EAM) project-related benefits (including $150 million in operation and maintenance (O&M) benefits) to be delivered to customers over its 12-year estimated useful life and $25 million of annual cost reductions by the end of 2022 pursuant to a commitment made as a result of the management audit of Hawaiian Electric in its 2020 test year rate case;
•federal, state, county and international governmental and regulatory actions, such as existing, new and changes in laws, rules and regulations applicable to HEI, the Utilities and ASB (including changes in taxation and tax rates, increases in capital requirements, regulatory policy changes, environmental laws and regulations (including resulting compliance costs and risks of fines and penalties and/or liabilities), the regulation of greenhouse gas emissions, governmental fees and assessments (such as Federal Deposit Insurance Corporation assessments), and potential carbon “cap and trade” legislation that may fundamentally alter costs to produce electricity and accelerate the move to renewable generation);
•developments in laws, regulations and policies governing protections for historic, archaeological and cultural sites, and plant and animal species and habitats, as well as developments in the implementation and enforcement of such laws, regulations and policies;
•discovery of conditions that may be attributable to historical chemical releases, including any necessary investigation and remediation, and any associated enforcement, litigation or regulatory oversight;
•decisions by the PUC in rate cases and other proceedings (including the risks of delays in the timing of decisions, adverse changes in final decisions from interim decisions and the disallowance of project costs as a result of adverse regulatory audit reports or otherwise);
v

•decisions by the PUC and by other agencies and courts on land use, environmental and other permitting issues (such as required corrective actions, restrictions and penalties that may arise, such as with respect to environmental conditions or RPS);
•potential enforcement actions by the Office of the Comptroller of the Currency (OCC), the Federal Reserve Board (FRB), the Federal Deposit Insurance Corporation (FDIC) and/or other governmental authorities (such as consent orders, required corrective actions, restrictions and penalties that may arise, for example, with respect to compliance deficiencies under existing or new banking and consumer protection laws and regulations or with respect to capital adequacy);
•the risks associated with the geographic concentration of HEI’s businesses and ASB’s loans, ASB’s concentration in a single product type (i.e., first mortgages) and ASB’s significant credit relationships (i.e., concentrations of large loans and/or credit lines with certain customers);
•changes in accounting principles applicable to HEI and its subsidiaries, including the adoption of new U.S. accounting standards, the potential discontinuance of regulatory accounting related to PBR or other regulatory changes, the effects of potentially required consolidation of variable interest entities (VIEs), or required finance lease or on-balance-sheet operating lease accounting for PPAs with IPPs;
•downgrades by securities rating agencies in their ratings of the securities of HEI and Hawaiian Electric and their impact on results of financing efforts;
•faster than expected loan prepayments that can cause an acceleration of the amortization of premiums on loans and investments and the impairment of mortgage-servicing assets of ASB;
•changes in ASB’s loan portfolio credit profile and asset quality and/or mix, which may increase or decrease the required level of provision for credit losses, allowance for credit losses (ACL) and charge-offs;
•changes in ASB’s deposit cost or mix which may have an adverse impact on ASB’s cost of funds;
•unanticipated changes from the expected discontinuance of LIBOR and the transition to an alternative reference rate, which may include adverse impacts to the Company’s cost of capital, loan portfolio and interest income on loans;
•the final outcome of tax positions taken by HEI and its subsidiaries;
•the risks of suffering losses and incurring liabilities that are uninsured (e.g., damages to the Utilities’ transmission and distribution system and losses from business interruption) or underinsured (e.g., losses not covered as a result of insurance deductibles or other exclusions or exceeding policy limits);
•the ability of the Company’s non-regulated subsidiary, Pacific Current, LLC (Pacific Current), to achieve its performance and growth objectives, which in turn could affect its ability to service its non-recourse debt;
•the Company’s reliance on third parties and the risk of their non-performance, which has increased due to the impact from the COVID-19 pandemic; and
•other risks or uncertainties described elsewhere in this report and in other reports (e.g., “Item 1A. Risk Factors” in the Company’s Annual Report on Form 10-K) previously and subsequently filed by HEI and/or Hawaiian Electric with the Securities and Exchange Commission.
Forward-looking statements speak only as of the date of the report, presentation or filing in which they are made. Except to the extent required by the federal securities laws, HEI, Hawaiian Electric, ASB, Pacific Current and their subsidiaries undertake no obligation to publicly update or revise any forward-looking statements, whether written or oral and whether as a result of new information, future events or otherwise.
vi

PART I - FINANCIAL INFORMATION

Item 1.  Financial Statements

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Statements of Income (unaudited)
Three months ended September 30Nine months ended September 30
(in thousands, except per share amounts)2020201920202019
Revenues    
Electric utility$562,568 $688,330 $1,694,225 $1,900,609 
Bank78,644 82,548 233,096 247,287 
Other215 4 237 86 
Total revenues641,427 770,882 1,927,558 2,147,982 
Expenses    
Electric utility474,050 616,537 1,493,948 1,716,562 
Bank63,144 54,240 189,700 171,605 
Other4,672 3,450 13,091 12,589 
Total expenses541,866 674,227 1,696,739 1,900,756 
Operating income (loss)    
Electric utility88,518 71,793 200,277 184,047 
Bank15,500 28,308 43,396 75,682 
Other(4,457)(3,446)(12,854)(12,503)
Total operating income99,561 96,655 230,819 247,226 
Retirement defined benefits expense—other than service costs
(1,102)(648)(2,970)(2,172)
Interest expense, net—other than on deposit liabilities and other bank borrowings
(22,086)(22,425)(66,474)(69,081)
Allowance for borrowed funds used during construction801 1,208 2,241 3,465 
Allowance for equity funds used during construction2,347 3,250 6,556 9,335 
Gain on sale of investment securities, net— 653 9,275 653 
Income before income taxes79,521 78,693 179,447 189,426 
Income taxes14,018 14,803 30,691 36,390 
Net income65,503 63,890 148,756 153,036 
Preferred stock dividends of subsidiaries471 471 1,417 1,417 
Net income for common stock$65,032 $63,419 $147,339 $151,619 
Basic earnings per common share$0.60 $0.58 $1.35 $1.39 
Diluted earnings per common share$0.59 $0.58 $1.35 $1.39 
Weighted-average number of common shares outstanding109,181 108,973 109,126 108,941 
Net effect of potentially dilutive shares155 390 261 437 
Weighted-average shares assuming dilution109,336 109,363 109,387 109,378 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2019 Form 10-K.

1

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Statements of Comprehensive Income (unaudited)
 Three months ended September 30Nine months ended September 30
(in thousands)2020201920202019
Net income for common stock$65,032 $63,419 $147,339 $151,619 
Other comprehensive income (loss), net of taxes:    
Net unrealized gains on available-for-sale investment securities:    
Net unrealized gains on available-for-sale investment securities arising during the period, net of taxes of $360, $1,557, $7,836 and $10,194, respectively
984 4,253 21,405 27,846 
Reclassification adjustment for net realized gains included in net income, net of taxes of nil, (175), $(599) and (175), respectively
— (478)(1,638)(478)
Derivatives qualifying as cash flow hedges:    
Unrealized interest rate hedging losses arising during the period, net of taxes of $(51), $(208), $(739) and $(577), respectively
(147)(600)(2,129)(1,663)
Retirement benefit plans:    
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of taxes of $2,202, $741, $6,169 and $2,482, respectively
6,324 2,615 17,720 7,621 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $(1,985), $(865), $(5,563) and $(2,459), respectively
(5,721)(2,493)(16,038)(7,089)
Other comprehensive income, net of taxes1,440 3,297 19,320 26,237 
Comprehensive income attributable to Hawaiian Electric Industries, Inc.
$66,472 $66,716 $166,659 $177,856 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2019 Form 10-K.

2

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets (unaudited) 
(dollars in thousands)September 30, 2020December 31, 2019
Assets  
Cash and cash equivalents$193,126 $196,813 
Restricted cash21,881 30,872 
Accounts receivable and unbilled revenues, net276,299 300,794 
Available-for-sale investment securities, at fair value1,747,658 1,232,826 
Held-to-maturity investment securities, at amortized cost133,858 139,451 
Stock in Federal Home Loan Bank, at cost10,920 8,434 
Loans held for investment, net5,389,443 5,067,821 
Loans held for sale, at lower of cost or fair value16,806 12,286 
Property, plant and equipment, net of accumulated depreciation of $2,873,348 and $2,765,569 at September 30, 2020 and December 31, 2019, respectively
5,232,177 5,109,628 
Operating lease right-of-use assets169,062 199,171 
Regulatory assets677,683 715,080 
Other591,258 649,885 
Goodwill82,190 82,190 
Total assets$14,542,361 $13,745,251 
Liabilities and shareholders’ equity  
Liabilities  
Accounts payable$158,292 $220,633 
Interest and dividends payable34,271 24,941 
Deposit liabilities7,038,137 6,271,902 
Short-term borrowings—other than bank137,783 185,710 
Other bank borrowings151,875 115,110 
Long-term debt, net—other than bank2,068,852 1,964,365 
Deferred income taxes376,356 379,324 
Operating lease liabilities176,258 199,571 
Regulatory liabilities967,846 972,310 
Defined benefit pension and other postretirement benefit plans liability488,314 513,287 
Other586,853 583,545 
Total liabilities12,184,837 11,430,698 
Preferred stock of subsidiaries - not subject to mandatory redemption34,293 34,293 
Commitments and contingencies (Notes 3 and 4)
Shareholders’ equity  
Preferred stock, no par value, authorized 10,000,000 shares; issued: none
— — 
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding: 109,181,124 shares and 108,973,328 shares at September 30, 2020 and December 31, 2019, respectively
1,678,007 1,678,257 
Retained earnings645,943 622,042 
Accumulated other comprehensive loss, net of tax benefits(719)(20,039)
Total shareholders’ equity2,323,231 2,280,260 
Total liabilities and shareholders’ equity$14,542,361 $13,745,251 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2019 Form 10-K.

3

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Statements of Changes in Shareholders’ Equity (unaudited) 
 Common stockRetainedAccumulated
other
comprehensive		 
(in thousands)SharesAmountEarningsincome (loss)Total
Balance, December 31, 2019108,973 $1,678,257 $622,042 $(20,039)$2,280,260 
Impact of adoption of ASU No. 2016-13
— — (15,372)— (15,372)
Balance, January 1, 2020 after adoption of
ASU No. 2016-13		108,973 1,678,257 606,670 (20,039)2,264,888 
Net income for common stock— — 33,420 — 33,420 
Other comprehensive income, net of taxes— — — 18,212 18,212 
Share-based expenses and other, net172 (3,996)— — (3,996)
Common stock dividends (33¢ per share)
— — (36,019)— (36,019)
Balance, March 31, 2020109,145 1,674,261 604,071 (1,827)2,276,505 
Net income for common stock— — 48,887 — 48,887 
Other comprehensive loss, net of tax benefits— — — (332)(332)
Share-based expenses and other, net36 2,355 — — 2,355 
Common stock dividends (33¢ per share)
— — (36,017)— (36,017)
Balance, June 30, 2020109,181 1,676,616 616,941 (2,159)2,291,398 
Net income for common stock— — 65,032 — 65,032 
Other comprehensive income, net of taxes— — — 1,440 1,440 
Share-based expenses and other, net— 1,391 — — 1,391 
Common stock dividends (33¢ per share)
— — (36,030)— (36,030)
Balance, September 30, 2020109,181 $1,678,007 $645,943 $(719)$2,323,231 
Balance, December 31, 2018108,879 $1,669,267 $543,623 $(50,610)$2,162,280 
Net income for common stock— — 45,688 — 45,688 
Other comprehensive income, net of taxes— — — 9,241 9,241 
Share-based expenses and other, net58 1,166 — — 1,166 
Common stock dividends 32¢ per share)
— — (34,860)— (34,860)
Balance, March 31, 2019108,937 1,670,433 554,451 (41,369)2,183,515 
Net income for common stock— — 42,512 — 42,512 
Other comprehensive income, net of taxes— — — 13,699 13,699 
Share-based expenses and other, net35 3,720 — — 3,720 
Common stock dividends (32¢ per share)— — (34,860)— (34,860)
Balance, June 30, 2019108,972 1,674,153 562,103 (27,670)2,208,586 
Net income for common stock— — 63,419 — 63,419 
Other comprehensive income, net of taxes— — — 3,297 3,297 
Share-based expenses and other, net1 2,258 — — 2,258 
Common stock dividends (32¢ per share)— — (34,871)— (34,871)
Balance, September 30, 2019108,973 $1,676,411 $590,651 $(24,373)$2,242,689 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2019 Form 10-K.

4

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows (unaudited)
Nine months ended September 30
(in thousands)20202019
Cash flows from operating activities  
Net income$148,756 $153,036 
Adjustments to reconcile net income to net cash provided by operating activities  
Depreciation of property, plant and equipment178,674 172,307 
Other amortization39,580 35,553 
Provision for credit losses39,504 17,873 
Loans originated, held for sale(380,864)(190,700)
Proceeds from sale of loans, held for sale387,247 177,345 
Gain on sale of investment securities, net(9,275)(653)
Gain on sale of loans(15,933)(3,080)
Deferred income taxes(14,464)265 
Share-based compensation expense5,449 8,142 
Allowance for equity funds used during construction(6,556)(9,335)
Other(4,773)(6,157)
Changes in assets and liabilities  
Decrease in accounts receivable and unbilled revenues, net11,252 10,723 
Decrease (increase) in fuel oil stock31,899 (3,438)
Decrease in regulatory assets10,012 54,274 
Increase (decrease) in regulatory liabilities(15,755)2,494 
Increase (decrease) in accounts, interest and dividends payable(20,794)215 
Change in prepaid and accrued income taxes, tax credits and utility revenue taxes(32,750)(32,436)
Decrease in defined benefit pension and other postretirement benefit plans liability(1,398)(2,794)
Change in other assets and liabilities(37,543)(42,206)
Net cash provided by operating activities312,268 341,428 
Cash flows from investing activities  
Available-for-sale investment securities purchased(985,874)(4,823)
Principal repayments on available-for-sale investment securities331,238 194,845 
Proceeds from sale of available-for-sale investment securities169,157 19,810 
Principal repayments of held-to-maturity investment securities34,740 9,183 
Purchases of held-to-maturity investment securities(28,602)— 
Purchase of stock from Federal Home Loan Bank (24,006)(80,475)
Redemption of stock from Federal Home Loan Bank21,520 80,480 
Net increase in loans held for investment(374,307)(258,064)
Proceeds from sale of low-income housing investments6,725 — 
Capital expenditures(296,172)(332,273)
Contributions to low income housing investments(3,951)(5,612)
Other4,899 3,495 
Net cash used in investing activities(1,144,633)(373,434)
Cash flows from financing activities  
Net increase in deposit liabilities766,235 37,371 
Net increase (decrease) in short-term borrowings with original maturities of three months or less(112,710)64,844 
Net increase in other bank borrowings with original maturities of three months or less6,765 19,150 
Proceeds from issuance of short-term debt165,000 25,000 
Repayment of short-term debt(100,000)— 
Proceeds from issuance of other bank borrowings30,000 — 
Proceeds from issuance of long-term debt365,146 208,970 
Repayment of long-term debt and funds transferred for repayment of long-term debt(178,291)(204,278)
Withheld shares for employee taxes on vested share-based compensation(5,700)(997)
Common stock dividends(108,066)(104,591)
Preferred stock dividends of subsidiaries(1,417)(1,417)
Other(7,275)(4,266)
Net cash provided by financing activities819,687 39,786 
Net increase (decrease) in cash, cash equivalents and restricted cash(12,678)7,780 
Cash, cash equivalents and restricted cash, beginning of period227,685 169,208 
Cash, cash equivalents and restricted cash, end of period215,007 176,988 
Less: Restricted cash(21,881)— 
Cash and cash equivalents, end of period$193,126 $176,988 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2019 Form 10-K.
5

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Statements of Income (unaudited)
Three months ended September 30Nine months ended September 30
(in thousands)2020201920202019
Revenues$562,568 $688,330 $1,694,225 $1,900,609 
Expenses    
Fuel oil105,042 199,093 390,714 541,322 
Purchased power149,025 175,037 425,679 472,336 
Other operation and maintenance111,243 124,415 348,831 361,805 
Depreciation55,689 53,935 167,235 161,795 
Taxes, other than income taxes53,051 64,057 161,489 179,304 
Total expenses474,050 616,537 1,493,948 1,716,562 
Operating income88,518 71,793 200,277 184,047 
Allowance for equity funds used during construction2,347 3,250 6,556 9,335 
Retirement defined benefits expense—other than service costs
(432)(723)(1,195)(2,127)
Interest expense and other charges, net(16,836)(17,429)(50,768)(53,945)
Allowance for borrowed funds used during construction801 1,208 2,241 3,465 
Income before income taxes74,398 58,099 157,111 140,775 
Income taxes13,835 10,822 29,316 27,800 
Net income60,563 47,277 127,795 112,975 
Preferred stock dividends of subsidiaries228 228 686 686 
Net income attributable to Hawaiian Electric60,335 47,049 127,109 112,289 
Preferred stock dividends of Hawaiian Electric270 270 810 810 
Net income for common stock$60,065 $46,779 $126,299 $111,479 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2019 Form 10-K.
HEI owns all of the common stock of Hawaiian Electric. Therefore, per share data with respect to shares of common stock of Hawaiian Electric are not meaningful.

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Statements of Comprehensive Income (unaudited)
 Three months ended September 30Nine months ended September 30
(in thousands)2020201920202019
Net income for common stock$60,065 $46,779 $126,299 $111,479 
Other comprehensive income (loss), net of taxes:    
Retirement benefit plans:    
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of taxes of $2,001, $874, $5,597 and $2,484, respectively
5,769 2,519 16,137 7,162 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $(1,985), $(865), $(5,563) and $(2,459), respectively
(5,721)(2,493)(16,038)(7,089)
Other comprehensive income, net of taxes48 26 99 73 
Comprehensive income attributable to Hawaiian Electric Company, Inc.
$60,113 $46,805 $126,398 $111,552 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2019 Form 10-K.
6

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets (unaudited)
(dollars in thousands, except par value)September 30, 2020December 31, 2019
Assets  
Property, plant and equipment
Utility property, plant and equipment  
Land$51,589 $51,816 
Plant and equipment7,422,908 7,240,288 
Less accumulated depreciation(2,789,917)(2,690,157)
Construction in progress212,537 193,074 
Utility property, plant and equipment, net4,897,117 4,795,021 
Nonutility property, plant and equipment, less accumulated depreciation of $114 and $111 as of September 30, 2020 and December 31, 2019, respectively
6,954 6,956 
Total property, plant and equipment, net4,904,071 4,801,977 
Current assets  
Cash and cash equivalents29,800 11,022 
Restricted cash20,458 30,872 
Customer accounts receivable, net137,936 152,790 
Accrued unbilled revenues, net106,415 117,227 
Other accounts receivable, net7,074 11,568 
Fuel oil stock, at average cost60,443 91,937 
Materials and supplies, at average cost68,794 60,702 
Prepayments and other39,644 116,980 
Regulatory assets25,462 30,710 
Total current assets496,026 623,808 
Other long-term assets  
Operating lease right-of-use assets144,740 176,809 
Regulatory assets652,221 684,370 
Other125,246 101,718 
Total other long-term assets922,207 962,897 
Total assets$6,322,304 $6,388,682 
Capitalization and liabilities  
Capitalization  
Common stock ($6 2/3 par value, authorized 50,000,000 shares; outstanding 17,048,783 shares at
September 30, 2020 and December 31, 2019)
$113,678 $113,678 
Premium on capital stock714,824 714,824 
Retained earnings1,266,076 1,220,129 
Accumulated other comprehensive loss, net of tax benefits-retirement benefit plans(1,180)(1,279)
Common stock equity2,093,398 2,047,352 
Cumulative preferred stock — not subject to mandatory redemption34,293 34,293 
Long-term debt, net1,561,128 1,401,714 
Total capitalization3,688,819 3,483,359 
Commitments and contingencies (Note 3)
Current liabilities  
Current portion of operating lease liabilities64,906 63,707 
Current portion of long-term debt, net— 95,953 
Short-term borrowings from non-affiliates49,948 88,987 
Accounts payable118,480 187,770 
Interest and preferred dividends payable30,244 20,728 
Taxes accrued, including revenue taxes183,744 207,992 
Regulatory liabilities36,555 30,724 
Other75,050 67,305 
Total current liabilities558,927 763,166 
Deferred credits and other liabilities  
Operating lease liabilities86,175 113,400 
Deferred income taxes381,535 377,150 
Regulatory liabilities931,291 941,586 
Unamortized tax credits113,516 117,868 
Defined benefit pension and other postretirement benefit plans liability454,150 478,763 
Other107,891 113,390 
Total deferred credits and other liabilities2,074,558 2,142,157 
Total capitalization and liabilities$6,322,304 $6,388,682 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2019 Form 10-K.
7

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Statements of Changes in Common Stock Equity (unaudited)
 
 Common stockPremium
on
capital		RetainedAccumulated
other
comprehensive		 
(in thousands)SharesAmountstockearningsincome (loss)Total
Balance, December 31, 201917,048 $113,678 $714,824 $1,220,129 $(1,279)$2,047,352 
Net income for common stock— — — 23,905 — 23,905 
Other comprehensive income, net of taxes— — — — 26 26 
Common stock dividends— — — (26,784)— (26,784)
Balance, March 31, 202017,048 113,678 714,824 1,217,250 (1,253)2,044,499 
Net income for common stock— — — 42,329 — 42,329 
Other comprehensive income, net of taxes— — — — 25 25 
Common stock dividends— — — (26,784)— (26,784)
Balance, June 30, 202017,048 $113,678 714,824 1,232,795 (1,228)2,060,069 
Net income for common stock— — — 60,065 — 60,065 
Other comprehensive income, net of taxes— — — — 48 48 
Common stock dividends— — — (26,784)— (26,784)
Balance, September 30, 202017,048 $113,678 $714,824 $1,266,076 $(1,180)$2,093,398 
Balance, December 31, 201816,751 $111,696 $681,305 $1,164,541 $99 $1,957,641 
Net income for common stock— — — 32,126 — 32,126 
Other comprehensive income, net of taxes— — — — 24 24 
Common stock dividends— — — (25,313)— (25,313)
Balance, March 31, 201916,751 111,696 681,305 1,171,354 123 1,964,478 
Net income for common stock— — — 32,574 — 32,574 
Other comprehensive income, net of taxes— — — — 23 23 
Common stock dividends— — — (25,313)— (25,313)
Balance, June 30, 201916,751 111,696 681,305 $1,178,615 $146 $1,971,762 
Net income for common stock— — — 46,779 — 46,779 
Other comprehensive income, net of taxes— — — — 26 26 
Common stock dividends— — — (25,313)— (25,313)
Balance, September 30, 201916,751 $111,696 $681,305 $1,200,081 $172 $1,993,254 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2019 Form 10-K.


8

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows (unaudited)
Nine months ended September 30
(in thousands)20202019
Cash flows from operating activities  
Net income$127,795 $112,975 
Adjustments to reconcile net income to net cash provided by operating activities  
Depreciation of property, plant and equipment167,235 161,795 
Other amortization24,929 21,476 
Deferred income taxes(9,827)(1,386)
State refundable credit(7,589)(6,242)
Bad debt expense1,401 1,650 
Allowance for equity funds used during construction(6,556)(9,335)
Other1,614 613 
Changes in assets and liabilities  
Decrease in accounts receivable7,076 12,706 
Decrease (increase) in accrued unbilled revenues9,842 (2,101)
Decrease (increase) in fuel oil stock31,494 (4,608)
Increase in materials and supplies(8,092)(5,606)
Decrease in regulatory assets10,012 54,274 
Increase (decrease) in regulatory liabilities(15,755)2,494 
Decrease in accounts payable(34,874)(9,261)
Change in prepaid and accrued income taxes, tax credits and revenue taxes(34,768)(32,094)
Decrease in defined benefit pension and other postretirement benefit plans liability(3,064)(2,837)
Change in other assets and liabilities(15,918)(11,895)
Net cash provided by operating activities244,955 282,618 
Cash flows from investing activities  
Capital expenditures(267,482)(297,807)
Other7,295 2,662 
Net cash used in investing activities(260,187)(295,145)
Cash flows from financing activities  
Common stock dividends(80,352)(75,939)
Preferred stock dividends of Hawaiian Electric and subsidiaries(1,496)(1,496)
Proceeds from issuance of short-term debt100,000 25,000 
Repayment of short-term debt(100,000)— 
Proceeds from issuance of long-term debt255,000 200,000 
Repayment of long-term debt and funds transferred for repayment of long-term debt(109,000)(201,546)
Net Increase (decrease) in short-term borrowings from non-affiliates and affiliates with original maturities of three months or less(38,987)62,353 
Other(1,569)785 
Net cash provided by financing activities23,596 9,157 
Net increase (decrease) in cash and cash equivalents8,364 (3,370)
Cash, cash equivalents and restricted cash, beginning of period41,894 35,877 
Cash, cash equivalents and restricted cash, end of period50,258 32,507 
Less: Restricted cash(20,458)— 
Cash and cash equivalents, end of period$29,800 $32,507 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2019 Form 10-K.

9

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
Note 1 · Basis of presentation
The accompanying unaudited condensed consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (GAAP) for interim financial information, the instructions to SEC Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In preparing the unaudited condensed consolidated financial statements, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the balance sheet and the reported amounts of revenues and expenses for the period. Actual results could differ significantly from those estimates. The accompanying unaudited condensed consolidated financial statements and the following notes should be read in conjunction with the audited consolidated financial statements and the notes thereto in HEI’s and Hawaiian Electric’s Form 10-K for the year ended December 31, 2019.
In the opinion of HEI’s and Hawaiian Electric’s management, the accompanying unaudited condensed consolidated financial statements contain all material adjustments required by GAAP to fairly state consolidated HEI’s and Hawaiian Electric’s financial positions as of September 30, 2020 and December 31, 2019 and the results of their operations for the three and nine months ended September 30, 2020 and 2019 and cash flows for the nine months ended September 30, 2020 and 2019. All such adjustments are of a normal recurring nature, unless otherwise disclosed below or in other referenced material. Results of operations for interim periods are not necessarily indicative of results for the full year.
Recent accounting pronouncements.
Credit losses. In June 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” which replaces the incurred loss methodology with an expected loss methodology. The new methodology is referred to as the current expected credit loss (CECL) methodology and applies to financial assets subject to credit losses and measured at amortized cost and certain off-balance sheet credit exposures. This includes, but is not limited to loans, loan commitments and held-to-maturity securities. In addition, ASU No. 2016-13 amends the accounting for credit losses on available-for-sale (AFS) debt securities and purchased financial assets with credit deterioration. The other-than-temporary impairment model of accounting for credit losses on AFS debt securities has been replaced with an estimate of expected credit losses only when the fair value is below the amortized cost of the asset. The length of time the fair value of an AFS debt security has been below the amortized cost will no longer impact the determination of whether a credit loss exists. The AFS debt security model requires the use of an allowance to record the estimated losses (and subsequent recoveries).
The Company adopted ASU No. 2016-13 on January 1, 2020 using the modified retrospective method with the cumulative effect of initially applying the amendments recognized in retained earnings as of January 1, 2020. The CECL models use a probability-of-default, loss given default and exposure at default methodology to estimate the expected credit losses. Within each model or calculation, loans are further segregated based on additional risk characteristics specific to that loan type, such as risk rating, FICO score, bankruptcy score, age of loan and collateral. The Company uses both internal and external historical data, as appropriate, and a blend of economic forecasts to estimate credit losses over a reasonable and supportable forecast period and then reverts to a longer-term historical loss experience to arrive at lifetime expected credit losses. The reversion period incorporates forward-looking expectations about repayments (including prepayments) as determined by the Company’s asset liability management system.
The allowance for credit losses (ACL) is a material estimate of the Company. As a result of the change from an incurred loss model to a methodology that considers the credit loss over the expected life of the loan, on January 1, 2020, the Company recorded an adjustment of $21 million to increase the ACL, including a $2 million increase in the allowance for loan commitments, with a corresponding adjustment to reduce retained earnings by $15 million on an after-tax basis. The ACL is based on the composition, characteristics and quality of the loans and off balance sheet credit exposures as well as the prevailing economic conditions as of the adoption date. The increase in the ACL primarily relates to required reserves for residential mortgages and consumer loans, due to the requirement to estimate lifetime expected credit losses, with lower ACL requirements for commercial and commercial real estate loans due to their short-term nature. Based on the credit quality of the Company’s existing held-to-maturity and AFS investment securities portfolio, the Company did not recognize an ACL at adoption for those investments. The adoption of the new standard did not have a material impact to the Utilities’ customer and other accounts receivables and accrued unbilled revenue. Results for reporting periods beginning after January 1, 2020 are presented under ASU No. 2016-13 while prior period amounts continue to be reported in accordance with previously applicable GAAP.
10

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The table below summarizes the impact of the Company’s adoption of ASU No. 2016-13.
January 1, 2020
(in thousands)Pre-ASU No. 2016-13 adoption
Impact of ASU No. 2016-13
As reported under ASU No. 2016-13
HEI consolidated
Loans held for investments, net1
$5,067,821 $(19,441)$5,048,380 
Total assets$13,745,251 $(19,441)$13,725,810 
Deferred income taxes$379,324 $(5,628)$373,696 
Other1
583,545 1,559 585,104 
Total liabilities11,430,698 (4,069)11,426,629 
Retained earnings622,042 (15,372)606,670 
Total shareholders’ equity2,280,260 (15,372)2,264,888 
Total liabilities and shareholders’ equity$13,745,251 $(19,441)$13,725,810 
1 The allowance for credit losses is classified in “Loans held for investments, net,” and the allowance for loan commitments is classified in “Other” liabilities in the Company’s condensed consolidated balance sheets.

Reference Rate Reform. In March 2020, the FASB issued ASU No. 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting.” ASU 2020-04 provides optional guidance for a limited period of time to ease the potential impacts of transitioning away from reference rates which are expected to be discontinued, such as the London Interbank Offered Rate (LIBOR). The amendments in this ASU apply only to contracts, hedging relationships, and other transactions that reference LIBOR or another reference rate expected to be discontinued. The guidance is effective upon issuance and generally can be applied through December 2022. The Company is evaluating the options provided by ASU 2020-04 and is evaluating the impact on its consolidated financial statements and related disclosures.

Reclassifications. Certain reclassifications of prior year amounts were made to conform to the current-year financial statement presentation. Reclassifications did not affect previously reported cash flows, net income or retained earnings.

11

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Note 2 · Segment financial information
(in thousands) Electric utilityBankOtherTotal
Three months ended September 30, 2020    
Revenues from external customers$562,559 $78,644 $224 $641,427 
Intersegment revenues (eliminations)9 — (9)— 
Revenues$562,568 $78,644 $215 $641,427 
Income (loss) before income taxes$74,398 $15,027 $(9,904)$79,521 
Income taxes (benefit)13,835 2,877 (2,694)14,018 
Net income (loss)60,563 12,150 (7,210)65,503 
Preferred stock dividends of subsidiaries498 — (27)471 
Net income (loss) for common stock$60,065 $12,150 $(7,183)$65,032 
Nine months ended September 30, 2020    
Revenues from external customers$1,694,195 $233,096 $267 $1,927,558 
Intersegment revenues (eliminations)30 — (30)— 
Revenues$1,694,225 $233,096 $237 $1,927,558 
Income (loss) before income taxes$157,111 $51,330 $(28,994)$179,447 
Income taxes (benefit)29,316 9,405 (8,030)30,691 
Net income (loss)127,795 41,925 (20,964)148,756 
Preferred stock dividends of subsidiaries1,496 — (79)1,417 
Net income (loss) for common stock$126,299 $41,925 $(20,885)$147,339 
Total assets (at September 30, 2020)
$6,322,304 $8,075,745 $144,312 $14,542,361 
Three months ended September 30, 2019    
Revenues from external customers$688,299 $82,548 $35 $770,882 
Intersegment revenues (eliminations)31 — (31)— 
Revenues$688,330 $82,548 $4 $770,882 
Income (loss) before income taxes$58,099 $29,157 $(8,563)$78,693 
Income taxes (benefit)10,822 6,269 (2,288)14,803 
Net income (loss)47,277 22,888 (6,275)63,890 
Preferred stock dividends of subsidiaries498 — (27)471 
Net income (loss) for common stock $46,779 $22,888 $(6,248)$63,419 
Nine months ended September 30, 2019    
Revenues from external customers$1,900,552 $247,287 $143 $2,147,982 
Intersegment revenues (eliminations)57 — (57)— 
Revenues$1,900,609 $247,287 $86 $2,147,982 
Income (loss) before income taxes$140,775 $76,611 $(27,960)$189,426 
Income taxes (benefit)27,800 15,868 (7,278)36,390 
Net income (loss)112,975 60,743 (20,682)153,036 
Preferred stock dividends of subsidiaries1,496 — (79)1,417 
Net income (loss) for common stock $111,479 $60,743 $(20,603)$151,619 
Total assets (at December 31, 2019)$6,388,682 $7,233,017 $123,552 $13,745,251 
 
Intercompany electricity sales of the Utilities to the bank and “other” segments are not eliminated because those segments would need to purchase electricity from another source if it were not provided by the Utilities and the profit on such sales is nominal.
Bank fees that ASB charges the Utilities and “other” segments are not eliminated because those segments would pay fees to another financial institution if they were to bank with another institution and the profit on such fees is nominal.
Hamakua Energy, LLC’s (Hamakua Energy’s) sales to Hawaii Electric Light (a regulated affiliate) are eliminated in consolidation.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Note 3 · Electric utility segment
Unconsolidated variable interest entities.
Power purchase agreements.  As of September 30, 2020, the Utilities had four PPAs for firm capacity (excluding the Puna Geothermal Ventures (PGV) PPA as PGV has been offline since May 2018 due to lava flow on Hawaii Island) and other PPAs with independent power producers (IPPs) and Schedule Q providers (i.e., customers with cogeneration and/or power production facilities who buy power from or sell power to the Utilities), none of which are currently required to be consolidated as VIEs.
Pursuant to the current accounting standards for VIEs, the Utilities are deemed to have a variable interest in Kalaeloa Partners, L.P. (Kalaeloa), AES Hawaii, Inc. (AES Hawaii) and Hamakua Energy by reason of the provisions of the PPA that the Utilities have with the three IPPs. However, management has concluded that the Utilities are not the primary beneficiary of Kalaeloa, AES Hawaii and Hamakua Energy because the Utilities do not have the power to direct the activities that most significantly impact the three IPPs’ economic performance nor the obligation to absorb their expected losses, if any, that could potentially be significant to the IPPs. Thus, the Utilities have not consolidated Kalaeloa, AES Hawaii and Hamakua Energy in its condensed consolidated financial statements. Hamakua Energy is an indirect subsidiary of Pacific Current and is consolidated in HEI’s condensed consolidated financial statements.
For the other PPAs with IPPs, the Utilities have concluded that the consolidation of the IPPs was not required because either the Utilities do not have variable interests in the IPPs due to the absence of an obligation in the PPAs for the Utilities to absorb any variability of the IPPs, or the IPP was considered a “governmental organization,” and thus excluded from the scope of accounting standards for VIEs. Two IPPs of as-available energy declined to provide the information necessary for Utilities to determine the applicability of accounting standards for VIEs. If information is ultimately received from the IPPs, a possible outcome of future analyses of such information is the consolidation of one or both of such IPPs in the unaudited condensed consolidated financial statements. The consolidation of any significant IPP could have a material effect on the unaudited condensed consolidated financial statements, including the recognition of a significant amount of assets and liabilities and, if such a consolidated IPP were operating at a loss and had insufficient equity, the potential recognition of such losses. If the Utilities determine they are required to consolidate the financial statements of such an IPP and the consolidation has a material effect, the Utilities would retrospectively apply accounting standards for VIEs to the IPP.
Commitments and contingencies.
Contingencies. The Utilities are subject in the normal course of business to pending and threatened legal proceedings. Management does not anticipate that the aggregate ultimate liability arising out of these pending or threatened legal proceedings will be material to its financial position. However, the Utilities cannot rule out the possibility that such outcomes could have a material effect on the results of operations or liquidity for a particular reporting period in the future.
Power purchase agreements.  Purchases from all IPPs were as follows:
 Three months ended September 30Nine months ended September 30
(in millions)2020201920202019
Kalaeloa$39 $58 $111 $159 
AES Hawaii33 38 96 102 
HPOWER18 20 52 57 
Hamakua Energy12 17 36 51 
Wind IPPs30 30 83 73 
Solar IPPs17 11 45 26 
Other IPPs 1
— 2 3 4 
Total IPPs$149 $176 $426 $472 
 
1Includes hydro power and other PPAs
Kalaeloa Partners, L.P.  Under a 1988 PPA, as amended, Hawaiian Electric is committed to purchase 208 MW of firm capacity from Kalaeloa. Hawaiian Electric and Kalaeloa continue negotiations to address the PPA term that ended on May 23, 2016. The PPA automatically extends on a month-to-month basis as long as the parties are still negotiating in good faith. Hawaiian Electric and Kalaeloa have agreed that neither party will terminate the PPA (which has been subject to automatic extension on a month-to-month basis) prior to November 20, 2020, to allow for a negotiated resolution and PUC approval.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
AES Hawaii, Inc. Under a PPA entered into in March 1988, as amended (through Amendment No. 2) for a period of 30 years ending September 2022, Hawaiian Electric agreed to purchase 180 MW of firm capacity from AES Hawaii. Hawaiian Electric and AES Hawaii have been in dispute over an additional 9 MW of capacity. In February 2018, Hawaiian Electric reached agreement with AES Hawaii on an amendment to the PPA. However, in June 2018, the PUC issued an order suspending review of the amendment pending a Department of Health of the State of Hawaii (DOH) decision on AES Hawaii’s request for approval of its Emission Reduction Plan and partnership with Hawaiian Electric. If approved by the PUC, the amendment will resolve AES Hawaii’s claims related to the additional capacity.
Hu Honua Bioenergy, LLC (Hu Honua). In May 2012, Hawaii Electric Light signed a PPA, which the PUC approved in December 2013, with Hu Honua for 21.5 MW of renewable, dispatchable firm capacity fueled by locally grown biomass from a facility on the island of Hawaii. Under the terms of the PPA, the Hu Honua plant was scheduled to be in service in 2016. However, Hu Honua encountered construction and litigation delays, which resulted in an amended and restated PPA between Hawaii Electric Light and Hu Honua dated May 9, 2017. In July 2017, the PUC approved the amended and restated PPA, which becomes effective once the PUC’s order is final and non-appealable. In August 2017, the PUC’s approval was appealed by a third party. On May 10, 2019, the Hawaii Supreme Court issued a decision remanding the matter to the PUC for further proceedings consistent with the court’s decision which must include express consideration of Green House Gas (GHG) emissions that would result from approving the PPA, whether the cost of energy under the PPA is reasonable in light of the potential for GHG emissions, and whether the terms of the PPA are prudent and in the public interest, in light of its potential hidden and long-term consequences. On June 20, 2019, the PUC issued an order reopening the docket for further proceedings, including re-examining all of the issues in the proceedings. On September 29, 2019, the PUC issued an order setting the procedural schedule for the matter and on December 20, 2019, issued an order modifying the procedural schedule. Pre-hearing matters were completed on March 6, 2020. On July 9, 2020, the PUC issued an order denying the Hawaii Electric Light’s request to waive the amended and restated PPA from the PUC’s competitive bidding requirements and therefore, dismissed the request for approval of the amended and restated PPA without prejudice to possible participation in any future competitive bidding process. On July 20, 2020, Hu Honua filed a motion for reconsideration of the PUC’s order which was denied by the PUC on September 9, 2020. On September 16 2020, Hu Honua filed its notice of appeal to the Hawaii Supreme Court of the PUC’s order denying Hu Honua’s motion for reconsideration.
Molokai New Energy Partners (MNEP). In July 2018, the PUC approved Maui Electric’s PPA with MNEP to purchase solar energy from a PV plus battery storage project. The 4.88 MW PV and 3 MW Battery Energy Storage System project was to deliver no more than 2.64 MW at any time to the Molokai system. On March 25, 2020, MNEP filed a complaint in the United Stated District Court for the District of Hawaii against Maui Electric claiming breach of contract. On June 3, 2020, Maui Electric provided Notice of Default and Termination of the PPA to MNEP terminating the PPA with an effective date of July 10, 2020. Thereafter, MNEP filed an amended Complaint to include claims relating to the termination and Hawaiian Electric filed its Answer to the Amended Complaint on September 11, 2020, disputing the facts presented by MNEP and all claims within the original and amended complaint.
Utility projects.  Many public utility projects require PUC approval and various permits from other governmental agencies. Difficulties in obtaining, or the inability to obtain, the necessary approvals or permits can result in significantly increased project costs or even cancellation of projects. In the event a project does not proceed, or if it becomes probable the PUC will disallow cost recovery for all or part of a project, or if PUC-imposed caps on project costs are expected to be exceeded, project costs may need to be written off in amounts that could result in significant reductions in Hawaiian Electric’s consolidated net income.
Enterprise Resource Planning/Enterprise Asset Management (ERP/EAM) implementation project. The ERP/EAM Implementation Project went live in October 2018. Hawaii Electric Light and Hawaiian Electric began to incorporate their portion of the deferred project costs in rate base and started the amortization over a 12-year period in January 2020 and November 2020, respectively. As of September 30, 2020, the total deferred project costs and accrued carrying costs after the project went into service amounted to $59.5 million, which is net of the amortization of $0.5 million at Hawaii Electric Light.
In February 2019, the PUC approved a methodology for passing the future cost saving benefits of the new ERP/EAM system to customers developed by the Utilities in collaboration with the Consumer Advocate. The Utilities filed a benefits clarification document on June 10, 2019, reflecting $150 million in future net O&M expense reductions and cost avoidance, and $96 million in capital cost reductions and tax savings over the 12-year service life. To the extent the reduction in O&M expense relates to amounts reflected in electric rates, the Utilities would reduce future rates for such amounts. In October 2019, the PUC approved the Utilities and the Consumer Advocate’s Stipulated Performance Metrics and Tracking Mechanism. As of September 30, 2020, the Utilities’ regulatory liability was $9.7 million for amounts to be returned to customers for reduction in O&M expense included in rates. As part of the settlement agreement approved in the Hawaiian Electric 2020 test year rate case, O&M benefits for Hawaiian Electric have been flowed through to customers as of October 2020.
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At the PUC’s direction, the Utilities have been filing Semi-Annual Enterprise System Benefits (SAESB) reports. The most recent SAESB report was filed on August 31, 2020 for the period January 1 through June 30, 2020.
Environmental regulation.  The Utilities are subject to environmental laws and regulations that regulate the operation of existing facilities, the construction and operation of new facilities and the proper cleanup and disposal of hazardous waste and toxic substances.
Hawaiian Electric, Hawaii Electric Light and Maui Electric, like other utilities, periodically encounter petroleum or other chemical releases associated with current or previous operations. The Utilities report and take action on these releases when and as required by applicable law and regulations. The Utilities believe the costs of responding to such releases identified to date will not have a material effect, individually or in the aggregate, on Hawaiian Electric’s consolidated results of operations, financial condition or liquidity.
Former Molokai Electric Company generation site.  In 1989, Maui Electric acquired Molokai Electric Company. Molokai Electric Company had sold its former generation site (Site) in 1983, but continued to operate at the Site under a lease until 1985. The Environmental Protection Agency (EPA) has since identified environmental impacts in the subsurface soil at the Site. In cooperation with the DOH and EPA, Maui Electric further investigated the Site and the Adjacent Parcel to determine the extent of impacts of polychlorinated biphenyls (PCBs), residual fuel oils and other subsurface contaminants. Maui Electric has a reserve balance of $2.7 million as of September 30, 2020, representing the probable and reasonably estimable undiscounted cost for remediation of the Site and the Adjacent Parcel; however, final costs of remediation will depend on the cleanup approach implemented.
Pearl Harbor sediment study. In July 2014, the U.S. Navy notified Hawaiian Electric of the Navy’s determination that Hawaiian Electric is a Potentially Responsible Party responsible for the costs of investigation and cleanup of PCB contamination in sediment in the area offshore of the Waiau Power Plant as part of the Pearl Harbor Superfund Site. Hawaiian Electric was also required by the EPA to assess potential sources and extent of PCB contamination onshore at Waiau Power Plant.
As of September 30, 2020, the reserve account balance recorded by Hawaiian Electric to address the PCB contamination was $4.6 million. The reserve balance represents the probable and reasonably estimable undiscounted cost for the onshore investigation and the remediation of PCB contamination in the offshore sediment. The final remediation costs will depend on the potential onshore source control requirements and actual offshore cleanup costs.
Regulatory proceedings
Decoupling. Decoupling is a regulatory model that is intended to provide the Utilities with financial stability and facilitate meeting the State of Hawaii’s goals to transition to a clean energy economy and achieve an aggressive renewable portfolio standard. The decoupling mechanism has the following major components: (1) monthly revenue balancing account (RBA) revenues or refunds for the difference between PUC-approved target revenues and recorded adjusted revenues, which delinks revenues from kilowatthour sales, (2) rate adjustment mechanism (RAM) revenues for escalation in certain O&M expenses and rate base changes, (3) major project interim recovery (MPIR) component, (4) performance incentive mechanisms (PIMs), and (5) an earnings sharing mechanism, which would provide for a reduction of revenues between rate cases in the event the utility exceeds the return on average common equity (ROACE) allowed in its most recent rate case.
Rate adjustment mechanism. The RAM is based on the lesser of: a) an inflationary adjustment for certain O&M expenses and return on investment for certain rate base changes, or b) cumulative annual compounded increase in Gross Domestic Product Price Index applied to annualized target revenues (the RAM Cap). Annualized target revenues may be reset upon the issuance of an interim or final decision and order (D&O) in a rate case. All Utilities were limited to the RAM Cap in 2020.
Major project interim recovery. On April 27, 2017, the PUC issued an order that provided guidelines for interim recovery of revenues to support major projects placed in service between general rate cases.
Projects eligible for recovery through the MPIR adjustment mechanism are major projects (i.e., projects with capital expenditures net of customer contributions in excess of $2.5 million), including, but not restricted to, renewable energy, energy efficiency, utility scale generation, grid modernization and smaller qualifying projects grouped into programs for review. The MPIR adjustment mechanism provides the opportunity to recover revenues for approved costs of eligible projects placed in service between general rate cases wherein cost recovery is limited by a revenue cap and is not provided by other effective recovery mechanisms. The request for PUC approval must include a business case, and all costs that are allowed to be recovered through the MPIR adjustment mechanism must be offset by any related benefits. The guidelines provide for accrual of revenues approved for recovery upon in-service date to be collected from customers through the annual RBA tariff. Capital
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projects that are not recovered through the MPIR would be included in the RAM and be subject to the RAM Cap, until the next rate case when the Utilities would request recovery in base rates.
The 2019 approved MPIR amounts for Schofield Generating Station of $19.8 million (which accrued effective January 1, 2019), included the 2019 return on project amount (based on the 90% cap on cost recovery of the project through any mechanism other than base rates) in rate base, depreciation and incremental O&M expenses, are collected from June 2020 through May 2021.
The PUC approved the Utilities’ requests for MPIR recovery of the cost of the Grid Modernization Strategy Phase 1 project and West Loch Photovoltaic (PV) project in March and December 2019, respectively. On June 5, 2020, the Utilities submitted 2020 MPIR amounts totaling $23.6 million for the Schofield Generation Station ($19.2 million), West Loch PV project ($3.8 million) and Grid Modernization Strategy Phase 1 project ($0.6 million for all three utilities) for the accrual of revenues effective January 1, 2020, that included the 2020 return on project amount (based on the capped amount) in rate base, depreciation and incremental O&M expenses, for collection from June 2021 through May 2022.
On October 22, 2020, the PUC issued the final D&O in Hawaiian Electric’s 2020 test year rate case approving the parties’ settlement agreement, including the parties’ agreement to remove the 90% cap on cost recovery for the Schofield Generating Station, such that 100% of the allowed project costs will flow through the MPIR mechanism. The 2020 MPIR amounts will be revised to reflect the new lower depreciation rates effective January 1, 2020 as approved in the Hawaiian Electric 2020 test year rate case, and for the removal of the 90% cap on cost recovery and revised rate of return effective November 1, 2020.
Performance incentive mechanisms. The PUC has established the following PIMs: (1) Service Quality performance incentives, (2) Phase 1 RFP PIM for procurement of low-cost renewable energy, (3) Phase 2 RFP PIMs for generation and generation plus storage project, and Grid Services and standalone storage.
•Service Quality performance incentives (ongoing). Service Quality performance incentives are measured on a calendar-year basis. The PIM tariff requires the performance targets, deadbands and the amount of maximum financial incentives used to determine the PIM financial incentive levels for each of the PIMs to be re-determined upon issuance of an interim or final order in a general rate case for each utility.
•Service Reliability Performance measured by System Average Interruption Duration and Frequency Indexes (penalties only). Target performance is based on each utility’s historical 10-year average performance with a deadband of one standard deviation. The maximum penalty for each performance index is 20 basis points applied to the common equity share of each respective utility’s approved rate base (or maximum penalties of approximately $6.8 million - for both indices in total for the three utilities).
•Call Center Performance measured by the percentage of calls answered within 30 seconds. Target performance is based on the annual average performance for each utility for the most recent 8 quarters with a deadband of 3% above and below the target. The maximum penalty or reward is 8 basis points applied to the common equity share of each respective utility’s approved rate base (or maximum penalties or rewards of approximately $1.4 million - in total for the three utilities).
•In December 2019, the Utilities accrued $0.3 million in estimated rewards for call center performance, net of service reliability penalties, for 2019. The net service quality performance rewards related to 2019 was reflected in the 2020 annual decoupling filing and increased customer rates in the period June 1, 2020 through May 31, 2021.
•Phase 1 RFP PIM. Procurement of low-cost variable renewable resources through the request for proposal process in 2018 is measured by comparison of the procurement price to target prices. The incentive is a percentage of the savings determined by comparing procured price to a target of 11.5 cents per kilowatt-hour for renewable projects with storage capability and 9.5 cents per kilowatt-hour for energy-only renewable projects. Half of the incentive was earned upon PUC approval of the PPAs and the other half is eligible to be earned in the year following the in-service date of the projects and is dependent on the amount of energy the Utilities receive from the facilities. The total amount of the incentive the Utilities are eligible for is capped at $3.5 million. Based on the seven PPAs approved in 2019, the Utilities recognized $1.7 million in 2019.
•Phase 2 RFP PIMs. On October 9, 2019, the PUC issued an order establishing PIMs for the Utilities with regards to the Variable Renewable Dispatchable Generation and Energy Storage requests for proposals (RFPs) as well as the Delivery of Grid Services via Customer-sited Distributed Energy Resources RFPs that were issued on August 22, 2019 for Oahu, Maui and Hawaii island. The order establishes pricing thresholds, timelines to complete contracting, and other performance criteria for the performance incentive eligibility. The PIMs provide incentives only without penalties. The earliest the Utilities would be eligible for a PIM pursuant to this order is upon PUC approval of
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executed contracts resulting from the Phase 2 RFPs. The order requires contracts under the Grid Service RFP be filed for approval by May 2020 (subsequently extended to July 9, 2020), and by September 2020 under the Renewable RFPs, with a declining PIM for projects that are not filed by these deadlines. On July 9, 2020, the Utilities filed two Grid Service Purchase Agreements for the Grid Service RFP, which qualify for PIMs, however, details of the incentive metrics will be determined by PUC. On September 15, 2020, the Utilities filed eight power purchase agreements for the Phase 2 RFP. Of those eight, only one project qualified for a potential PIM incentive payout. The Utilities do not anticipate that any of the remaining projects from the Phase 2 RFP will qualify for PIM payouts.
Annual decoupling filings. The net annual incremental amounts to be collected (refunded) from June 1, 2020 through May 31, 2021 are as follows:
(in millions)Hawaiian ElectricHawaii Electric LightMaui ElectricTotal
2020 Annual incremental RAM adjusted revenues
$20.6 $3.2 $5.7 $29.5 
Annual change in accrued RBA balance as of December 31, 2019 (and associated revenue taxes) which incorporates MPIR recovery
(46.5)(9.9)(11.0)(67.4)
Incremental Performance Incentive Mechanisms (net)
2.2 (0.1)(0.1)2.0 
Net annual incremental amount to be collected (refunded) under the tariffs$(23.7)$(6.8)$(5.4)$(35.9)

Performance-based regulation proceeding. On April 18, 2018, the PUC issued an order, instituting a proceeding to investigate performance-based regulation (PBR). The PUC stated that PBR seeks to utilize both revenue adjustment mechanisms and performance mechanisms to more strongly align utilities’ incentives with customer interests.
The order stated that, in general, the PUC is interested in ratemaking elements and/or mechanisms that result in:
•Greater cost control and reduced rate volatility;
•Efficient investment and allocation of resources regardless of classification as capital or operating expense;
•Fair distribution of risks between utilities and customers; and
•Fulfillment of State policy goals.
The proceeding has two phases. Phase 1 concluded in May 2019 with the issuance of a PUC order, which established guiding principles, regulatory goals, and priority outcomes to guide the development of the PBR mechanisms in Phase 2. The PUC identified the following guiding principles, which will inform the development of the PBR framework: 1) a customer-centric approach, 2) administrative efficiency to reduce regulatory burdens; and 3) utility financial integrity to maintain the utility’s financial health. Priority goals (and priority outcomes) identified by the PUC were: enhance customer experience (affordability, reliability, interconnection experience, and customer engagement), improve utility performance (cost control, distributed energy resources (DER) asset effectiveness, and grid investment efficiency), and advance societal outcomes (capital formation, customer equity, greenhouse gas reduction, electrification of transportation, and resilience).
The order also outlined the PUC’s vision of a comprehensive PBR framework that would be further developed in Phase 2. The framework envisioned would include 1) a five-year multi-year rate plan with an index-driven annual revenue adjustment based on an inflation factor, an X-factor which would encompass productivity, a Z-factor to account for exceptional circumstances not in the utility’s control and a customer dividend, 2) a symmetric earnings sharing mechanism that would help ensure that utility earnings do not excessively benefit or suffer from external factors outside of utility control or unforeseen results of regulatory mechanisms, 3) off-ramp provisions, 4) continuation of the RBA, MPIR adjustment mechanism, the pension and OPEB tracking mechanism, and other recovery mechanisms, and 5) a portfolio of performance incentive mechanisms for customer engagement and DER asset effectiveness (rewards only), and interconnection experience (both rewards and penalties), in addition to scorecards to track progress against targeted performance levels, shared savings mechanisms to apportion savings to the utility and customers, and reported metrics.
The Phase 2 schedule included working group meetings through the first half of 2020, followed by statements of positions that were filed in June 2020. In August 2020, the Parties filed their respective Phase 2 Reply Statement of Positions. In September 2020, the PUC held its hearing, and the Parties filed the post-hearing briefs in October 2020. The PUC’s decision is expected in December 2020.
Most recent rate proceedings.
Hawaiian Electric 2020 test year rate case. On May 27, 2020, Hawaiian Electric and the Consumer Advocate filed a Stipulated Settlement Letter, documenting a global settlement of all issues in this rate case. The Parties agreed that as a result of this settlement agreement, there will be no increase in electric revenues over the revenues established in the 2017 test year rate case.
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On May 13, 2020, the PUC issued its Final Report on the Management Audit, which recommended various operational and organizational changes intended to better manage costs and provide value to customers. The report also recommended a three-year timeframe to ramp up to a sustained $25 million in annual savings by the end of 2022, split between capital (approximately 80%) and O&M (approximately 20%). In its statement of position on the management audit filed on June 17, 2020, Hawaiian Electric committed to deliver these savings to customers over time through a proposal it later submitted in its statement of position in the PBR proceeding.
On October 22, 2020, the PUC issued a final D&O approving the stipulated settlement agreement filed in the proceeding. As a result, there will be no increase in base electric rates established in the 2017 test year rate case. In the final D&O, the PUC approved the capital structure that consists of a 58% total equity ratio, and a ROACE of 9.5% for the 2020 test year. The resulting return on rate base (RORB) is 7.37%. The D&O approved the agreement to implement the overall lower depreciation rates approved in the last depreciation study proceeding, effective January 1, 2020. While the PUC generally approved the amount and treatment of Hawaiian Electric's Management Audit savings commitment reflected in the settlement agreement as reasonable, the PUC clarified that it is not bound in the Performance-Based Regulation proceeding to accept the proposed implementation details identified in the settlement agreement and retains full discretion in that proceeding as to the scope, nature, and treatment of Hawaiian Electric’s savings commitment. Hawaiian Electric is required to file revised tariff sheets within fifteen days of this final D&O. The effective date of the final tariffs is subject to PUC approval.
Hawaii Electric Light 2019 test year rate case. On September 24, 2019, Hawaii Electric Light and the Consumer Advocate filed a Stipulated Partial Settlement Letter which documented agreements reached on all of the issues in the proceeding, except for the ROACE, capital structure, amortization period for the state investment tax credit, and automatic annual target heat rate adjustment. On November 13, 2019, the PUC issued an interim decision maintaining Hawaii Electric Light’s revenues at current effective rates based on an interim revenue requirement of $387 million, average rate base of $534 million, and a 7.52% RORB that incorporates a ROACE of 9.5% and 58.0% total equity ratio, and tariffs became effective January 1, 2020. On July 28, 2020, the PUC issued a final D&O, approving the Stipulated Partial Settlement Letter in part and ordering final rates for the 2019 test year to remain at current effective rates such that there is a zero increase in rates. The PUC determined that an appropriate ROACE for the 2019 test year is 9.5%, approved a capital structure of 58% total equity and approved as fair a 7.52% RORB. In addition, the order, among others, (1) approved a 10-year amortization period for the state investment tax credit; and (2) approved a modification to Hawaii Electric Light’s ECRC to incorporate a 98%/2% risk-sharing split between customers and Hawaii Electric Light with an annual maximum exposure cap of +/- $600,000. Hawaii Electric Light’s proposed final tariffs, PIM tariffs and ECRC tariff submitted on August 27, 2020 were approved by the PUC on October 26, 2020. The proposed final tariffs and PIM tariffs took effect on November 1, 2020, and the ECRC tariff will take effect on January 1, 2021.
Regulatory assets for COVID-19 related expenses. On May 4, 2020, the PUC issued an order, authorizing all utilities, including the Utilities, to establish regulatory assets to record costs resulting from the suspension of disconnections of service during the pendency of the Governor’s Emergency Proclamation and until otherwise ordered by the PUC. In future proceedings, the PUC will consider the reasonableness of the costs, the appropriate period of recovery, any amount of carrying costs thereon, and any savings directly attributable to suspension of disconnects, and other related matters. As part of the order, the PUC prohibits the Utilities from charging late payment fees on past due payments. On June 30, 2020, the PUC issued an order approving the Utilities’ request made in April 2020 for deferral treatment of COVID-19 related expenses through December 31, 2020, and allowed the Utilities to file application to request an extension of the deferral period beyond December 31, 2020. The Utilities are required to file quarterly reports to update the Utilities’ financial condition, measures in place to assist their customers during the COVID-19 emergency situation, identifying the planned deferred costs and details for the deferred costs, and identifying funds received or benefits received that have resulted from the COVID-19 emergency period. The recovery of the regulatory assets would be determined in a subsequent proceeding. As of September 30, 2020, the Utilities recorded a total of $12.4 million in regulatory assets pursuant to the orders.
Condensed consolidating financial information. Condensed consolidating financial information for Hawaiian Electric and its subsidiaries are presented for the three and nine month periods ended September 30, 2020 and 2019, and as of September 30, 2020 and December 31, 2019.
Hawaiian Electric unconditionally guarantees Hawaii Electric Light’s and Maui Electric’s obligations (a) to the State of Hawaii for the repayment of principal and interest on Special Purpose Revenue Bonds issued for the benefit of Hawaii Electric Light and Maui Electric, and (b) under their respective private placement note agreements and the Hawaii Electric Light notes and Maui Electric notes issued thereunder. Hawaiian Electric is also obligated, after the satisfaction of its obligations on its own preferred stock, to make dividend, redemption and liquidation payments on Hawaii Electric Light’s and Maui Electric’s preferred stock if the respective subsidiary is unable to make such payments.
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Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Three months ended September 30, 2020

(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other subsidiaries
Consolidating adjustments
Hawaiian Electric
Consolidated
Revenues$398,877 82,172 81,629 — (110)$562,568 
Expenses
Fuel oil70,557 17,047 17,438 — — 105,042 
Purchased power116,249 17,665 15,111 — — 149,025 
Other operation and maintenance71,179 17,565 22,499 — — 111,243 
Depreciation37,853 9,760 8,076 — — 55,689 
Taxes, other than income taxes38,005 7,512 7,534 — — 53,051 
   Total expenses333,843 69,549 70,658 — — 474,050 
Operating income65,034 12,623 10,971 — (110)88,518 
Allowance for equity funds used during construction1,902 208 237 — — 2,347 
Equity in earnings of subsidiaries14,912 — — — (14,912)— 
Retirement defined benefits expense—other than service costs(591)194 (35)— — (432)
Interest expense and other charges, net(11,970)(2,519)(2,457)— 110 (16,836)
Allowance for borrowed funds used during construction659 65 77 — — 801 
Income before income taxes69,946 10,571 8,793 — (14,912)74,398 
Income taxes9,611 2,378 1,846 13,835 
Net income60,335 8,193 6,947 — (14,912)60,563 
Preferred stock dividends of subsidiaries— 133 95 — 228 
Net income attributable to Hawaiian Electric
60,335 8,060 6,852 — (14,912)60,335 
Preferred stock dividends of Hawaiian Electric270 — — — — 270 
Net income for common stock$60,065 8,060 6,852 — (14,912)$60,065 

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Three months ended September 30, 2020

(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net income for common stock$60,065 8,060 6,852 — (14,912)$60,065 
Other comprehensive income (loss), net of taxes:      
Retirement benefit plans:      
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits5,769 885 770 — (1,655)5,769 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes(5,721)(887)(767)— 1,654 (5,721)
Other comprehensive income (loss), net of taxes48 (2)3 — (1)48 
Comprehensive income attributable to common shareholder
$60,113 8,058 6,855 — (14,913)$60,113 


19

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Three months ended September 30, 2019
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other subsidiaries
Consolidating adjustments
Hawaiian Electric
Consolidated
Revenues$491,723 93,576 103,236 — (205)$688,330 
Expenses
Fuel oil139,747 21,427 37,919 — — 199,093 
Purchased power135,447 24,342 15,248 — — 175,037 
Other operation and maintenance80,582 19,868 23,965 — — 124,415 
Depreciation35,867 10,453 7,615 — — 53,935 
Taxes, other than income taxes46,433 8,359 9,265 — — 64,057 
   Total expenses438,076 84,449 94,012 — — 616,537 
Operating income53,647 9,127 9,224 — (205)71,793 
Allowance for equity funds used during construction2,685 229 336 — — 3,250 
Equity in earnings of subsidiaries11,048 — — — (11,048)— 
Retirement defined benefits expense—other than service costs(582)(105)(36)— — (723)
Interest expense and other charges, net(12,771)(2,524)(2,339)— 205 (17,429)
Allowance for borrowed funds used during construction990 95 123 — — 1,208 
Income before income taxes55,017 6,822 7,308 — (11,048)58,099 
Income taxes7,968 1,420 1,434 — — 10,822 
Net income47,049 5,402 5,874 — (11,048)47,277 
Preferred stock dividends of subsidiaries— 133 95 — — 228 
Net income attributable to Hawaiian Electric
47,049 5,269 5,779 — (11,048)47,049 
Preferred stock dividends of Hawaiian Electric270 — — — — 270 
Net income for common stock$46,779 5,269 5,779 — (11,048)$46,779 

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Three months ended September 30, 2019

(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net income for common stock$46,779 5,269 5,779 — (11,048)$46,779 
Other comprehensive income (loss), net of taxes:      
Retirement benefit plans:      
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits2,519 387 309 — (696)2,519 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes(2,493)(387)(309)— 696 (2,493)
Other comprehensive income, net of taxes26 — — — — 26 
Comprehensive income attributable to common shareholder$46,805 5,269 5,779 — (11,048)$46,805 

20

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Nine months ended September 30, 2020

(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiariesConsolidating adjustmentsHawaiian Electric
Consolidated
Revenues$1,200,677 249,970 244,043 — (465)$1,694,225 
Expenses
Fuel oil268,382 55,733 66,599 — — 390,714 
Purchased power333,146 53,032 39,501 — — 425,679 
Other operation and maintenance231,090 54,250 63,491 — — 348,831 
Depreciation113,724 29,281 24,230 — — 167,235 
Taxes, other than income taxes115,179 23,324 22,986 — — 161,489 
   Total expenses1,061,521 215,620 216,807 — — 1,493,948 
Operating income139,156 34,350 27,236 — (465)200,277 
Allowance for equity funds used during construction5,452 520 584 — — 6,556 
Equity in earnings of subsidiaries37,492 — — — (37,492)— 
Retirement defined benefits expense—other than service costs(1,683)581 (93)— — (1,195)
Interest expense and other charges, net(36,471)(7,536)(7,226)— 465 (50,768)
Allowance for borrowed funds used during construction1,887 163 191 — — 2,241 
Income before income taxes145,833 28,078 20,692 — (37,492)157,111 
Income taxes18,724 6,372 4,220 — — 29,316 
Net income127,109 21,706 16,472 — (37,492)127,795 
Preferred stock dividends of subsidiaries— 400 286 — — 686 
Net income attributable to Hawaiian Electric127,109 21,306 16,186 — (37,492)127,109 
Preferred stock dividends of Hawaiian Electric810 — — — — 810 
Net income for common stock$126,299 21,306 16,186 — (37,492)$126,299 


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Nine months ended September 30, 2020

(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiariesConsolidating adjustmentsHawaiian Electric Consolidated
Net income for common stock$126,299 21,306 16,186 — (37,492)$126,299 
Other comprehensive income (loss), net of taxes:
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits16,137 2,384 2,072 — (4,456)16,137 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes(16,038)(2,382)(2,072)— 4,454 (16,038)
Other comprehensive income, net of taxes99 2 — — (2)99 
Comprehensive income attributable to common shareholder$126,398 21,308 16,186 — (37,494)$126,398 

21

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Nine months ended September 30, 2019


(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiariesConsolidating adjustmentsHawaiian Electric
Consolidated
Revenues$1,347,412 270,697 282,939 — (439)$1,900,609 
Expenses
Fuel oil374,100 62,210 105,012 — — 541,322 
Purchased power367,541 67,548 37,247 — — 472,336 
Other operation and maintenance240,311 56,635 64,859 — — 361,805 
Depreciation107,602 31,359 22,834 — — 161,795 
Taxes, other than income taxes127,654 25,170 26,480 — — 179,304 
   Total expenses1,217,208 242,922 256,432 — — 1,716,562 
Operating income130,204 27,775 26,507 — (439)184,047 
Allowance for equity funds used during construction7,746 579 1,010 — — 9,335 
Equity in earnings of subsidiaries30,983 — — — (30,983)— 
Retirement defined benefits expense—other than service costs(1,716)(316)(95)— — (2,127)
Interest expense and other charges, net(38,961)(8,345)(7,078)— 439 (53,945)
Allowance for borrowed funds used during construction2,854 242 369 — — 3,465 
Income before income taxes131,110 19,935 20,713 — (30,983)140,775 
Income taxes18,821 4,431 4,548 — — 27,800 
Net income112,289 15,504 16,165 — (30,983)112,975 
Preferred stock dividends of subsidiaries— 400 286 — — 686 
Net income attributable to Hawaiian Electric112,289 15,104 15,879 — (30,983)112,289 
Preferred stock dividends of Hawaiian Electric810 — — — — 810 
Net income for common stock$111,479 15,104 15,879 — (30,983)$111,479 


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Nine months ended September 30, 2019

(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiariesConsolidating adjustmentsHawaiian Electric Consolidated
Net income for common stock$111,479 15,104 15,879 — (30,983)$111,479 
Other comprehensive income (loss), net of taxes:
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits7,162 1,091 887 — (1,978)7,162 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes(7,089)(1,089)(887)— 1,976 (7,089)
Other comprehensive income, net of taxes73 2 — — (2)73 
Comprehensive income attributable to common shareholder$111,552 15,106 15,879 — (30,985)$111,552 

22

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Balance Sheet
September 30, 2020
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsi-
diaries		Consoli-
dating
adjustments		Hawaiian Electric
Consolidated
Assets      
Property, plant and equipment
Utility property, plant and equipment      
Land$42,389 5,606 3,594 — — $51,589 
Plant and equipment4,910,344 1,331,934 1,180,630 — — 7,422,908 
Less accumulated depreciation(1,656,533)(592,461)(540,923)— — (2,789,917)
Construction in progress163,757 20,975 27,805 — — 212,537 
Utility property, plant and equipment, net3,459,957 766,054 671,106 — — 4,897,117 
Nonutility property, plant and equipment, less accumulated depreciation
5,307 115 1,532 — — 6,954 
Total property, plant and equipment, net3,465,264 766,169 672,638 — — 4,904,071 
Investment in wholly owned subsidiaries, at equity606,411 — — — (606,411)— 
Current assets      
Cash and cash equivalents23,525 4,363 1,835 77 — 29,800 
Restricted cash20,458 — — — — 20,458 
Advances to affiliates28,500 — — — (28,500)— 
Customer accounts receivable, net95,884 23,322 18,730 — — 137,936 
Accrued unbilled revenues, net77,981 14,633 13,801 — — 106,415 
Other accounts receivable, net18,878 2,625 2,191 — (16,620)7,074 
Fuel oil stock, at average cost38,716 10,216 11,511 — — 60,443 
Materials and supplies, at average cost39,549 10,954 18,291 — — 68,794 
Prepayments and other30,400 4,056 5,509 — (321)39,644 
Regulatory assets19,095 2,502 3,865 — — 25,462 
Total current assets392,986 72,671 75,733 77 (45,441)496,026 
Other long-term assets      
Operating lease right-of-use assets142,912 1,466 362 — — 144,740 
Regulatory assets453,384 103,556 95,281 — — 652,221 
Other87,024 17,515 20,707 — — 125,246 
Total other long-term assets683,320 122,537 116,350 — — 922,207 
Total assets$5,147,981 961,377 864,721 77 (651,852)$6,322,304 
Capitalization and liabilities      
Capitalization      
Common stock equity$2,093,398 308,066 298,268 77 (606,411)$2,093,398 
Cumulative preferred stock—not subject to mandatory redemption
22,293 7,000 5,000 — — 34,293 
Long-term debt, net1,116,305 216,424 228,399 — — 1,561,128 
Total capitalization3,231,996 531,490 531,667 77 (606,411)3,688,819 
Current liabilities      
Current portion of operating lease liabilities64,776 98 32 — — 64,906 
Current portion of long-term debt— — — — — — 
Short-term borrowings from non-affiliates49,948 — — — — 49,948 
Short-term borrowings from affiliate— 26,500 2,000 — (28,500)— 
Accounts payable88,867 13,730 15,883 — — 118,480 
Interest and preferred dividends payable21,681 3,950 4,653 — (40)30,244 
Taxes accrued, including revenue taxes127,948 29,187 26,930 — (321)183,744 
Regulatory liabilities22,943 9,304 4,308 — — 36,555 
Other57,763 14,285 19,582 — (16,580)75,050 
Total current liabilities433,926 97,054 73,388 — (45,441)558,927 
Deferred credits and other liabilities      
Operating lease liabilities84,471 1,369 335 — — 86,175 
Deferred income taxes269,635 52,682 59,218 — — 381,535 
Regulatory liabilities661,649 174,919 94,723 — — 931,291 
Unamortized tax credits83,626 15,502 14,388 — — 113,516 
Defined benefit pension and other postretirement benefit plans liability
321,768 66,237 66,145 — — 454,150 
Other60,910 22,124 24,857 — — 107,891 
Total deferred credits and other liabilities1,482,059 332,833 259,666 — — 2,074,558 
Total capitalization and liabilities$5,147,981 961,377 864,721 77 (651,852)$6,322,304 

23

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Balance Sheet
December 31, 2019
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsi-diaries		Consoli-
dating
adjustments		Hawaiian Electric
Consolidated
Assets      
Property, plant and equipment
Utility property, plant and equipment      
Land$42,598 5,606 3,612 — — $51,816 
Plant and equipment4,765,362 1,313,727 1,161,199 — — 7,240,288 
Less accumulated depreciation(1,591,241)(574,615)(524,301)— — (2,690,157)
Construction in progress165,137 9,993 17,944 — — 193,074 
Utility property, plant and equipment, net3,381,856 754,711 658,454 — — 4,795,021 
Nonutility property, plant and equipment, less accumulated depreciation
5,310 114 1,532 — — 6,956 
Total property, plant and equipment, net3,387,166 754,825 659,986 — — 4,801,977 
Investment in wholly owned subsidiaries, at equity
591,969 — — — (591,969)— 
Current assets      
Cash and cash equivalents2,239 6,885 1,797 101 — 11,022 
Restricted cash30,749 123 — — — 30,872 
Advances to affiliates27,700 8,000 — — (35,700)— 
Customer accounts receivable, net105,454 24,520 22,816 — — 152,790 
Accrued unbilled revenues, net83,148 17,071 17,008 — — 117,227 
Other accounts receivable, net18,396 1,907 1,960 — (10,695)11,568 
Fuel oil stock, at average cost69,003 8,901 14,033 — — 91,937 
Materials and supplies, at average cost34,876 8,313 17,513 — — 60,702 
Prepayments and other88,334 3,725 24,921 — — 116,980 
Regulatory assets27,689 1,641 1,380 — — 30,710 
Total current assets487,588 81,086 101,428 101 (46,395)623,808 
Other long-term assets      
Operating lease right-of-use assets174,886 1,537 386 — — 176,809 
Regulatory assets476,390 109,163 98,817 — — 684,370 
Other69,010 15,493 17,215 — — 101,718 
Total other long-term assets720,286 126,193 116,418 — — 962,897 
Total assets$5,187,009 962,104 877,832 101 (638,364)$6,388,682 
Capitalization and liabilities      
Capitalization
Common stock equity$2,047,352 298,998 292,870 101 (591,969)$2,047,352 
Cumulative preferred stock—not subject to mandatory redemption
22,293 7,000 5,000 — — 34,293 
Long-term debt, net1,006,737 206,416 188,561 — — 1,401,714 
Total capitalization3,076,382 512,414 486,431 101 (591,969)3,483,359 
Current liabilities     
Current portion of operating lease liabilities63,582 94 31 — — 63,707 
Current portion of long-term debt61,958 13,995 20,000 — — 95,953 
Short-term borrowings-non-affiliate88,987 — — — — 88,987 
Short-term borrowings-affiliate8,000 — 27,700 — (35,700)— 
Accounts payable139,056 25,629 23,085 — — 187,770 
Interest and preferred dividends payable14,759 3,115 2,900 — (46)20,728 
Taxes accrued, including revenue taxes143,522 32,541 31,929 — — 207,992 
Regulatory liabilities13,363 9,454 7,907 — — 30,724 
Other51,295 11,362 15,297 — (10,649)67,305 
Total current liabilities584,522 96,190 128,849 — (46,395)763,166 
Deferred credits and other liabilities     
Operating lease liabilities111,598 1,442 360 — — 113,400 
Deferred income taxes265,864 53,534 57,752 — — 377,150 
Regulatory liabilities664,894 178,474 98,218 — — 941,586 
Unamortized tax credits86,852 16,196 14,820 — — 117,868 
Defined benefit pension and other postretirement benefit plans liability
339,471 69,928 69,364 — — 478,763 
Other57,426 33,926 22,038 — — 113,390 
Total deferred credits and other liabilities1,526,105 353,500 262,552 — — 2,142,157 
Total capitalization and liabilities$5,187,009 962,104 877,832 101 (638,364)$6,388,682 

24

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Changes in Common Stock Equity
Nine months ended September 30, 2020
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Balance, December 31, 2019$2,047,352 298,998 292,870 101 (591,969)$2,047,352 
Net income for common stock126,299 21,306 16,186 — (37,492)126,299 
Other comprehensive income, net of taxes99 2 — — (2)99 
Common stock dividends(80,352)(12,240)(10,788)— 23,028 (80,352)
Dissolution of subsidiary— — — (24)24 — 
Balance, September 30, 2020$2,093,398 308,066 298,268 77 (606,411)$2,093,398 
 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Changes in Common Stock Equity
Nine months ended September 30, 2019  
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Balance, December 31, 2018$1,957,641 295,874 280,863 101 (576,838)$1,957,641 
Net income for common stock111,479 15,104 15,879 — (30,983)111,479 
Other comprehensive income, net of taxes
73 2 — — (2)73 
Common stock dividends(75,939)(7,635)(11,301)— 18,936 (75,939)
Common stock issuance expenses— — (1)— 1 — 
Balance, September 30, 2019$1,993,254 303,345 285,440 101 (588,886)$1,993,254 

25

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Cash Flows
Nine months ended September 30, 2020
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net cash provided by operating activities$205,645 27,256 34,678 — (22,624)$244,955 
Cash flows from investing activities      
Capital expenditures(180,088)(48,750)(38,644)— — (267,482)
Advances from (to) affiliates(800)8,000 — — (7,200)— 
Other5,636 1,056 1,031 (24)(404)7,295 
Net cash used in investing activities(175,252)(39,694)(37,613)(24)(7,604)(260,187)
Cash flows from financing activities      
Common stock dividends(80,352)(12,240)(10,788)— 23,028 (80,352)
Preferred stock dividends of Hawaiian Electric and subsidiaries(810)(400)(286)— — (1,496)
Proceeds from issuance of short-term debt100,000 — — — — 100,000 
Repayment of short-term debt(100,000)— — — — (100,000)
Proceeds from issuance of long-term debt205,000 10,000 40,000 — — 255,000 
Repayment of long-term debt(95,000)(14,000)— — — (109,000)
Net increase (decrease) in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less(46,987)26,500 (25,700)— 7,200 (38,987)
Other(1,249)(67)(253)— — (1,569)
Net cash provided by financing activities(19,398)9,793 2,973 — 30,228 23,596 
Net increase (decrease) in cash and cash equivalents10,995 (2,645)38 (24)— 8,364 
Cash, cash equivalents and restricted cash, beginning of period32,988 7,008 1,797 101 — 41,894 
Cash, cash equivalents and restricted cash, end of period43,983 4,363 1,835 77 — 50,258 
Less: Restricted cash(20,458)— — — — (20,458)
Cash and cash equivalents, end of period$23,525 4,363 1,835 77 — $29,800 

26

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Cash Flows
Nine months ended September 30, 2019
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net cash provided by operating activities$223,733 41,694 36,126 — (18,935)$282,618 
Cash flows from investing activities                                                                                                                                        
Capital expenditures (223,803)(29,119)(44,885)— — (297,807)
Advances to affiliates(22,200)(15,000)— — 37,200 — 
Other2,975 (283)(30)— — 2,662 
Net cash used in investing activities(243,028)(44,402)(44,915)— 37,200 (295,145)
Cash flows from financing activities     
Common stock dividends(75,939)(7,635)(11,301)— 18,936 (75,939)
Preferred stock dividends of Hawaiian Electric and subsidiaries(810)(400)(286)— — (1,496)
Proceeds from issuance of short-term debt25,000 — — — — 25,000 
Proceeds from issuance of long-term debt120,000 70,000 10,000 — — 200,000 
Repayment of long-term debt and funds transferred for repayment of long-term debt(121,546)(70,000)(10,000)— — (201,546)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less77,353 — 22,200 — (37,200)62,353 
Other578 123 85 — (1)785 
Net cash provided by (used in) financing activities24,636 (7,912)10,698 — (18,265)9,157 
Net increase (decrease) in cash and cash equivalents5,341 (10,620)1,909 — — (3,370)
Cash and cash equivalents, beginning of period16,732 15,623 3,421 101 — 35,877 
Cash and cash equivalents, end of period$22,073 5,003 5,330 101 — $32,507 

27

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Note 4 · Bank segment
Selected financial information
American Savings Bank, F.S.B.
Statements of Income and Comprehensive Income Data
 Three months ended September 30Nine months ended September 30
(in thousands)2020201920202019
Interest and dividend income    
Interest and fees on loans$52,419 $59,260 $161,505 $175,740 
Interest and dividends on investment securities7,221 7,599 22,939 25,762 
Total interest and dividend income59,640 66,859 184,444 201,502 
Interest expense    
Interest on deposit liabilities2,287 4,384 8,945 12,923 
Interest on other borrowings61 422 449 1,361 
Total interest expense2,348 4,806 9,394 14,284 
Net interest income57,292 62,053 175,050 187,218 
Provision for credit losses13,970 3,315 39,504 17,873 
Net interest income after provision for credit losses43,322 58,738 135,546 169,345 
Noninterest income    
Fees from other financial services4,233 5,085 11,906 14,445 
Fee income on deposit liabilities3,832 5,320 11,842 15,402 
Fee income on other financial products1,524 1,706 4,608 5,129 
Bank-owned life insurance1,965 1,660 4,432 6,309 
Mortgage banking income7,681 1,490 15,933 3,080 
Gain on sale of investment securities, net— 653 9,275 653 
Other income, net(231)428 (69)1,420 
Total noninterest income19,004 16,342 57,927 46,438 
Noninterest expense    
Compensation and employee benefits26,431 25,364 77,287 76,626 
Occupancy5,693 5,694 16,402 15,843 
Data processing3,366 3,763 11,052 11,353 
Services2,624 2,829 7,907 7,861 
Equipment2,001 2,163 6,630 6,416 
Office supplies, printing and postage1,187 1,297 3,577 4,320 
Marketing727 1,142 1,908 3,455 
FDIC insurance714 (5)1,567 1,249 
Other expense1
4,556 3,676 15,813 12,049 
Total noninterest expense47,299 45,923 142,143 139,172 
Income before income taxes15,027 29,157 51,330 76,611 
Income taxes2,877 6,269 9,405 15,868 
Net income12,150 22,888 41,925 60,743 
Other comprehensive income, net of taxes1,393 3,809 20,960 24,336 
Comprehensive income$13,543 $26,697 $62,885 $85,079 

1 The three and nine-month periods ended September 30, 2020 include approximately $0.7 million and $4.5 million, respectively, of certain direct and incremental COVID-19 related costs. For the nine months ended September 30, 2020, these costs, which have been recorded in Other expense, include $2.4 million of compensation expense and $1.7 million of enhanced cleaning and sanitation costs.
28

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Reconciliation to amounts per HEI Condensed Consolidated Statements of Income*:
 Three months ended September 30,Nine months ended September 30
(in thousands)2020201920202019
Interest and dividend income$59,640 $66,859 $184,444 $201,502 
Noninterest income19,004 16,342 57,927 46,438 
Less: Gain on sale of investment securities, net— (653)(9,275)(653)
*Revenues-Bank78,644 82,548 233,096 247,287 
Total interest expense2,348 4,806 9,394 14,284 
Provision for credit losses13,970 3,315 39,504 17,873 
Noninterest expense47,299 45,923 142,143 139,172 
Less: Retirement defined benefits gain (expense)—other than service costs(473)196 (1,341)276 
*Expenses-Bank63,144 54,240 189,700 171,605 
*Operating income-Bank15,500 28,308 43,396 75,682 
Add back: Retirement defined benefits (gain) expense—other than service costs473 (196)1,341 (276)
Add back: Gain on sale of investment securities, net— (653)(9,275)(653)
Income before income taxes$15,027 $29,157 $51,330 $76,611 


29

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
American Savings Bank, F.S.B.
Balance Sheets Data
(in thousands)September 30, 2020December 31, 2019
Assets    
Cash and due from banks
 $150,087  $129,770 
Interest-bearing deposits10,918 48,628 
Investment securities
Available-for-sale, at fair value 1,747,658  1,232,826 
Held-to-maturity, at amortized cost (fair value of $138,622 and $143,467, respectively)
133,858 139,451 
Stock in Federal Home Loan Bank, at cost 10,920  8,434 
Loans held for investment 5,480,902  5,121,176 
Allowance for credit losses (91,459) (53,355)
Net loans 5,389,443  5,067,821 
Loans held for sale, at lower of cost or fair value 16,806  12,286 
Other 533,865  511,611 
Goodwill 82,190  82,190 
Total assets $8,075,745  $7,233,017 
Liabilities and shareholder’s equity    
Deposit liabilities—noninterest-bearing $2,424,539  $1,909,682 
Deposit liabilities—interest-bearing 4,613,598  4,362,220 
Other borrowings 151,875  115,110 
Other 165,300  146,954 
Total liabilities 7,355,312  6,533,966 
Commitments and contingencies  
Common stock 1  1 
Additional paid-in capital351,322 349,453 
Retained earnings 356,812  358,259 
Accumulated other comprehensive income (loss), net of taxes    
Net unrealized gains on securities$22,248  $2,481  
Retirement benefit plans(9,950)12,298 (11,143)(8,662)
Total shareholder’s equity 720,433  699,051 
Total liabilities and shareholder’s equity $8,075,745  $7,233,017 
Other assets    
Bank-owned life insurance $161,206  $157,465 
Premises and equipment, net 206,190  204,449 
Accrued interest receivable 24,770  19,365 
Mortgage-servicing rights 9,553  9,101 
Low-income housing investments71,467 66,302 
Real estate acquired in settlement of loans, net 42  — 
Other 60,637  54,929 
  $533,865  $511,611 
Other liabilities    
Accrued expenses $52,170  $45,822 
Federal and state income taxes payable 9,750  14,996 
Cashier’s checks 28,638  23,647 
Advance payments by borrowers 5,413  10,486 
Other 69,329  52,003 
  $165,300  $146,954 
    
30

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Bank-owned life insurance is life insurance purchased by ASB on the lives of certain key employees, with ASB as the beneficiary. The insurance is used to fund employee benefits through tax-free income from increases in the cash value of the policies and insurance proceeds paid to ASB upon an insured’s death.
Other borrowings consisted of securities sold under agreements to repurchase, federal funds purchased and advances from the Federal Home Loan Bank (FHLB) of $95.9 million, nil and $56.0 million, respectively, as of September 30, 2020 and $115.0 million, nil and nil, respectively, as of December 31, 2019.
Investment securities.  The major components of investment securities were as follows:
 Amortized costGross unrealized gainsGross unrealized lossesEstimated fair
value		Gross unrealized losses
 Less than 12 months12 months or longer
(dollars in thousands)Number of issuesFair 
value		AmountNumber of issuesFair 
value		Amount
September 30, 2020        
Available-for-sale
U.S. Treasury and federal agency obligations$61,359 $2,229 $— $63,588 — $— $— — $— $— 
Mortgage-backed securities*1,598,949 27,580 (981)1,625,548 17 304,930 (981)— — — 
Corporate bonds29,772 1,565 — 31,337 — — — — — — 
Mortgage revenue bonds27,185 — — 27,185 — — — — 
 $1,717,265 $31,374 $(981)$1,747,658 17 $304,930 $(981)— $— $— 
Held-to-maturity
Mortgage-backed securities*$133,858 $4,878 $(114)$138,622 2 $28,486 $(114)— $— $— 
 $133,858 $4,878 $(114)$138,622 2 $28,486 $(114)— $— $— 
December 31, 2019
Available-for-sale
U.S. Treasury and federal agency obligations$117,255 $652 $(120)$117,787 2 $4,110 $(11)3 $27,637 $(109)
Mortgage-backed securities*1,024,892 6,000 (4,507)1,026,385 19 152,071 (819)75 318,020 (3,688)
Corporate bonds58,694 1,363 — 60,057 — — — — — — 
Mortgage revenue bonds28,597 — — 28,597 — — — — — — 
 $1,229,438 $8,015 $(4,627)$1,232,826 21 $156,181 $(830)78 $345,657 $(3,797)
Held-to-maturity
Mortgage-backed securities* $139,451 $4,087 $(71)$143,467 1 $12,986 $(71)— $— $— 
 $139,451 $4,087 $(71)$143,467 1 $12,986 $(71)— $— $— 
* Issued or guaranteed by U.S. Government agencies or sponsored agencies
ASB does not believe that the investment securities that were in an unrealized loss position at September 30, 2020, represent a credit loss. Total gross unrealized losses were primarily attributable to change in market conditions. On a quarterly basis the investment securities are evaluated for changes in financial condition of the issuer. Based upon ASB’s evaluation, all securities held within the investment portfolio continue to be investment grade by one or more agencies. The contractual cash flows of the U.S. Treasury, federal agency obligations and agency mortgage-backed securities are backed by the full faith and credit guaranty of the United States government or an agency of the government. ASB does not intend to sell the securities before the recovery of its amortized cost basis and there have been no adverse changes in the timing of the contractual cash flows for the securities. ASB’s investment securities portfolio did not require an allowance for credit losses at September 30, 2020.
U.S. Treasury, federal agency obligations, corporate bonds, and mortgage revenue bonds have contractual terms to maturity. Mortgage-backed securities have contractual terms to maturity, but require periodic payments to reduce principal. In addition, expected maturities will differ from contractual maturities because borrowers have the right to prepay the underlying mortgages.
31

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The contractual maturities of investment securities were as follows:
September 30, 2020Amortized costFair value
(in thousands)  
Available-for-sale
Due in one year or less$16,952 $17,193 
Due after one year through five years41,941 43,735 
Due after five years through ten years32,238 33,997 
Due after ten years27,185 27,185 
 118,316 122,110 
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies1,598,949 1,625,548 
Total available-for-sale securities$1,717,265 $1,747,658 
Held-to-maturity
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies$133,858 $138,622 
Total held-to-maturity securities$133,858 $138,622 
Proceeds from the sale of available-for-sale securities, which also included the sale of ASB’s entire Visa Class B restricted stock holdings in the second quarter of 2020, were nil and $169.2 million for the three and nine month period ended September 30, 2020, respectively, and $19.8 million for each of the three and nine month periods ended September 30, 2019. Gross realized gains were nil and $9.3 million for the three and nine months ended September 30, 2020, respectively, and $0.7 million for each of the three and nine months ended September 30, 2019. Gross realized losses were nil for the three and nine months ended September 30, 2020 and 2019. Tax expense on realized gains were nil and $2.5 million for the three and nine months ended September 30, 2020, respectively and $0.2 million for each of the three and nine months ended September 30, 2019.
Loans. The components of loans were summarized as follows:
September 30, 2020December 31, 2019
(in thousands)  
Real estate:  
Residential 1-4 family$2,195,093 $2,178,135 
Commercial real estate900,912 824,830 
Home equity line of credit1,028,011 1,092,125 
Residential land14,310 14,704 
Commercial construction112,930 70,605 
Residential construction10,281 11,670 
Total real estate4,261,537 4,192,069 
Commercial1,042,435 670,674 
Consumer190,138 257,921 
Total loans5,494,110 5,120,664 
          Deferred fees and discounts(13,208)512 
          Allowance for credit losses(91,459)(53,355)
Total loans, net$5,389,443 $5,067,821 
ASB's policy is to require private mortgage insurance on all real estate loans when the loan-to-value ratio of the property exceeds 80% of the lower of the appraised value or purchase price at origination. For non-owner occupied residential property purchases, the loan-to-value ratio may not exceed 75% of the lower of the appraised value or purchase price at origination.
32

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Allowance for credit losses.  The allowance for credit losses by portfolio segment were as follows:
(in thousands)Residential
1-4 family		Commercial real
estate		Home
equity line of credit		Residential landCommercial constructionResidential constructionCommercial loansConsumer loansTotal
Three months ended September 30, 2020        
Allowance for credit losses:         
Beginning balance$3,911 $21,100 $6,214 $356 $4,757 $14 $13,868 $31,087 $81,307 
Charge-offs— — — — — — (1,727)(3,881)(5,608)
Recoveries12 — 50 12 — — 211 1,005 1,290 
Provision(286)11,049 (390)178 1,282 (3)5,840 (3,200)14,470 
Ending balance$3,637 $32,149 $5,874 $546 $6,039 $11 $18,192 $25,011 $91,459 
Three months ended September 30, 2019        
Allowance for credit losses:         
Beginning balance$2,015 $15,811 $6,881 $537 $2,046 $2 $13,073 $18,060 $58,425 
Charge-offs(7)— (13)— — — (4,900)(5,311)(10,231)
Recoveries27 — 4 28 — — 726 746 1,531 
Provision(56)(396)135 (104)196 1 (517)4,056 3,315 
Ending balance$1,979 $15,415 $7,007 $461 $2,242 $3 $8,382 $17,551 $53,040 
Nine months ended September 30, 2020        
Allowance for credit losses:         
Beginning balance, prior to adoption of ASU No. 2016-13$2,380 $15,053 $6,922 $449 $2,097 $3 $10,245 $16,206 $53,355 
Impact of adopting ASU No. 2016-13
2,150 208 (541)(64)289 14 922 16,463 19,441 
Charge-offs(7)— — (351)— — (2,795)(16,466)(19,619)
Recoveries67 — 56 26 — — 503 2,426 3,078 
Provision(953)16,888 (563)486 3,653 (6)9,317 6,382 35,204 
Ending balance$3,637 $32,149 $5,874 $546 $6,039 $11 $18,192 $25,011 $91,459 
Nine months ended September 30, 2019        
Allowance for credit losses:         
Beginning balance$1,976 $14,505 $6,371 $479 $2,790 $4 $9,225 $16,769 $52,119 
Charge-offs(26)— (32)(4)— — (6,012)(15,972)(22,046)
Recoveries644 — 13 42 — — 2,187 2,208 5,094 
Provision(615)910 655 (56)(548)(1)2,982 14,546 17,873 
Ending balance$1,979 $15,415 $7,007 $461 $2,242 $3 $8,382 $17,551 $53,040 
December 31, 2019
Ending balance: individually evaluated for impairment$898 $2 $322 $— $— $— $1,015 $454 $2,691 
Ending balance: collectively evaluated for impairment$1,482 $15,051 $6,600 $449 $2,097 $3 $9,230 $15,752 $50,664 
Financing Receivables:         
Ending balance$2,178,135 $824,830 $1,092,125 $14,704 $70,605 $11,670 $670,674 $257,921 $5,120,664 
Ending balance: individually evaluated for impairment$15,600 $1,048 $12,073 $3,091 $— $— $8,418 $507 $40,737 
Ending balance: collectively evaluated for impairment$2,162,535 $823,782 $1,080,052 $11,613 $70,605 $11,670 $662,256 $257,414 $5,079,927 

33

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Allowance for loan commitments.  The allowance for loan commitments by portfolio segment were as follows:
(in thousands)Home equity
 line of credit		Commercial constructionCommercial loansTotal
Three months ended September 30, 2020
Allowance for loan commitments:
Beginning balance$300 $7,500 $300 $8,100 
Provision— (800)300 (500)
Ending balance$300 $6,700 $600 $7,600 
Nine months ended September 30, 2020
Allowance for loan commitments:
Beginning balance, prior to adoption of ASU No. 2016-13$392 $931 $418 $1,741 
Impact of adopting ASU No. 2016-13
(92)1,745 (94)1,559 
Provision— 4,024 276 4,300 
Ending balance$300 $6,700 $600 $7,600 
Credit quality.  ASB performs an internal loan review and grading on an ongoing basis. The review provides management with periodic information as to the quality of the loan portfolio and effectiveness of its lending policies and procedures. The objectives of the loan review and grading procedures are to identify, in a timely manner, existing or emerging credit trends so that appropriate steps can be initiated to manage risk and avoid or minimize future losses. Loans subject to grading include commercial, commercial real estate and commercial construction loans.
Each commercial and commercial real estate loan is assigned an Asset Quality Rating (AQR) reflecting the likelihood of repayment or orderly liquidation of that loan transaction pursuant to regulatory credit classifications:  Pass, Special Mention, Substandard, Doubtful and Loss. The AQR is a function of the probability of default model rating, the loss given default and possible non-model factors which impact the ultimate collectability of the loan such as character of the business owner/guarantor, interim period performance, litigation, tax liens and major changes in business and economic conditions. Pass exposures generally are well protected by the current net worth and paying capacity of the obligor or by the value of the asset or underlying collateral. Special Mention loans have potential weaknesses that, if left uncorrected, could jeopardize the liquidation of the debt. Substandard loans have well-defined weaknesses that jeopardize the liquidation of the debt and are characterized by the distinct possibility that ASB may sustain some loss. An asset classified Doubtful has the weaknesses of those classified Substandard, with the added characteristic that the weaknesses make collection or liquidation in full, on the basis of currently existing facts, conditions, and values, highly questionable and improbable. An asset classified Loss is considered uncollectible and has such little value that its continuance as a bankable asset is not warranted.
34

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The credit risk profile by vintage date based on payment activity or internally assigned grade for loans was as follows:
Term Loans by Origination YearRevolving Loans
(in thousands)20202019201820172016PriorRevolvingConverted to term loansTotal
September 30, 2020
Residential 1-4 family
Current$425,930 $242,811 $138,155 $233,944 $201,532 $947,343 $— $— $2,189,715 
30-59 days past due— — — — — 2,461 — — 2,461 
60-89 days past due— — — — — 1,028 — — 1,028 
Greater than 89 days past due— — — 353 — 1,536 — — 1,889 
425,930 242,811 138,155 234,297 201,532 952,368 — — 2,195,093 
Home equity line of credit
Current— — — — — — 991,199 33,800 1,024,999 
30-59 days past due— — — — — — 419 349 768 
60-89 days past due— — — — — — 158 — 158 
Greater than 89 days past due— — — — — — 1,287 799 2,086 
— — — — — — 993,063 34,948 1,028,011 
Residential land
Current4,606 4,433 1,598 1,600 22 1,751 — — 14,010 
30-59 days past due— — — — — 300 — — 300 
60-89 days past due— — — — — — — — — 
Greater than 89 days past due— — — — — — — — — 
4,606 4,433 1,598 1,600 22 2,051 — — 14,310 
Residential construction
Current4,368 4,897 386 630 — — — — 10,281 
30-59 days past due— — — — — — — — — 
60-89 days past due— — — — — — — — — 
Greater than 89 days past due— — — — — — — — — 
4,368 4,897 386 630 — — — — 10,281 
Consumer
Current25,661 77,454 45,485 10,916 764 423 19,906 3,221 183,830 
30-59 days past due387 981 723 239 13 — 467 131 2,941 
60-89 days past due95 717 674 152 5 — 70 87 1,800 
Greater than 89 days past due32 507 411 156 18 — 359 84 1,567 
26,175 79,659 47,293 11,463 800 423 20,802 3,523 190,138 
Commercial real estate
Pass161,130 73,086 63,082 28,685 55,742 154,297 11,000 — 547,022 
Special Mention9,634 38,908 65,840 33,921 68,502 65,431 — — 282,236 
Substandard— 3,165 4,193 1,896 4,461 57,939 — — 71,654 
Doubtful— — — — — — — — — 
170,764 115,159 133,115 64,502 128,705 277,667 11,000 — 900,912 
Commercial construction
Pass11,122 21,322 30,655 — 5,999 — 24,200 — 93,298 
Special Mention1,632 — — 18,000 — — — — 19,632 
Substandard— — — — — — — — — 
Doubtful— — — — — — — — — 
12,754 21,322 30,655 18,000 5,999 — 24,200 — 112,930 
Commercial
Pass454,219 131,481 91,147 30,680 13,067 37,580 76,449 13,397 848,020 
Special Mention36,029 23,458 3,681 7,176 30,864 15,105 32,494 11,221 160,028 
Substandard132 9,420 371 4,402 8,547 3,742 6,943 830 34,387 
Doubtful— — — — — — — — — 
490,380 164,359 95,199 42,258 52,478 56,427 115,886 25,448 1,042,435 
Total loans$1,134,977 $632,640 $446,401 $372,750 $389,536 $1,288,936 $1,164,951 $63,919 $5,494,110 
35

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Revolving loans converted to term loans during the nine months ended September 30, 2020 in the commercial, home equity line of credit and consumer portfolios was $13.8 million, $10.0 million, and $2.0 million, respectively.
The credit risk profile based on payment activity for loans was as follows:
(in thousands)30-59
days
past due		60-89
days
past due		 90 days or more past dueTotal
past due		CurrentTotal
financing
receivables		Amortized cost>
90 days and
accruing
September 30, 2020       
Real estate:       
Residential 1-4 family$2,461 $1,028 $1,889 $5,378 $2,189,715 $2,195,093 $— 
Commercial real estate— — — — 900,912 900,912 — 
Home equity line of credit768 158 2,086 3,012 1,024,999 1,028,011 — 
Residential land300 — — 300 14,010 14,310 — 
Commercial construction— — — — 112,930 112,930 — 
Residential construction— — — — 10,281 10,281 — 
Commercial1,702 326 105 2,133 1,040,302 1,042,435 — 
Consumer2,941 1,800 1,567 6,308 183,830 190,138 — 
Total loans$8,172 $3,312 $5,647 $17,131 $5,476,979 $5,494,110 $— 
December 31, 2019       
Real estate:       
Residential 1-4 family$2,588 $290 $1,808 $4,686 $2,173,449 $2,178,135 $— 
Commercial real estate— — — — 824,830 824,830 — 
Home equity line of credit813 — 2,117 2,930 1,089,195 1,092,125 — 
Residential land— — 25 25 14,679 14,704 — 
Commercial construction— — — — 70,605 70,605 — 
Residential construction— — — — 11,670 11,670 — 
Commercial1,077 311 172 1,560 669,114 670,674 — 
Consumer4,386 3,257 2,907 10,550 247,371 257,921 — 
Total loans$8,864 $3,858 $7,029 $19,751 $5,100,913 $5,120,664 $— 

36

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The credit risk profile based on nonaccrual loans were as follows:
(in thousands)September 30, 2020December 31, 2019
With a Related ACLWithout a Related ACLTotalTotal
Real estate:
Residential 1-4 family$8,271 $1,919 $10,190 $11,395 
Commercial real estate15,965 — 15,965 195 
Home equity line of credit6,246 1,555 7,801 6,638 
Residential land410 — 410 448 
Commercial construction— — — — 
Residential construction— — — — 
Commercial 758 2,552 3,310 5,947 
Consumer 4,304 — 4,304 5,113 
  Total nonaccrual loans$35,954 $6,026 $41,980 $29,736 


The credit risk profile based on loans whose terms have been modified and accruing interest were as follows:
(in thousands)September 30, 2020December 31, 2019
Real estate:
Residential 1-4 family$8,224 $9,869 
Commercial real estate997 853 
Home equity line of credit8,809 10,376 
Residential land1,891 2,644 
Commercial construction— — 
Residential construction— — 
Commercial2,531 2,614 
Consumer54 57 
Total troubled debt restructured loans accruing interest$22,506 $26,413 

ASB did not recognize interest on nonaccrual loans for the three and nine months ended September 30, 2020.
Troubled debt restructurings.  A loan modification is deemed to be a TDR when the borrower is determined to be experiencing financial difficulties and ASB grants a concession it would not otherwise consider.
The allowance for credit losses on TDR loans that do not share risk characteristics are individually evaluated based on the present value of expected future cash flows discounted at the loan’s effective original contractual rate or based on the fair value of collateral less cost to sell. The financial impact of the estimated loss is an increase to the allowance associated with the modified loan. When available information confirms that specific loans or portions thereof are uncollectible (confirmed losses), these amounts are charged off against the allowance for credit losses.
37

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Loan modifications that occurred during the first nine months of 2020 and 2019 were as follows:
Loans modified as a TDRThree months ended September 30, 2020Nine months ended September 30, 2020
(dollars in thousands)Number 
of contracts
Outstanding 
recorded 
investment
 (as of period end)1
Related allowance
(as of period end)
Number 
of contracts
Outstanding 
recorded 
investment
 (as of period end)1
Related allowance
(as of period end)
Troubled debt restructurings    
Real estate:    
Residential 1-4 family— $— $— 1 $146 $7 
Commercial real estate— — — 2 16,149 4,019 
Home equity line of credit— — — 2 22 1 
Residential land— — — 2 228 15 
Commercial construction— — — — — — 
Residential construction— — — — — — 
Commercial2 52 45 5 207 180 
Consumer — — — — — — 
 2 $52 $45 12 $16,752 $4,222 
Three months ended September 30, 2019Nine months ended September 30, 2019
(dollars in thousands)Number 
of contracts
Outstanding 
recorded 
investment
 (as of period end)1
Related allowance
(as of period end)
Number 
of contracts
Outstanding 
recorded 
investment
 (as of period end)1
Related allowance
(as of period end)
Troubled debt restructurings    
Real estate:    
Residential 1-4 family1 $324 $— 10 $1,563 $165 
Commercial real estate— — — — — — 
Home equity line of credit— — — 3 429 85 
Residential land1 350 — 3 1,169 — 
Commercial construction— — — — — — 
Residential construction— — — — — — 
Commercial3 275 58 6 1,761 218 
Consumer — — — — — — 
 5 $949 $58 22 $4,922 $468 

1     The period end balances reflect all paydowns and charge-offs since the modification period. TDRs fully paid off, charged-off, or foreclosed upon by period end are not included.

There were no loans modified in TDRs that experienced a payment default of 90 days or more during the third quarter and first nine months of 2020 and 2019.
If a loan modified in a TDR subsequently defaults, ASB evaluates the loan for further impairment. Based on its evaluation, adjustments may be made in the allocation of the allowance or partial charge-offs may be taken to further write-down the carrying value of the loan. Commitments to lend additional funds to borrowers whose loan terms have been modified in a TDR totaled nil at September 30, 2020 and December 31, 2019.
The Coronavirus Aid, Relief, and Economic Security Act (CARES Act) provides that a financial institution may elect to suspend the requirements under GAAP for certain loan modifications that would otherwise be categorized as a TDR and any related impairment for accounting purposes.
In response to the COVID-19 pandemic, the Board of Governors of the FRB, the FDIC, the National Credit Union Administration, the OCC, and the Consumer Financial Protection Bureau, in consultation with the state financial regulators (collectively, the “agencies”) issued a joint interagency statement (issued March 22, 2020; revised statement issued April 7, 2020). Some of the provisions applicable to the Company include, but are not limited to accounting for loan modifications, past due reporting and nonaccrual status and charge-offs.
38

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Loan modifications that do not meet the conditions of the CARES Act may still qualify as a modification that does not need to be accounted for as a TDR. The agencies confirmed with the FASB staff that short-term modifications made on a good faith basis in response to COVID-19 to borrowers who were current prior to any relief are not TDRs. This includes short-term (e.g., six months) modifications such as payment deferrals, fee waivers, extensions of repayment terms, or insignificant delays in payment. Financial institutions are not expected to designate loans with deferrals granted due to COVID-19 as past due because of the deferral. A loan’s payment date is governed by the due date stipulated in the legal agreement. If a financial institution agrees to a payment deferral, these loans would not be considered past due during the period of the deferral. Lastly, during short-term COVID-19 modifications, these loans generally should not be reported as nonaccrual or as classified.
Collateral-dependent loans. A loan is considered collateral-dependent when the borrower is experiencing financial difficulty and repayment of the loan is expected to be provided substantially through the operation or sale of the collateral. Loans considered collateral-dependent were as follows:
September 30, 2020Amortized costCollateral type
(in thousands)
Real estate:
   Residential 1-4 family$2,057  Residential real estate property
   Home equity line of credit1,555  Residential real estate property
Commercial construction— 
     Total real estate3,612 
Commercial— 
     Total $3,612 
ASB had $3.0 million and $3.5 million of consumer mortgage loans collateralized by residential real estate property that were in the process of foreclosure at September 30, 2020 and December 31, 2019, respectively.
The credit risk profile by internally assigned grade for loans was as follows:
 December 31, 2019
(in thousands)Commercial
real estate		Commercial
construction		CommercialTotal
Grade:   
Pass$756,747 $68,316 $621,657 $1,446,720 
Special mention4,451 — 29,921 34,372 
Substandard63,632 2,289 19,096 85,017 
Doubtful— — — — 
Loss— — — — 
Total$824,830 $70,605 $670,674 $1,566,109 

39

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The total carrying amount and the total unpaid principal balance of impaired loans were as follows:
 December 31, 2019Three months ended September 30, 2019Nine months ended September 30, 2019
(in thousands)Recorded
investment		Unpaid
principal
balance		Related
allowance		Average
recorded
investment		Interest
income
recognized*		Average
recorded
investment		Interest
income
recognized*
With no related allowance recorded      
Real estate:       
Residential 1-4 family$6,817 $7,207 $— $8,562 $175 $8,515 $422 
Commercial real estate195 200 — — — — — 
Home equity line of credit1,984 2,135 — 1,797 12 2,091 78 
Residential land3,091 3,294 — 3,205 40 2,507 90 
Commercial construction— — — — — — — 
Residential construction— — — — — — — 
Commercial1,948 2,285 — 4,812 239 4,470 239 
Consumer2 2 — 21 4 27 4 
 $14,037 $15,123 $— $18,397 $470 $17,610 $833 
With an allowance recorded       
Real estate:       
Residential 1-4 family$8,783 $8,835 $898 $8,296 $86 $8,377 $265 
Commercial real estate853 853 2 881 9 894 28 
Home equity line of credit10,089 10,099 322 11,332 143 11,606 425 
Residential land— — — — — 36 — 
Commercial construction— — — — — — — 
Residential construction— — — — — — — 
Commercial6,470 6,470 1,015 8,330 38 8,026 94 
Consumer505 505 454 556 12 301 14 
 $26,700 $26,762 $2,691 $29,395 $288 $29,240 $826 
Total       
Real estate:       
Residential 1-4 family$15,600 $16,042 $898 $16,858 $261 $16,892 $687 
Commercial real estate1,048 1,053 2 881 9 894 28 
Home equity line of credit12,073 12,234 322 13,129 155 13,697 503 
Residential land3,091 3,294 — 3,205 40 2,543 90 
Commercial construction— — — — — — — 
Residential construction— — — — — — — 
Commercial8,418 8,755 1,015 13,142 277 12,496 333 
Consumer507 507 454 577 16 328 18 
 $40,737 $41,885 $2,691 $47,792 $758 $46,850 $1,659 
*     Since loan was classified as impaired.
Mortgage servicing rights (MSRs). In its mortgage banking business, ASB sells residential mortgage loans to government-sponsored entities and other parties, who may issue securities backed by pools of such loans. ASB retains no beneficial interests in these loans other than the servicing rights of certain loans sold.
ASB received proceeds from the sale of residential mortgages of $128.0 million and $87.8 million for the three months ended September 30, 2020 and 2019, respectively, and $387.2 million and $177.3 million for the nine months ended September 30, 2020 and 2019, respectively, and recognized gains on such sales of $7.7 million and $1.5 million for the three months ended September 30, 2020 and 2019, respectively, and $15.9 million and $3.1 million for the nine months ended September 30, 2020 and 2019, respectively.
There were no repurchased mortgage loans for the three and nine months ended September 30, 2020 and 2019. The repurchase reserve was $0.1 million as of September 30, 2020 and 2019.
40

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Mortgage servicing fees, a component of other income, net, were $0.9 million and $0.8 million for the three months ended September 30, 2020 and 2019, respectively, and $2.5 million and $2.2 million for the nine months ended September 30, 2020 and 2019, respectively.
Changes in the carrying value of MSRs were as follows:
(in thousands)
Gross
carrying amount1
Accumulated amortizationValuation allowanceNet
carrying amount
September 30, 2020$25,024 $(15,089)$(382)$9,553 
December 31, 201921,543 (12,442)— 9,101 
1     Reflects impact of loans paid in full
Changes related to MSRs were as follows:
Three months ended September 30,Nine months ended September 30
(in thousands)2020201920202019
Mortgage servicing rights
Beginning balance$9,911 $8,103 $9,101 $8,062 
Amount capitalized1,119 995 3,481 1,857 
Amortization(1,095)(531)(2,647)(1,352)
Other-than-temporary impairment— — — — 
Carrying amount before valuation allowance9,935 8,567 9,935 8,567 
Valuation allowance for mortgage servicing rights
Beginning balance264 — — — 
Provision118 — 382 — 
Other-than-temporary impairment— — — — 
Ending balance382 — 382 — 
Net carrying value of mortgage servicing rights$9,553 $8,567 $9,553 $8,567 
ASB capitalizes MSRs acquired upon the sale of mortgage loans with servicing rights retained. On a monthly basis, ASB compares the net carrying value of the MSRs to its fair value to determine if there are any changes to the valuation allowance and/or other-than-temporary impairment for the MSRs.
ASB uses a present value cash flow model to estimate the fair value of MSRs. Impairment is recognized through a valuation allowance for each stratum when the carrying amount exceeds fair value, with any associated provision recorded as a component of loan servicing fees included in “Revenues - bank” in the consolidated statements of income. A direct write-down is recorded when the recoverability of the valuation allowance is deemed to be unrecoverable.
Key assumptions used in estimating the fair value of ASB’s MSRs used in the impairment analysis were as follows:
(dollars in thousands)September 30, 2020December 31, 2019
Unpaid principal balance$1,456,434 $1,276,437 
Weighted average note rate3.77 %3.96 %
Weighted average discount rate9.3 %9.3 %
Weighted average prepayment speed17.8 %11.4 %
41

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The sensitivity analysis of fair value of MSRs to hypothetical adverse changes of 25 and 50 basis points in certain key assumptions was as follows:
(dollars in thousands)September 30, 2020December 31, 2019
Prepayment rate:
  25 basis points adverse rate change$(826)$(950)
  50 basis points adverse rate change(1,524)(1,947)
Discount rate:
  25 basis points adverse rate change(65)(102)
  50 basis points adverse rate change(129)(202)
The effect of a variation in certain assumptions on fair value is calculated without changing any other assumptions. This analysis typically cannot be extrapolated because the relationship of a change in one key assumption to the changes in the fair value of MSRs typically is not linear.
Other borrowings.  As of September 30, 2020, ASB had $56.0 million of FHLB advances outstanding. ASB was in compliance with all Advances, Pledge and Security Agreement requirements as of September 30, 2020. ASB also had no federal funds purchased with the Federal Reserve Bank as of September 30, 2020. There were no FHLB advances or federal funds purchased with the Federal Reserve Bank as of December 31, 2019.
Securities sold under agreements to repurchase are accounted for as financing transactions and the obligations to repurchase these securities are recorded as liabilities in the condensed consolidated balance sheets. ASB pledges investment securities as collateral for securities sold under agreements to repurchase. All such agreements are subject to master netting arrangements, which provide for a conditional right of set-off in case of default by either party; however, ASB presents securities sold under agreements to repurchase on a gross basis in the balance sheet. The following tables present information about the securities sold under agreements to repurchase, including the related collateral received from or pledged to counterparties:
(in millions)Gross amount
 of recognized
 liabilities		Gross amount
 offset in the 
Balance Sheets		Net amount of
liabilities presented
in the Balance Sheets
Repurchase agreements   
September 30, 2020$96 $— $96 
December 31, 2019115 — 115 

 Gross amount not offset in the Balance Sheets
(in millions) Net amount of liabilities presented
in the Balance Sheets		Financial
instruments		Cash
collateral
pledged
Commercial account holders
September 30, 2020$96 $116 $— 
December 31, 2019115 130 — 
The securities underlying the agreements to repurchase are book-entry securities and were delivered by appropriate entry into the counterparties’ accounts or into segregated tri-party custodial accounts at the FHLB. The securities underlying the agreements to repurchase continue to be reflected in ASB’s asset accounts.
Derivative financial instruments. ASB enters into interest rate lock commitments (IRLCs) with borrowers, and forward commitments to sell loans or to-be-announced mortgage-backed securities to investors to hedge against the inherent interest rate and pricing risks associated with selling loans.
ASB enters into IRLCs for residential mortgage loans, which commit ASB to lend funds to a potential borrower at a specific interest rate and within a specified period of time. IRLCs that relate to the origination of mortgage loans that will be held for sale are considered derivative financial instruments under applicable accounting guidance. Outstanding IRLCs expose ASB to the risk that the price of the mortgage loans underlying the commitments may decline due to increases in mortgage interest rates from inception of the rate lock to the funding of the loan. The IRLCs are free-standing derivatives which are carried at fair value with changes recorded in mortgage banking income.
42

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
ASB enters into forward commitments to hedge the interest rate risk for rate locked mortgage applications in process and closed mortgage loans held for sale. These commitments are primarily forward sales of to-be-announced mortgage backed securities. Generally, when mortgage loans are closed, the forward commitment is liquidated and replaced with a mandatory delivery forward sale of the mortgage to a secondary market investor. These commitments are free-standing derivatives which are carried at fair value with changes recorded in mortgage banking income.
Changes in the fair value of IRLCs and forward commitments subsequent to inception are based on changes in the fair value of the underlying loan resulting from the fulfillment of the commitment and changes in the probability that the loan will fund within the terms of the commitment, which is affected primarily by changes in interest rates and the passage of time.
The notional amount and fair value of ASB’s derivative financial instruments were as follows:
 September 30, 2020December 31, 2019
(in thousands)Notional amountFair valueNotional amountFair value
Interest rate lock commitments$129,806 $5,271 $23,171 $297 
Forward commitments104,500 (243)29,383 (42)
ASB’s derivative financial instruments, their fair values and balance sheet location were as follows:
Derivative Financial Instruments Not Designated as Hedging Instruments 1
September 30, 2020December 31, 2019
(in thousands) Asset derivatives Liability
derivatives 		 Asset derivatives Liability
derivatives
Interest rate lock commitments$5,271 $— $297 $— 
Forward commitments— 243 3 45 
 $5,271 $243 $300 $45 
1 Asset derivatives are included in other assets and liability derivatives are included in other liabilities in the balance sheets.
The following table presents ASB’s derivative financial instruments and the amount and location of the net gains or losses recognized in ASB’s statements of income:
Derivative Financial Instruments Not Designated as Hedging Instruments Location of net gains (losses) recognized in the Statements of IncomeThree months ended September 30,Nine months ended September 30
(in thousands)2020201920202019
Interest rate lock commitmentsMortgage banking income$2,930 $(3)$4,974 $379 
Forward commitmentsMortgage banking income44 39 (201)(33)
 $2,974 $36 $4,773 $346 
Low-Income Housing Tax Credit (LIHTC). ASB’s unfunded commitments to fund its LIHTC investment partnerships were $31.3 million and $23.4 million at September 30, 2020 and December 31, 2019, respectively. These unfunded commitments were unconditional and legally binding and are recorded in other liabilities with a corresponding increase in other assets. As of September 30, 2020, ASB did not have any impairment losses resulting from forfeiture or ineligibility of tax credits or other circumstances related to its LIHTC investment partnerships.
43

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Note 5 · Credit agreements and changes in debt
HEI and Hawaiian Electric each entered into a separate agreement with a syndicate of eight financial institutions (the HEI Facility and Hawaiian Electric Facility, respectively, and together, the Credit Facilities), effective July 3, 2017, to amend and restate their respective previously existing revolving unsecured credit agreements. The $150 million HEI Facility and $200 million Hawaiian Electric Facility both will terminate on June 30, 2022. None of the facilities are collateralized. As of September 30, 2020 and December 31, 2019, no amounts were outstanding under the Credit Facilities.
The Credit Facilities will be maintained to support each company’s respective short-term commercial paper program, but may be drawn on to meet each company’s respective working capital needs and general corporate purposes.
Changes in debt. On April 20, 2020, HEI closed on a $65 million 364-day term loan from a syndicate of two banks. The loan bears interest at a floating rate at HEI’s option of either (i) a rate equal to an alternate base rate as defined in the agreement or (ii) a rate equal to an adjusted London interbank offered rate, as defined in the agreement, plus an applicable margin, and matures on April 19, 2021. The proceeds of the loan were used to pay down the balance on the HEI Facility, which increased the available borrowing capacity on the HEI Facility by $65 million. The loan contains provisions requiring the maintenance by HEI of certain financial ratios substantially consistent with those in HEI’s existing, amended and restated revolving unsecured credit agreement. The loan may be prepaid without penalty at any time, but proceeds from any debt capital market transactions over $50 million must first be applied to pay down the term loan.
On September 11, 2020, HEI entered into a $50 million note purchase agreement (HEI NPA) with The Prudential Insurance Company of America and several of its affiliates under which HEI has authorized the issue and sale of $50 million of unsecured senior notes (HEI Notes). Under the HEI NPA, HEI plans to draw $50 million on or before December 29, 2020. The HEI Notes bear interest at a fixed rate of 2.98%, require semi-annual interest payments, and mature December 15, 2030. The HEI Notes include substantially the same financial covenants and customary conditions as the HEI Facility. The proceeds from the HEI Notes will be used to refinance short-term borrowings and for general corporate purposes. The HEI Notes may be prepaid in whole or in part at any time at the prepayment price of the principal amount, together with interest accrued to the date of prepayment plus a “Make-Whole Amount,” as defined in the agreement.
On September 28, 2020, Ka‘ie‘ie Waho Company, LLC (KWCL), a wholly owned indirect subsidiary of HEI, entered into a $13 million non-recourse term loan agreement with Bank of Hawaii. The proceeds of the loan were used to acquire a 6-MW solar photovoltaic facility on Kauai, which serves as collateral for the loan. The loan bears interest at a rate equal to LIBOR, as defined in the agreement, plus 2.00%, matures September 28, 2031, and requires the maintenance of a minimum debt service coverage ratio equal to at least 1.10 to 1.0. The loan requires quarterly principal and monthly interest payments, which total approximately $0.4 million per quarter.
On April 20, 2020, Hawaiian Electric closed on a $75 million 364-day revolving credit agreement (364-day Revolver) with a syndicate of four banks. Under the 364-day Revolver, draws bear interest at a floating rate at Hawaiian Electric’s option of either (i) a rate equal to an alternate base rate as defined in the agreement or (ii) a rate equal to an adjusted London interbank offered rate, as defined in the agreement, plus an applicable margin, requires annual fees for undrawn amounts, and terminates on April 19, 2021. The 364-day Revolver includes substantially the same financial covenant and customary representations and warranties, affirmative and negative covenants, and events of default (the occurrence of which may result in the loan outstanding becoming immediately due and payable) consistent with those in Hawaiian Electric’s existing, amended and restated revolving unsecured credit agreement. As of September 30, 2020, Hawaiian Electric had no amounts outstanding on this revolving credit agreement.
44

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
On May 14, 2020, the Utilities issued, through a private placement pursuant to separate note purchase agreements (NPAs), the following unsecured senior notes bearing taxable interest (May Notes):
Series 2020ASeries 2020BSeries 2020C
Aggregate principal amount
$80 million$60 million$20 million
Fixed coupon interest rate
Hawaiian Electric3.31%3.31%3.96%
Hawaii Electric Light3.96%
Maui Electric3.31%3.96%
Maturity date
Hawaiian Electric5/1/20305/1/20305/1/2050
Hawaii Electric Light5/1/2050
Maui Electric5/1/20305/1/2050
Principal amount by company:
     Hawaiian Electric
$50 million
(Green Bond)
$40 million$20 million
     Hawaii Electric Light$10 million— —
     Maui Electric$20 million$20 million—
The May Notes include substantially the same financial covenants and customary conditions as Hawaiian Electric’s credit agreement. Hawaiian Electric is also a party as guarantor under the NPAs entered into by Hawaii Electric Light and Maui Electric. All of the proceeds of the May Notes were used by Hawaiian Electric, Hawaii Electric Light and Maui Electric to finance their capital expenditures and/or to reimburse funds used for the payment of capital expenditures. The May Notes may be prepaid in whole or in part at any time at the prepayment price of the principal amount, together with interest accrued to the date of prepayment plus a “Make-Whole Amount,” as defined in the agreement.
On May 19, 2020, Hawaiian Electric paid off and terminated the $100 million term loan credit agreement dated as of December 23, 2019. In addition, Hawaiian Electric entered into a 364-day, $50 million term loan credit agreement that matures on April 19, 2021. The term loan credit agreement includes substantially the same financial covenant and customary representations and warranties, affirmative and negative covenants, and events of default (the occurrence of which may result in the loan outstanding becoming immediately due and payable) consistent with those in Hawaiian Electric’s existing, amended and restated revolving unsecured credit agreement. The loan may be prepaid without penalty at any time, but proceeds from any debt capital market transactions over $75 million must be first applied to pay down the term loan. Hawaiian Electric drew the full $50 million on May 19, 2020.
Changes in debt-subsequent event. On October 29, 2020, the Utilities executed, through a private placement pursuant to separate NPAs, unsecured senior notes bearing taxable interest (October Notes) as shown in the table below. Funding for this transaction will occur on or before January 15, 2021, with a written notice to each purchaser at least seven business days prior to receiving funds.
Series 2020BSeries 2020CSeries 2020DSeries 2020E
Aggregate principal amount
$15 million$40 million$30 million$30 million
Fixed coupon interest rate
Hawaiian Electric3.28%3.51%
Hawaii Electric Light3.28%3.51%
Maui Electric3.51%
Maturity date (from funding)
Hawaiian Electric
20 years
30 years
Hawaii Electric Light
20 years
30 years
Maui Electric
30 years
Principal amount by company:
     Hawaiian Electric——$30 million$30 million
     Hawaii Electric Light$15 million$15 million— —
     Maui Electric— $25 million— —

45

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The October Notes include substantially the same financial covenants and customary conditions as Hawaiian Electric’s credit agreement. Hawaiian Electric is also a party as guarantor under the NPAs entered into by Hawaii Electric Light and Maui Electric. The Utilities did not obtain any of the proceeds at execution and intend to obtain funding at a later date, on or prior to January 15, 2021, at which time it will be used to finance their capital expenditures and/or to reimburse funds used for the payment of capital expenditures. The October Notes may be prepaid in whole or in part at any time at the prepayment price of the principal amount plus a “Make-Whole Amount.”
Note 6 · Shareholders’ equity
Accumulated other comprehensive income/(loss).  Changes in the balances of each component of accumulated other comprehensive income/(loss) (AOCI) were as follows:
HEI ConsolidatedHawaiian Electric Consolidated
 (in thousands) Net unrealized gains (losses) on securities Unrealized gains (losses) on derivativesRetirement benefit plansAOCIAOCI-Retirement benefit plans
Balance, December 31, 2019$2,481 $(1,613)$(20,907)$(20,039)$(1,279)
Current period other comprehensive income (loss)19,767 (2,129)1,682 19,320 99 
Balance, September 30, 2020$22,248 $(3,742)$(19,225)$(719)$(1,180)
Balance, December 31, 2018$(24,423)$(436)$(25,751)$(50,610)$99 
Current period other comprehensive income (loss)27,368 (1,663)532 26,237 73 
Balance, September 30, 2019$2,945 $(2,099)$(25,219)$(24,373)$172 

Reclassifications out of AOCI were as follows:
 Amount reclassified from AOCI 
 Three months ended September 30Nine months ended September 30Affected line item in the
 Statements of Income / Balance Sheets
(in thousands)2020201920202019
HEI consolidated
Net realized gains on securities included in net income$— $(478)$(1,638)$(478)Gain on sale of investment securities, net
Retirement benefit plans:     
Amortization of prior service credit and net losses recognized during the period in net periodic benefit cost6,324 2,615 17,720 7,621 
See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets(5,721)(2,493)(16,038)(7,089)
See Note 8 for additional details
Total reclassifications$603 $(356)$44 $54  
Hawaiian Electric consolidated
Retirement benefit plans:   
Amortization of prior service credit and net losses recognized during the period in net periodic benefit cost$5,769 $2,519 $16,137 $7,162 
See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets(5,721)(2,493)(16,038)(7,089)
See Note 8 for additional details
Total reclassifications$48 $26 $99 $73  

46

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Note 7 · Revenues
Revenue from contracts with customers. The following tables disaggregate revenues by major source, timing of revenue recognition, and segment:
Three months ended September 30, 2020Nine months ended September 30, 2020
(in thousands) Electric  utilityBankOtherTotalElectric  utilityBankOtherTotal
Revenues from contracts with customers
Electric energy sales - residential
$191,321 $— $— $191,321 $569,177 $— $— $569,177 
Electric energy sales - commercial
171,156 — — 171,156 528,135 — — 528,135 
Electric energy sales - large light and power
176,200 — — 176,200 568,887 — — 568,887 
Electric energy sales - other 1,935 — — 1,935 7,172 — — 7,172 
Bank fees— 9,589 — 9,589 — 28,356 — 28,356 
Solar energy sales— — 211 211 — — 240 240 
Total revenues from contracts with customers540,612 9,589 211 550,412 1,673,371 28,356 240 1,701,967 
Revenues from other sources
Regulatory revenue15,457 — — 15,457 2,979 — — 2,979 
Bank interest and dividend income
— 59,640 — 59,640 — 184,444 — 184,444 
Other bank noninterest income— 9,415 — 9,415 — 20,296 — 20,296 
Other6,499 — 4 6,503 17,875 — (3)17,872 
Total revenues from other sources21,956 69,055 4 91,015 20,854 204,740 (3)225,591 
Total revenues$562,568 $78,644 $215 $641,427 $1,694,225 $233,096 $237 $1,927,558 
Timing of revenue recognition
Services/goods transferred at a point in time
$— $9,589 $— $9,589 $— $28,356 $— $28,356 
Services/goods transferred over time
540,612 — 211 540,823 1,673,371 — 240 1,673,611 
Total revenues from contracts with customers$540,612 $9,589 $211 $550,412 $1,673,371 $28,356 $240 $1,701,967 


Three months ended September 30, 2019Nine months ended September 30, 2019
(in thousands) Electric  utilityBankOtherTotalElectric  utilityBankOtherTotal
Revenues from contracts with customers
Electric energy sales - residential
$230,051 $— $— $230,051 $601,664 $— $— $601,664 
Electric energy sales - commercial
230,411 — — 230,411 635,097 — — 635,097 
Electric energy sales - large light and power
248,457 — — 248,457 679,252 — — 679,252 
Electric energy sales - other4,081 — — 4,081 11,933 — — 11,933 
Bank fees— 12,111 — 12,111 — 34,976 — 34,976 
Total revenues from contracts with customers713,000 12,111 — 725,111 1,927,946 34,976 — 1,962,922 
Revenues from other sources
Regulatory revenue(30,800)— — (30,800)(44,953)— — (44,953)
Bank interest and dividend income
— 66,859 — 66,859 — 201,502 — 201,502 
Other bank noninterest income— 3,578 — 3,578 — 10,809 — 10,809 
Other6,130 — 4 6,134 17,616 — 86 17,702 
Total revenues from other sources(24,670)70,437 4 45,771 (27,337)212,311 86 185,060 
Total revenues$688,330 $82,548 $4 $770,882 $1,900,609 $247,287 $86 $2,147,982 
Timing of revenue recognition
Services/goods transferred at a point in time
$— $12,111 $— $12,111 $— $34,976 $— $34,976 
Services/goods transferred over time
713,000 — — 713,000 1,927,946 — — 1,927,946 
Total revenues from contracts with customers$713,000 $12,111 $— $725,111 $1,927,946 $34,976 $— $1,962,922 
There are no material contract assets or liabilities associated with revenues from contracts with customers existing at the beginning of the period or as of September 30, 2020. Accounts receivable and unbilled revenues related to contracts with
47

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
customers represent an unconditional right to consideration since all performance obligations have been satisfied. These amounts are disclosed as accounts receivable and unbilled revenues, net on HEI’s condensed consolidated balance sheets and customer accounts receivable, net and accrued unbilled revenues, net on Hawaiian Electric’s condensed consolidated balance sheets.
As of September 30, 2020, the Company had no material remaining performance obligations due to the nature of the Company’s contracts with its customers. For the Utilities, performance obligations are fulfilled as electricity is delivered to customers. For ASB, fees are recognized when a transaction is completed.
Note 8 · Retirement benefits
Defined benefit pension and other postretirement benefit plans information.  For the first nine months of 2020, the Company contributed $53 million ($52 million by the Utilities) to its pension and other postretirement benefit plans, compared to $36 million ($36 million by the Utilities) in the first nine months of 2019. The Company’s current estimate of total contributions to its pension and other postretirement benefit plans in 2020 is $71 million ($70 million by the Utilities, $1 million by HEI and nil by ASB), compared to $49 million ($48 million by the Utilities, $1 million by HEI and nil by ASB) in 2019. In addition, the Company expects to pay directly $2 million ($1 million by the Utilities) of benefits in 2020, compared to $2 million ($1 million by the Utilities) paid in 2019.
The components of net periodic pension costs (NPPC) and net periodic benefit costs (NPBC) for HEI consolidated and Hawaiian Electric consolidated were as follows:
Three months ended September 30Nine months ended September 30
 Pension benefitsOther benefitsPension benefitsOther benefits
(in thousands)20202019202020192020201920202019
HEI consolidated
Service cost$18,341 $15,800 $641 $573 $55,066 $46,564 $1,903 $1,656 
Interest cost20,660 21,150 1,842 2,006 60,987 63,216 5,553 6,000 
Expected return on plan assets(28,422)(27,991)(3,023)(3,101)(85,353)(83,988)(9,100)(9,273)
Amortization of net prior period (gain)/cost
2 (10)(474)(451)7 (32)(1,355)(1,355)
Amortization of net actuarial (gains)/losses
8,944 3,989 53 (3)25,059 11,667 154 (10)
Net periodic pension/benefit cost (return)
19,525 12,938 (961)(976)55,766 37,427 (2,845)(2,982)
Impact of PUC D&Os4,976 11,554 835 821 17,499 36,111 2,389 2,443 
Net periodic pension/benefit cost (adjusted for impact of PUC D&Os)
$24,501 $24,492 $(126)$(155)$73,265 $73,538 $(456)$(539)
Hawaiian Electric consolidated
Service cost$17,921 $15,344 $635 $568 $53,703 $45,346 $1,886 $1,643 
Interest cost19,183 19,560 1,764 1,920 56,613 58,388 5,327 5,755 
Expected return on plan assets(26,815)(26,146)(2,986)(3,064)(80,527)(78,474)(8,966)(9,135)
Amortization of net prior period (gain)/cost
1 2 (474)(451)6 6 (1,353)(1,353)
Amortization of net actuarial losses
8,188 3,841 53 — 22,925 10,993 155 — 
Net periodic pension/benefit cost (return)
18,478 12,601 (1,008)(1,027)52,720 36,259 (2,951)(3,090)
Impact of PUC D&Os4,976 11,554 835 821 17,499 36,111 2,389 2,443 
Net periodic pension/benefit cost (adjusted for impact of PUC D&Os)
$23,454 $24,155 $(173)$(206)$70,219 $72,370 $(562)$(647)
HEI consolidated recorded retirement benefits expense of $46 million ($43 million by the Utilities) in the first nine months of 2020 and $44 million ($43 million by the Utilities) in the first nine months of 2019 and charged the remaining net periodic benefit cost primarily to electric utility plant.
48

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The Utilities have implemented pension and OPEB tracking mechanisms under which all of their retirement benefit expenses (except for executive life and nonqualified pension plan expenses) determined in accordance with GAAP are recovered over time. Under the tracking mechanisms, any actual costs determined in accordance with GAAP that are over/under amounts allowed in rates are charged/credited to a regulatory asset/liability. The regulatory asset/liability for each utility will then be amortized over 5 years beginning with the respective utility’s next rate case.
Defined contribution plans information.  For the first nine months of 2020 and 2019, the Company’s expenses for its defined contribution plans under the Hawaiian Electric Industries Retirement Savings Plan (HEIRSP) and the ASB 401(k) Plan were $5.5 million and $5.1 million, respectively, and cash contributions were $6.0 million and $6.0 million, respectively. For the first nine months of 2020 and 2019, the Utilities’ expenses for its defined contribution plan under the HEIRSP were $2.1 million and $1.9 million, respectively, and cash contributions were $2.1 million and $1.9 million, respectively.
Note 9 · Share-based compensation
Under the 2010 Equity and Incentive Plan, as amended, HEI can issue shares of common stock as incentive compensation to selected employees in the form of stock options, stock appreciation rights, restricted shares, restricted stock units, performance shares and other share-based and cash-based awards. The 2010 Equity and Incentive Plan (original EIP) was amended and restated effective March 1, 2014 (EIP) and an additional 1.5 million shares were added to the shares available for issuance under these programs.
As of September 30, 2020, approximately 3.0 million shares remained available for future issuance under the terms of the EIP, assuming recycling of shares withheld to satisfy minimum statutory tax liabilities relating to EIP awards, including an estimated 0.7 million shares that could be issued upon the vesting of outstanding restricted stock units and the achievement of performance goals for awards outstanding under long-term incentive plans (assuming that such performance goals are achieved at maximum levels).
Under the 2011 Nonemployee Director Stock Plan (2011 Director Plan), HEI can issue shares of common stock as compensation to nonemployee directors of HEI, Hawaiian Electric and ASB. In June 2019, an additional 300,000 shares were made available for issuance under the 2011 Director Plan. As of September 30, 2020, there were 274,163 shares remaining available for future issuance under the 2011 Director Plan.
Share-based compensation expense and the related income tax benefit were as follows:
 Three months ended September 30Nine months ended September 30
(in millions)2020201920202019
HEI consolidated
Share-based compensation expense 1
$1.4 $2.3 $5.4 $8.1 
Income tax benefit0.2 0.3 0.9 1.2 
Hawaiian Electric consolidated
Share-based compensation expense 1
— 0.8 1.2 2.6 
Income tax benefit— 0.1 0.3 0.5 
1    For the three and nine months ended September 30, 2020 and 2019, the Company has not capitalized any share-based compensation.
Stock awards. HEI granted HEI common stock to nonemployee directors under the 2011 Director Plan as follows:
Three months ended September 30Nine months ended September 30
(dollars in millions)2020201920202019
Shares granted— — 36,100 35,580 
Fair value$— $— $1.3 $1.5 
Income tax benefit— — 0.3 0.4 
The number of shares issued to each nonemployee director of HEI, Hawaiian Electric and ASB is determined based on the closing price of HEI common stock on the grant date.
49

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Restricted stock units.  Information about HEI’s grants of restricted stock units was as follows:
Three months ended September 30Nine months ended September 30
 2020201920202019
Shares(1)Shares(1)Shares(1)Shares(1)
Outstanding, beginning of period204,357 $40.65 208,625  $35.28 207,641  $35.36 200,358  $33.05 
Granted— — 1,006 44.16 78,595 47.99 95,565 37.75 
Vested— — (101)36.27 (77,719)34.19 (76,813)32.61 
Forfeited— — (2,889)35.44 (4,160)35.81 (12,469)34.20 
Outstanding, end of period204,357 $40.65 206,641  $35.32 204,357  $40.65 206,641  $35.32 
Total weighted-average grant-date fair value of shares granted (in millions)$— $— $3.8 $3.6 
(1)    Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.
For the first nine months of 2020 and 2019, total restricted stock units and related dividends that vested had a fair value of $4.2 million and $3.2 million, respectively, and the related tax benefits were $0.7 million and $0.5 million, respectively.
As of September 30, 2020, there was $6.2 million of total unrecognized compensation cost related to the nonvested restricted stock units. The cost is expected to be recognized over a weighted-average period of 2.7 years.
Long-term incentive plan payable in stock.  The 2018-2020, 2019-2021 and 2020-2022 long-term incentive plans (LTIP) provide for performance awards under the EIP of shares of HEI common stock based on the satisfaction of performance goals, including a market condition goal. The number of shares of HEI common stock that may be awarded is fixed on the date the grants are made, subject to the achievement of specified performance levels and calculated dividend equivalents. The potential payout varies from 0% to 200% of the number of target shares, depending on the achievement of the goals. The market condition goal is based on HEI’s total shareholder return (TSR) compared to the Edison Electric Institute Index over the relevant three-year period. The other performance condition goals relate to earnings per share (EPS) growth, return on average common equity (ROACE), renewable portfolio standards, Hawaiian Electric’s net income growth, ASB’s efficiency ratio and Pacific Current’s EBITDA growth and return on average invested capital.
LTIP linked to TSR.  Information about HEI’s LTIP grants linked to TSR was as follows:
Three months ended September 30Nine months ended September 30
 2020201920202019
Shares(1)Shares(1)Shares(1)Shares(1)
Outstanding, beginning of period90,616 $42.08 98,311 $39.61 96,402 $39.62 65,578 $38.81 
Granted — — 568 41.07 24,630 48.62 35,215 41.07 
Vested (issued or unissued and cancelled)— — — — (29,409)39.51 — — 
Forfeited— — (2,477)39.64 (1,007)41.72 (4,391)39.19 
Outstanding, end of period90,616 $42.08 96,402 $39.62 90,616 $42.08 96,402  $39.62 
Total weighted-average grant-date fair value of shares granted (in millions)$— $— $1.2 $1.4 
(1)    Weighted-average grant-date fair value per share determined using a Monte Carlo simulation model.
The grant date fair values of the shares were determined using a Monte Carlo simulation model utilizing actual information for the common shares of HEI and its peers for the period from the beginning of the performance period to the grant date and estimated future stock volatility and dividends of HEI and its peers over the remaining three-year performance period. The expected stock volatility assumptions for HEI and its peer group were based on the three-year historic stock volatility, and the annual dividend yield assumptions were based on dividend yields calculated on the basis of daily stock prices over the same three-year historical period.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The following table summarizes the assumptions used to determine the fair value of the LTIP awards linked to TSR and the resulting fair value of LTIP awards granted:
20202019
Risk-free interest rate1.39 %2.48 %
Expected life in years33
Expected volatility13.1 %15.8 %
Range of expected volatility for Peer Group
13.6% to 95.4%
15.0% to 73.2%
Grant date fair value (per share)$48.62$41.07
For the nine months ended September 30, 2020, total vested LTIP awards linked to TSR and related dividends had a fair value of $2.6 million and the related tax benefits were $0.4 million. There were no share-based LTIP awards linked to TSR with a vesting date in 2019.
As of September 30, 2020, there was $1.6 million of total unrecognized compensation cost related to the nonvested performance awards payable in shares linked to TSR. The cost is expected to be recognized over a weighted-average period of 1.2 years.
LTIP awards linked to other performance conditions.  Information about HEI’s LTIP awards payable in shares linked to other performance conditions was as follows:
Three months ended September 30Nine months ended September 30
2020201920202019
 Shares(1)Shares (1)Shares(1)Shares(1)
Outstanding, beginning of period297,523 $40.37 407,090  $35.12 403,768 $35.15 276,169  $33.80 
Granted — — 2,275 44.05 98,522 48.10 140,855 37.78 
Vested — — —  — (135,804)33.48 —  — 
Increase above target (cancelled)(21,807)34.11 11,131  33.49 (86,739)34.12 11,131  33.49 
Forfeited— — (9,911)35.24 (4,031)39.67 (17,570)34.66 
Outstanding, end of period275,716 $40.86 410,585  $35.12 275,716 $40.86 410,585  $35.12 
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)
$— $0.1 $4.7 $5.3 
(1)    Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.
For the nine months ended September 30, 2020, total vested LTIP awards linked to other performance conditions and related dividends had a fair value of $7.6 million and the related tax benefits were $1.2 million. There were no share-based LTIP awards linked to other performance conditions with a vesting date in 2019.
As of September 30, 2020, there was $5.8 million of total unrecognized compensation cost related to the nonvested shares linked to performance conditions other than TSR. The cost is expected to be recognized over a weighted-average period of 1.4 years.
Note 10 · Income taxes
The Company’s and the Utilities’ effective tax rates (combined federal and state income tax rates) were 17% and 19%, respectively, for the nine months ended September 30, 2020. These rates differed from the combined statutory rates, due primarily to the Utilities’ amortization of excess deferred income taxes related to the provision in the Tax Act that lowered the federal income tax rate from 35% to 21%, the tax benefits derived from the low income housing tax credit investments and the non-taxability of the bank-owned life insurance income. The Company’s and the Utilities’ effective tax rates were 19% and 20%, respectively, for the nine months ended September 30, 2019.

In August 2020, the Internal Revenue Service notified the Company that its 2017 and 2018 income tax returns will be examined. The Company was previously audited every year through 2011, at which time the IRS changed their internal policies regarding audit frequency. The Company has received several initial requests for general tax return information and has responded or is in the process of responding to such requests.

51

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Note 11 · Cash flows
Nine months ended September 3020202019
(in millions)  
Supplemental disclosures of cash flow information  
HEI consolidated
Interest paid to non-affiliates, net of amounts capitalized$64 $75 
Income taxes paid (including refundable credits)23 55 
Income taxes refunded (including refundable credits)— 4 
Hawaiian Electric consolidated
Interest paid to non-affiliates39 45 
Income taxes paid (including refundable credits)29 55 
Income taxes refunded (including refundable credits)— 4 
Supplemental disclosures of noncash activities  
HEI consolidated
Electric utility property, plant and equipment
   Estimated fair value of noncash contributions in aid of construction (investing)9 7 
   Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)32 37 
Reduction of long-term debt from funds previously transferred for repayment (financing)82 — 
Right-of-use assets obtained in exchange for operating lease obligations (investing)22 5 
Common stock issued (gross) for director and executive/management compensation (financing)1
16 5 
Real estate transferred from property, plant and equipment to other assets held-for-sale (investing)— 9 
Obligations to fund low income housing investments (investing)10 6 
Hawaiian Electric consolidated
Electric utility property, plant and equipment
   Estimated fair value of noncash contributions in aid of construction (investing)9 7 
   Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)28 34 
Reduction of long-term debt from funds previously transferred for repayment (financing)82 — 
Right-of-use assets obtained in exchange for operating lease obligations (investing)16 1 
1 The amounts shown represent the market value of common stock issued for director and executive/management compensation and withheld to satisfy statutory tax liabilities.
Note 12 · Fair value measurements
Fair value measurement and disclosure valuation methodology. The following are descriptions of the valuation methodologies used for assets and liabilities recorded at fair value and for estimating fair value for financial instruments not carried at fair value:
Short-term borrowings—other than bank.  The carrying amount of short-term borrowings approximated fair value because of the short maturity of these instruments.
Investment securities. The fair value of ASB’s investment securities is determined quarterly through pricing obtained from independent third-party pricing services or from brokers not affiliated with the trade. Non-binding broker quotes are infrequent and generally occur for new securities that are settled close to the month-end pricing date. The third-party pricing vendors ASB uses for pricing its securities are reputable firms that provide pricing services on a global basis and have processes in place to ensure quality and control. The third-party pricing services use a variety of methods to determine the fair value of securities that fall under Level 2 of ASB’s fair value measurement hierarchy. Among the considerations are quoted prices for similar securities in an active market, yield spreads for similar trades, adjustments for liquidity, size, collateral characteristics, historic and generic prepayment speeds, and other observable market factors.
To enhance the robustness of the pricing process, ASB will on a quarterly basis compare its standard third-party vendor’s price with that of another third-party vendor. If the prices are within an acceptable tolerance range, the price of the standard vendor will be accepted. If the variance is beyond the tolerance range, an evaluation will be conducted by ASB and a challenge to the price may be made. Fair value in such cases will be based on the value that best reflects the data and observable
52

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
characteristics of the security. In all cases, the fair value used will have been independently determined by a third-party pricing vendor or non-affiliated broker.
The fair value of the mortgage revenue bonds is estimated using a discounted cash flow model to calculate the present value of future principal and interest payments and, therefore is classified within Level 3 of the valuation hierarchy.
Loans held for sale. Residential and commercial loans are carried at the lower of cost or market and are valued using market observable pricing inputs, which are derived from third party loan sales and, therefore, are classified within Level 2 of the valuation hierarchy.
Loans held for investment. Fair value of loans held for investment is derived using a discounted cash flow approach which includes an evaluation of the underlying loan characteristics. The valuation model uses loan characteristics which includes product type, maturity dates and the underlying interest rate of the portfolio. This information is input into the valuation models along with various forecast valuation assumptions including prepayment forecasts, to determine the discount rate. These assumptions are derived from internal and third party sources. Since the valuation is derived from model-based techniques, ASB includes loans held for investment within Level 3 of the valuation hierarchy.
Impaired loans. At the time a loan is considered impaired, it is valued at the lower of cost or fair value. Fair value is determined primarily by using an income, cost or market approach and is normally provided through appraisals. Impaired loans carried at fair value generally receive specific allocations within the allowance for credit losses. For collateral-dependent loans, fair value is commonly based on recent real estate appraisals. These appraisals may utilize a single valuation approach or a combination of approaches including comparable sales and the income approach. Adjustments are routinely made in the appraisal process by the independent appraisers to adjust for differences between the comparable sales and income data available. Such adjustments typically result in a Level 3 classification of the inputs for determining fair value. Non-real estate collateral may be valued using an appraisal, net book value per the borrower’s financial statements, or aging reports, adjusted or discounted based on management’s historical knowledge, changes in market conditions from the time of the valuation and management’s expertise and knowledge of the client and client’s business, resulting in a Level 3 fair value classification. Generally, impaired loans are evaluated quarterly for additional impairment and adjusted accordingly.
Real estate acquired in settlement of loans. Foreclosed assets are carried at fair value (less estimated costs to sell) and are generally based upon appraisals or independent market prices that are periodically updated subsequent to classification as real estate owned. Such adjustments typically result in a Level 3 classification of the inputs for determining fair value. ASB estimates the fair value of collateral-dependent loans and real estate owned using the sales comparison approach.
Mortgage servicing rights. MSRs are capitalized at fair value based on market data at the time of sale and accounted for in subsequent periods at the lower of amortized cost or fair value. MSRs are evaluated for impairment at each reporting date. ASB's MSRs are stratified based on predominant risk characteristics of the underlying loans including loan type and note rate. For each stratum, fair value is calculated by discounting expected net income streams using discount rates that reflect industry pricing for similar assets. Expected net income streams are estimated based on industry assumptions regarding prepayment expectations and income and expenses associated with servicing residential mortgage loans for others. Impairment is recognized through a valuation allowance for each stratum when the carrying amount exceeds fair value, with any associated provision recorded as a component of loan servicing fees included in "Revenues - bank" in the consolidated statements of income. A direct write-down is recorded when the recoverability of the valuation allowance is deemed to be unrecoverable. ASB compares the fair value of MSRs to an estimated value calculated by an independent third-party. The third-party relies on both published and unpublished sources of market related assumptions and its own experience and expertise to arrive at a value. ASB uses the third-party value only to assess the reasonableness of its own estimate.
Deposit liabilities. The fair value of fixed-maturity certificates of deposit was estimated by discounting the future cash flows using the rates currently offered for FHLB advances of similar remaining maturities. Deposit liabilities are classified in Level 2 of the valuation hierarchy.
Other borrowings. For advances and repurchase agreements, fair value is estimated using quantitative discounted cash flow models that require the use of interest rate inputs that are currently offered for advances and repurchase agreements of similar remaining maturities. The majority of market inputs are actively quoted and can be validated through external sources, including broker market transactions and third party pricing services.
Long-term debt—other than bank.  Fair value of fixed-rate long-term debt—other than bank was obtained from third-party financial services providers based on the current rates offered for debt of the same or similar remaining maturities and from discounting the future cash flows using the current rates offered for debt of the same or similar risks, terms, and remaining maturities. The carrying amount of floating rate long-term debt—other than bank approximated fair value because of the short-term interest reset periods. Long-term debt—other than bank is classified in Level 2 of the valuation hierarchy.
53

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Interest rate lock commitments (IRLCs). The estimated fair value of commitments to originate residential mortgage loans for sale is based on quoted prices for similar loans in active markets. IRLCs are classified as Level 2 measurements.
Forward sales commitments. To be announced (TBA) mortgage-backed securities forward commitments are classified as Level 1, and consist of publicly-traded debt securities for which identical fair values can be obtained through quoted market prices in active exchange markets. The fair values of ASB’s mandatory delivery loan sale commitments are determined using quoted prices in the market place that are observable and are classified as Level 2 measurements.
The following table presents the carrying or notional amount, fair value and placement in the fair value hierarchy of the Company’s financial instruments. For stock in Federal Home Loan Bank, the carrying amount is a reasonable estimate of fair value because it can only be redeemed at par.
Estimated fair value
(in thousands)Carrying or notional amountQuoted prices in
active markets
for identical assets
(Level 1)		Significant
 other observable
 inputs
(Level 2)		Significant
unobservable
inputs
(Level 3)		Total
September 30, 2020     
Financial assets     
HEI consolidated
Available-for-sale investment securities
$1,747,658 $— $1,720,473 $27,185 $1,747,658 
Held-to-maturity investment securities
133,858 — 138,622 — 138,622 
Stock in Federal Home Loan Bank
10,920 — 10,920 — 10,920 
Loans, net5,406,249 — 16,806 5,574,616 5,591,422 
Mortgage servicing rights9,553 — — 10,102 10,102 
Derivative assets129,806 — 5,271 — 5,271 
Financial liabilities    
HEI consolidated
Deposit liabilities558,177 — 563,169 — 563,169 
Short-term borrowings—other than bank137,783 — 137,783 — 137,783 
Other bank borrowings151,875 — 151,874 — 151,874 
Long-term debt, net—other than bank2,068,852 — 2,440,950 — 2,440,950 
   Derivative liabilities141,611 243 5,041 — 5,284 
Hawaiian Electric consolidated
Short-term borrowings49,948 — 49,948 — 49,948 
Long-term debt, net 1,561,128 — 1,895,820 — 1,895,820 
December 31, 2019     
Financial assets     
HEI consolidated
Available-for-sale investment securities
$1,232,826 $— $1,204,229 $28,597 $1,232,826 
Held-to-maturity investment securities
139,451 — 143,467 — 143,467 
Stock in Federal Home Loan Bank
8,434 — 8,434 — 8,434 
Loans, net5,080,107 — 12,295 5,145,242 5,157,537 
Mortgage servicing rights9,101 — — 12,379 12,379 
Derivative assets25,179 — 300 — 300 
Financial liabilities    
HEI consolidated
Deposit liabilities769,825 — 765,976 — 765,976 
Short-term borrowings—other than bank185,710 — 185,710 — 185,710 
Other bank borrowings115,110 — 115,107 — 115,107 
Long-term debt, net—other than bank1,964,365 — 2,156,927 — 2,156,927 
Derivative liabilities51,375 33 2,185 — 2,218 
Hawaiian Electric consolidated
Short-term borrowings88,987 — 88,987 — 88,987 
Long-term debt, net 1,497,667 — 1,670,189 — 1,670,189 
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Fair value measurements on a recurring basis.  Assets and liabilities measured at fair value on a recurring basis were as follows:
September 30, 2020December 31, 2019
 Fair value measurements usingFair value measurements using
(in thousands)Level 1Level 2Level 3Level 1Level 2Level 3
Available-for-sale investment securities (bank segment)      
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies
$— $1,625,548 $— $— $1,026,385 $— 
U.S. Treasury and federal agency obligations— 63,588 — — 117,787 — 
Corporate bonds— 31,337 — — 60,057 — 
Mortgage revenue bonds— — 27,185 — — 28,597 
 $— $1,720,473 $27,185 $— $1,204,229 $28,597 
Derivative assets      
Interest rate lock commitments (bank segment)1
$— $5,271 $— $— $297 $— 
Forward commitments (bank segment)1
— — — — 3 — 
 $— $5,271 $— $— $300 $— 
Derivative liabilities
Forward commitments (bank segment)1
$243 $— $— $33 $12 $— 
Interest rate swap (Other segment)2
— 5,041 — — 2,173 — 
$243 $5,041 $— $33 $2,185 $— 
1     Derivatives are carried at fair value in other assets or other liabilities in the balance sheets with changes in value included in mortgage banking income.
2     Derivatives are included in other liabilities in the balance sheets.
The changes in Level 3 assets and liabilities measured at fair value on a recurring basis were as follows:
Three months ended September 30Nine months ended September 30
Mortgage revenue bonds2020201920202019
(in thousands)
Beginning balance$28,827 $28,166 $28,597 $23,636 
Principal payments received(1,642)— (1,642)— 
Purchases— 293 230 4,823 
Unrealized gain (loss) included in other comprehensive income— — — — 
Ending balance$27,185 $28,459 $27,185 $28,459 
ASB holds two mortgage revenue bonds issued by the Department of Budget and Finance of the State of Hawaii. The Company estimates the fair value by using a discounted cash flow model to calculate the present value of estimated future principal and interest payments. The unobservable input used in the fair value measurement is the weighted average discount rate. As of September 30, 2020, the weighted average discount rate was 2.13%, which was derived by incorporating a credit spread over the one month LIBOR rate. Significant increases (decreases) in the weighted average discount rate could result in a significantly lower (higher) fair value measurement.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Fair value measurements on a nonrecurring basis.  Certain assets and liabilities are measured at fair value on a nonrecurring basis and therefore are not included in the tables above. These measurements primarily result from assets carried at the lower of cost or fair value or from impairment of individual assets. The carrying value of assets measured at fair value on a nonrecurring basis were as follows:
  Fair value measurements using
(in thousands) BalanceLevel 1Level 2Level 3
September 30, 2020
   Mortgage servicing rights$6,260 $— $— $6,260 
December 31, 2019
Loans25 — — 25 
For the nine months ended September 30, 2020 and 2019, there were no adjustments to fair value for ASB’s loans held for sale.
The following table presents quantitative information about Level 3 fair value measurements for financial instruments measured at fair value on a nonrecurring basis:
Significant unobservable
 input value (1)
($ in thousands)Fair value Valuation techniqueSignificant unobservable inputRangeWeighted
Average
September 30, 2020
Mortgage servicing rights$6,260 Discounted cash flowPrepayment Speed
11.2% - 21.3%
17.5 %
Discount rate9.3 %9.3 %
December 31, 2019
Residential land$25 Fair value of property or collateral
Appraised value less 7% selling cost
N/A (2)N/A (2)
Total loans$25    
(1) Represents percent of outstanding principal balance.
(2) N/A - Not applicable. There is one asset in each fair value measurement type.
Significant increases (decreases) in any of those inputs in isolation would result in significantly higher (lower) fair value measurements.
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Item 2.  Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion updates “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in HEI’s and Hawaiian Electric’s 2019 Form 10-K and should be read in conjunction with such discussion and the 2019 annual consolidated financial statements of HEI and Hawaiian Electric and notes thereto included in HEI’s and Hawaiian Electric’s 2019 Form 10-K, as well as the quarterly (as of and for the nine months ended September 30, 2020) condensed consolidated financial statements and notes thereto included in this Form 10-Q.
HEI consolidated
Recent developments—COVID-19.
The Company’s Incident Management Team, composed of senior executives across the Company, continues to monitor and manage the COVID-19 situation. Regular updates are provided to the boards of directors of the Company and its subsidiaries to discuss key focus areas, including employee and customer safety, operations, liquidity, cybersecurity, and internal controls over financial reporting. The Company’s top priority remains unchanged, which is to ensure the safety and well-being of our customers, our employees, their families and the community, while at the same time continuing to deliver essential electric and banking services. To protect its employees and customers and minimize community spread of the coronavirus, the Company’s moratorium on non-essential business travel and a mandatory work-from-home policy for all personnel that can perform their work remotely remains in effect. Such work-from-home mandates have not impaired the Company’s ability to maintain effective internal controls over financial reporting and related disclosures. For personnel that cannot perform their work remotely, the Company has taken steps to protect these employees, including implementing practices related to employee and facilities hygiene, in order to ensure the reliability and resilience of its operations. For example, at the Utilities, plant operators and operations crews have been separated into distinct teams with no overlap of personnel in order to mitigate transmission risk amongst critical personnel and to minimize the risk of not having appropriate backup personnel available to perform essential functions. Similarly, at ASB, branch operations continue to serve the community, but the number of open branches has been reduced to match reduced customer volumes, protect employees, and minimize community transmission risk.
The Company has extended various programs to support its customers and the community during this difficult and challenging time. For example, Hawaiian Electric has suspended, through December 31, 2020, customer disconnections for nonpayment and is working closely with impacted customers on payment plans. At ASB, borrowers that are experiencing financial hardship may be eligible to receive a loan forbearance, deferment or extension. Additionally, late fee waivers may be granted for up to three months and ATM fees were waived through July 1, 2020. ASB has also secured loans totaling more than $370 million for affected businesses under the Paycheck Protection Program (PPP). Through the PPP, which was established under the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) and implemented by the United States Small Business Association, ASB has helped approximately 4,100 small businesses, which support roughly 40,000 jobs that contribute to economic activity in Hawaii. See “Recent Developments—COVID-19” in the Bank section of the Management’s Discussion and Analysis of Financial Condition and Results of Operations (MD&A).
For further discussion of the impact of the COVID-19 pandemic on our subsidiaries see “Recent Developments—COVID-19” section in the Electric Utility and Bank MD&As. There has been no material impact on the “Other” segment and Pacific Current as a result of the COVID-19 pandemic.
For a discussion regarding the impact of the economic conditions caused by the pandemic on the Company’s liquidity and capital resources, see discussion under “Financial Condition–Liquidity and capital resources,” contained in each of the HEI Consolidated, Electric Utility and Bank MD&As.
Environmental, Social & Governance.
At HEI, environmental, social and governance (ESG) principles and sustainability have long been fundamental values embedded within all aspects of the Company’s activities. With all of its operations in the middle of the Pacific Ocean, the Company’s long-term health is inextricably linked with the strength of the economy, communities, and environment of the State of Hawaii. This is why the Company’s mission is to be a catalyst for a better Hawaii.
The Company is committed to transparency and providing information to allow customers, community leaders, investors and other stakeholders understand how the Company’s strategies and operations advance ESG objectives and contribute to long-term value creation.
The Company issued its first ESG report in September 2020. This report encompasses ESG policies, principles and results reported during 2019 across the Company’s two primary operating subsidiaries, Hawaiian Electric and ASB. This report is aligned with Sustainability Accounting Standards Board guidance—using the electric utilities standard for Hawaiian Electric, and the commercial banks, commercial finance, and mortgage finance standards for ASB. In future reports, the Company
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intends to incorporate disclosures relating to climate change based on recommendations from the Task Force on Climate-related Financial Disclosures. The Company’s ESG report can be found at www.hei.com/esg.

RESULTS OF OPERATIONS

Three months ended September 30%
(in thousands)20202019changePrimary reason(s)*
Revenues$641,427 $770,882 (17)Decrease for the electric utility and bank segments
Operating income99,561 96,655 3 Increase for electric utility segment, partly offset by decrease for the bank segment
Net income for common stock65,032 63,419 3 Increase due to higher net income at electric utility segment, partly offset by lower net income at the bank segment
Nine months ended September 30%
(in thousands)20202019changePrimary reason(s)*
Revenues$1,927,558 $2,147,982 (10)Decrease for the electric utility and bank segments
Operating income230,819 247,226 (7)Decrease for the bank segment, partly offset by increase for electric utility segment
Net income for common stock147,339 151,619 (3)Decrease due to lower net income at the bank segment, partly offset by higher net income at electric utility segment. See below for effective tax rate explanation
*     Also, see segment discussions which follow.
The Company’s effective tax rates for the third quarters of 2020 and 2019 were 18% and 19%, respectively. The Company’s effective tax rates for the first nine months of 2020 and 2019 were 17% and 19%, respectively. The effective tax rates were lower for the nine months ended September 30, 2020 compared to the same period in 2019 due primarily to higher amortization in 2020 of the Utilities’ regulatory liability related to certain excess deferred income taxes resulting from the Tax Act’s decrease in the federal income tax rate and an increase in excess tax benefits.
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Economic conditions.
Note: The statistical data in this section is from public third-party sources that management believes to be reliable (e.g., Department of Business, Economic Development and Tourism (DBEDT), University of Hawaii Economic Research Organization (UHERO), U.S. Bureau of Labor Statistics, Department of Labor and Industrial Relations (DLIR), Hawaii Tourism Authority (HTA), Honolulu Board of REALTORS® and national and local news media).
On March 11, 2020, the World Health Organization declared the virus strain severe acute respiratory syndrome coronavirus 2 (SARS-CoV-2), and the resulting disease COVID-19, to be a pandemic. In response, the Governor of the State of Hawaii issued a number of emergency and supplementary proclamations to limit the spread of the virus. Hawaii’s economy began to weaken in the latter part of March 2020, due to a forced statewide stay-at-home, work-from-home declaration that began on March 25, 2020. The restrictions shuttered many businesses, including hotels, restaurants, bars, and other gathering places, and led to an overwhelming surge in unemployment claims and impacted the tourism industry with a significant reduction to visitor arrivals. Starting in June 2020, restrictions were gradually lifted and most business activities resumed (with operations modified as required under state guidelines). However, due to an increase in new case counts starting in late July, certain restrictions to minimize the spread of the virus were reinstituted and the mandatory 14-day quarantine requirement for travelers entering the state was extended to be in effect through October 14, 2020. Beginning on October 15, 2020 travelers to Oahu are no longer subject to the mandatory 14-day quarantine if they test negative for COVID-19 within 72 hours of arrival and present valid documentation. Inter-island travel to Hawaii island requires a second test, while a second test is optional for inter-island travel to Maui and Kauai.
The most recent interim forecast by UHERO, which was issued on September 25, 2020, forecasts full year 2020 real GDP contraction of 11.8%, decline in total visitor arrivals of 73.7%, decline in real personal income of 4.9%, and an unemployment rate of 12.4%. However, federal fiscal and monetary policy response is expected to cushion the economic impact of the pandemic.
The CARES Act was passed by Congress and signed into law by President Trump on March 27, 2020. The economic relief package totals more than $2 trillion and provides direct economic support to businesses and individuals. Hawaii has received more than $7 billion through various federal assistance programs, including the CARES Act, that will help attenuate the impact to Hawaii’s economy.
On April 8, 2020, the Governor issued a proclamation appointing Alan Oshima, former CEO of the Utilities, to lead Hawaii’s efforts to develop and implement a plan for economic recovery. The “Hawaii Economic and Community Recovery & Resiliency Plan” includes a concurrent three-part strategy to address both the economic and community impacts of COVID-19 in the areas of stabilization, recovery and resiliency. Under the plan, the Beyond Recovery: Reopening Hawaii strategy conveys Hawaii’s coordinated, statewide strategy to address the COVID-19 health and economic crisis. The reopening strategy outlines a phased approach to pivot from the COVID-19 public health emergency to renew and rebuild our communities into a stronger and more resilient Hawaii moving forward.
In September 2020, the City and County of Honolulu announced a framework for reducing the spread of COVID-19 on Oahu, which tracks metrics that dictate the extent of restrictions on businesses and activities. There are four tiers with Tier 1 being the most restrictive and Tier 4 being the most relaxed. The minimum amount of time spent in each tier is four weeks. In order to move to the next higher tier, the last two weeks of a tier must meet the higher tier’s criteria. If a lower tier’s average daily case count is realized for two weeks in a row, the county will move back to the lower tier for a minimum of four weeks. On October 22, 2020, the county of Honolulu moved from Tier 1 to Tier 2, which relaxes certain restrictions. However, due to the uncertainty surrounding the timing and effectiveness of efforts to contain the spread of the virus while reopening the economy, the pace and the extent of the recovery cannot be predicted at this time.
See “Recent Developments—COVID-19” in the Electric Utility and Bank MD&As for further discussion of the economic impact caused by the pandemic.
Hawaii’s tourism industry, a significant driver of Hawaii’s economy, suffered dramatically with a decline of 71.6% in visitor arrivals through the first nine months of the year primarily due to travel restrictions amid the COVID-19 pandemic. Effective March 26, 2020, a mandatory 14-day self-quarantine was ordered for all travelers, both residents and visitors, to the islands including inter-island travelers. The mandatory quarantine for inter-island travel was lifted on June 16, 2020, but on August 20, 2020, a mandatory 14-day quarantine for travelers arriving on islands other than Oahu was reinstated. The mandatory 14-day quarantine for all travelers from outside the state was lifted, effective October 15, 2020, provided travelers test negative for COVID-19 within 72 hours of arrival and present valid documentation (additional restrictions apply to travel to Hawaii island). As a result of these restrictions, between April 1, 2020 and September 30, 2020, daily passenger counts declined by over 95% to 1,406 passengers on average per day compared to the same time period in 2019. On October 15, 2020, the first day the 14-day mandatory quarantine was no longer in effect if travelers tested negative for COVID-19 within 72 hours of arrival, the daily passenger count increased 333%, compared to the average daily passenger count for the preceding seven days.
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Due to the effects of the measures to contain the COVID-19 pandemic, Hawaii’s seasonally adjusted unemployment rate in September 2020 was 15.1%, which was substantially higher compared to the September 2019 rate of 2.7%. The national unemployment rate in September 2020 was 7.9% compared to 3.5% in September 2019. Hawaii’s unemployment rate is expected to decrease now that restrictions on travel have been reduced significantly. Year-to-date through October 24, 2020, there were 399,049 initial unemployment claims filed with the State compared to 52,332 initial claims, or an increase of 663%, during the same period in 2019.
Hawaii real estate activity through September 2020, as indicated by the home resale market, resulted in an increase in the median sales price of 1.2% for condominiums and 3.3% for single family homes through the same period in 2019. The number of closed sales was down 18.9% for condominiums and 1.4% for single family residential homes through September 2020 compared to same time period of 2019.
Hawaii’s petroleum product prices reflect supply and demand in the Asia-Pacific region and the price of crude oil in international markets. The price of crude oil decreased dramatically since the first quarter of 2020 and has remained at levels lower than last year. Lower fuel prices will benefit customers in the form of lower bills given the high proportion of fuel cost in the cost per kWh, but the benefit will be realized over time as existing inventory levels procured at higher cost are drawn down.
At its September 16, 2020 meeting, the Federal Open Market Committee (FOMC) decided to maintain the federal funds rate target range of 0%-0.25%. The FOMC will continue to maintain an accommodative stance of monetary policy to achieve maximum employment and inflation at the rate of 2 percent over the long run. The Federal Reserve stated that it will increase its holdings of Treasury securities and agency mortgage-backed securities at least at the current pace to sustain smooth market functioning and help foster accommodative financial conditions, thereby supporting the flow of credit to households and businesses.
The Company expects that the negative trends and uncertainties in the multiple sectors described above have contributed and will result in a significant economic downturn for the full year 2020 that may have a material unfavorable impact on the Company’s net revenues or income from continuing operations in 2020.
“Other” segment.
 Three months ended September 30Nine months ended September 30
(in thousands)2020201920202019Primary reason(s)
Revenues$215 $4 $237 $86 Increase in revenues due to solar energy sales at Mauo, LLC.
Operating loss(4,457)(3,446)(12,854)(12,503)
The third quarters of 2020 and 2019 include $0.2 million and $1.0 million, respectively, of operating income from Pacific Current1. Third quarter 2020 corporate expense was $0.3 million higher compared to the third quarter of 2019, primarily due to higher professional fees. The first nine months of 2020 and 2019 include $2.0 million and $2.3 million, respectively, of operating income from Pacific Current1. The first nine months of 2020 corporate expense was comparable to the same period in 2019.
Net loss (7,183)(6,248)(20,885)(20,603)
The net loss for the third quarter of 2020 was higher than the net loss for the third quarter of 2019 due to the same factors cited for the change in operating loss. The net loss for the first nine month of 2020 was lower than the net loss for the first nine months of 2019 due to the same factors cited for the change in operating loss.
1     Hamakua Energy’s sales to Hawaii Electric Light (a regulated affiliate) are eliminated in consolidation.

The “other” business segment (loss)/income includes results of the stand-alone corporate operations of HEI (including eliminations of intercompany transactions) and ASB Hawaii, Inc. (ASB Hawaii), as well as the results of Pacific Current, a direct subsidiary of HEI focused on investing in clean energy and sustainable infrastructure projects; Pacific Current’s indirect subsidiary, Hamakua Energy, which owns a 60-MW combined cycle power plant that provides electricity to Hawaii Electric Light; Pacific Current’s indirect subsidiary, Mauo, LLC (Mauo), which is currently constructing a solar-plus-storage project totaling 8.6 MW on five University of Hawaii campuses; and Pacific Current’s subsidiary, Ka‘ie‘ie Waho Company, LLC, which owns a 6 MW solar photovoltaic system that provides renewable energy to Kauai Island Utility Cooperative; as well as eliminations of intercompany transactions.

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FINANCIAL CONDITION
Liquidity and capital resources. In the first quarter of 2020, the capital markets, including the commercial paper markets, experienced high levels of volatility, and in some cases, disruption. As a result, in March 2020, due to elevated concerns regarding corporate credit risk, the commercial paper markets experienced significantly less liquidity, particularly for tier-3 issuers. As a consequence, HEI and Hawaiian Electric were unable to place commercial paper at reasonable rates and instead borrowed under their respective backup revolving credit facilities (floating rate at an adjusted London interbank offered rate, as defined in the agreements, plus 137.5 basis points or an alternate base rate, as defined in the agreements, plus 37.5 basis points). In the second quarter of 2020, conditions gradually improved in the commercial paper market for tier-3 issuers, and as a result, HEI returned to the commercial paper markets for its short-term borrowings at average rates that were lower than the average rates before the pandemic. As of September 30, 2020, HEI and Hawaiian Electric had approximately $23 million and nil of commercial paper outstanding, respectively.
As of September 30, 2020, there was no balance on HEI’s revolving credit facility and the available committed capacity under the revolving credit facility was $150 million. As of September 30, 2020, there was no balance on Hawaiian Electric’s revolving credit facilities and the available committed capacity under the revolving credit facilities was $275 million. As of September 30, 2020, ASB’s unused FHLB borrowing capacity was approximately $2.0 billion.
The Company expects that its liquidity will continue to be moderately impacted due to COVID-19. For the Utilities, the high level of unemployment in the state and the moratorium on customer disconnections (which moratorium is currently in place through December 31, 2020) are expected to result in higher accounts receivable balances, bad debt expense and write-offs. Additionally, lower kWh sales generally result in delayed timing of cash flows, resulting in higher working capital requirements (see “Recent Developments—COVID-19” in the Electric Utility MD&A). At ASB, liquidity remains at satisfactory levels. ASB’s cash and cash equivalents was $161.0 million as of September 30, 2020, compared to $178.4 million as of December 31, 2019. ASB remains well above the “well capitalized” level, but there continues to be significant uncertainty regarding COVID-19’s impact on loan performance and the allowance for credit losses (see “Recent Developments — COVID-19” in the Bank MD&A).
To preserve and enhance the Company’s liquidity position, in light of the significant and ongoing uncertainty regarding the potential scale and duration of the COVID-19 pandemic and its impact on the global, national and local economy, the Company took a number of steps. First, on April 20, 2020, HEI borrowed $65 million under a 364-day term loan to refinance the outstanding amounts under its revolving credit facility and thereby increase the available committed borrowing capacity under its revolving credit facility. Secondly, on April 20, 2020, the Utilities added an incremental $75 million in committed revolving credit capacity at Hawaiian Electric with a 364-day revolving credit facility (see Note 5 of the Condensed Consolidated Financial Statements). Thirdly, the Utilities also launched and closed on a $160 million private placement of taxable debt on May 14, 2020, the proceeds of which were used to finance capital expenditures, repay short-term debt used to finance or refinance capital expenditures, and reimburse funds for payment of capital expenditures. In addition, the Utilities executed a $115 million private placement of taxable debt on October 29, 2020 to finance their capital expenditures and/or to reimburse funds used for the payment of capital expenditures. The private placement has a delayed draw feature, which allows the Utilities to draw the funds at any time on or before January 15, 2021. Finally, $50 million of an existing 364-day term loan was refinanced with a new $50 million term loan maturing in April 2021. On September 11, 2020, HEI executed a $50 million private placement utilizing a delayed draw feature, which allows HEI to draw the funds at any time on or before December 29, 2020. Proceeds from the notes will be ultimately used to refinance HEI’s $50 million long-term notes maturing in March of 2021, but will provide additional liquidity in the interim period. The notes bear interest at 2.98% and mature on December 15, 2030. As of September 30, 2020 the total amount of available borrowing capacity (net of commercial paper outstanding) under the Company’s committed lines of credit was approximately $402 million, which was an increase of approximately $188 million compared to December 31, 2019. HEI and the Utilities have no remaining long-term debt maturities in 2020.
In addition to the foregoing financing transactions, in order to further enhance the Company’s liquidity position, the Company has deferred, pursuant to section 2302 of the CARES Act, the payment of the applicable employer portion of Old-Age, Survivors and Disability Insurance payroll tax deposits that are due in 2020, but arose subsequent to the enactment of the CARES Act, which is estimated to be approximately $10 million. Fifty percent of the deferred payroll taxes will be paid in each of December 2021 and December 2022. The Company has also deferred approximately $5.8 million per month in planned monthly pension contributions through August 2020 to further strengthen its liquidity position, but elected to fund such deferred contributions in September 2020 in order to deduct the contributions on its 2019 tax return. If further liquidity is necessary, which is not contemplated at this time, the Utilities could also reduce the pace of capital spending related to non-essential projects. Additionally, the Company has the option to issue new shares rather than purchase currently outstanding shares on the open market to satisfy share issuances under its Dividend Reinvestment and Stock Purchase Plan (DRIP) program. The estimated amount of capital that could be preserved by issuing new shares, rather than utilizing open market purchases, is estimated to be approximately $30 million on an annual basis, based on historical demand, but such future amount is dependent on a number of factors, including, without limitation, future share prices, number of shares/participants in the DRIP program,
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and the amount of new investment in HEI’s stock by DRIP participants.
The Company believes that its ability to generate cash, both internally from electric utility and banking operations and externally from issuances of equity and debt securities, as well as bank borrowings, is adequate to maintain sufficient liquidity to fund its contractual obligations and commercial commitments, its forecasted capital expenditures and investments, its expected retirement benefit plan contributions and other cash requirements. However, the COVID-19 pandemic is a rapidly evolving situation, and the Company cannot predict the extent or duration of the outbreak, the future effects that it will have on the global, national or local economy, including the impact on the Company’s cost of capital and its ability to access additional capital, or the future impacts on the Company’s financial position, results of operations, and cash flows. See Item 1A. “Risk Factors” in Part II for further discussion of risks and uncertainties.
The consolidated capital structure of HEI (excluding deposit liabilities and other bank borrowings) was as follows:
(dollars in millions)September 30, 2020December 31, 2019
Short-term borrowings—other than bank$138 3 %$186 4 %
Long-term debt, net—other than bank2,069 45 1,964 44 
Preferred stock of subsidiaries34 1 34 1 
Common stock equity2,323 51 2,280 51 
 $4,564 100 %$4,464 100 %
HEI’s commercial paper borrowings and line of credit facility were as follows:
 Average balanceBalance
(in millions) Nine months ended September 30, 2020September 30, 2020December 31, 2019
Commercial paper$26 $23 $97 
Line of credit draws9 — — 
Undrawn capacity under HEI’s line of credit facility 150 150 
Note: This table does not include Hawaiian Electric’s separate commercial paper issuances and line of credit facilities and draws, which are disclosed below under “Electric utility—Financial Condition—Liquidity and capital resources.” The maximum amount of HEI’s external short-term borrowings during the first nine months of 2020 was $99 million.
HEI has a $150 million line of credit facility with no amounts outstanding at September 30, 2020. See Note 5 of the Condensed Consolidated Financial Statements.
There were no new issuances of common stock through the DRIP, HEIRSP or the ASB 401(k) Plan in the nine months ended September 30, 2020 and 2019 and HEI satisfied the share purchase requirements of the DRIP, HEIRSP and ASB 401(k) Plan through open market purchases of its common stock.
For the first nine months of 2020, net cash provided by operating activities of HEI consolidated was $312 million. Net cash used by investing activities for the same period was $1,145 million, primarily due to capital expenditures, ASB’s purchases of available-for-sale investment securities and ASB’s net increase in loans, partly offset by ASB’s receipt of repayments from and sales of available-for-sale investment securities. Net cash provided by financing activities during this period was $820 million as a result of several factors, including net increases in ASB’s deposit liabilities and other bank borrowings and the issuances of short-term and long-term debt, partly offset by net decrease in short-term borrowings, repayment of short-term and long-term debt and payment of common stock dividends. During the first nine months of 2020, Hawaiian Electric and ASB (through ASB Hawaii) paid cash dividends to HEI of $80 million and $28 million, respectively.
Dividends.  The payout ratios for the first nine months of 2020 and full year 2019 were 73% and 64%, respectively. HEI currently expects to maintain its dividend at its present level; however, the HEI Board of Directors evaluates the dividend quarterly and considers many factors in the evaluation including, but not limited to, the Company’s results of operations, the long-term prospects for the Company and current and expected future economic conditions, including impacts from the COVID-19 pandemic.
MATERIAL ESTIMATES AND CRITICAL ACCOUNTING POLICIES
In preparing financial statements, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities and the reported amounts of revenues and expenses. Actual results could differ significantly from those estimates.
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In accordance with SEC Release No. 33-8040, “Cautionary Advice Regarding Disclosure About Critical Accounting Policies,” management has identified the accounting policies it believes to be the most critical to the Company’s financial statements—that is, management believes that these policies are both the most important to the portrayal of the Company’s results of operations and financial condition, and currently require management’s most difficult, subjective or complex judgments.
For information about these material estimates and critical accounting policies, in addition to the critical policy discussed below, see pages 38 to 39, 51 to 52, and 67 to 68 of HEI’s MD&A included in Part II, Item 7 of HEI’s 2019 Form 10-K.
Allowance for credit losses. The Company considers the policies related to the allowance for credit losses as critical to the financial statement presentation. The allowance for credit losses applies to financial assets subject to credit losses and measured at amortized cost and certain off-balance sheet credit exposures. This includes, but is not limited to loans, loan commitments and held-to-maturity securities. In addition, the accounting for credit losses on AFS debt securities and purchased financial assets with credit deterioration were amended. The other-than-temporary impairment model of accounting for credit losses on AFS debt securities was replaced with an estimate of expected credit losses only when the fair value is below the amortized cost of the asset. The credit loss models use a probability-of-default, loss given default and exposure at default methodology to estimate the expected credit losses. Within each model or calculation, loans are further segregated based on additional risk characteristics specific to that loan type, such as risk rating, FICO score, bankruptcy score, age of loan and collateral. The Company uses both internal and external historical data, as appropriate, and a blend of economic forecasts to estimate credit losses over a reasonable and supportable forecast period and then reverts to a longer-term historical loss experience to arrive at lifetime expected credit losses. The reversion period incorporates forward-looking expectations about repayments (including prepayments) as determined by the Company’s asset liability management system. See “Recent Accounting Pronouncements” in Note 1 of the Condensed Consolidated Financial Statements for further discussion of the Company’s allowance for credit losses.
Goodwill. Goodwill is initially recorded as the excess of the purchase price over the fair value of the net assets acquired in a business combination and is subsequently evaluated at least annually for impairment during the fourth quarter. The goodwill relates to ASB, which is the only reporting unit in the Company’s reportable Bank segment, and is the Company’s only intangible asset with an indefinite useful life. At September 30, 2020 the amount of goodwill was $82.2 million. In the third quarter of 2020, the combination of economic impacts from COVID-19 and the resulting reductions in market interest rates led ASB to determine that a triggering event existed, which required an assessment to determine whether goodwill was impaired. To determine if there was an impairment to the book value of goodwill, the fair value of ASB was estimated using a valuation method based on the market and income approaches. The market approach considers publicly traded financial institutions and measures the institutions’ market values as a multiple to (1) net income and (2) tangible book equity. The market approach also looks at sale transactions to determine the fair value under this approach. The mean market value multiples for net income and tangible book equity from the selected institutions were applied to ASB’s last twelve months’ net income, next year’s net income and tangible book equity to calculate ASB’s fair value using the market approach. Industry sale transactions for 2019 and 2020 were reviewed and used to calculate the market approach fair value. The income approach uses a discounted cash flow method to value a company on a going concern basis and is based on the concept that the future benefits derived from a particular company can be measured by its sustainable after-tax cash flows in the future. ASB used its forecasted net income and estimated cost savings if the bank were acquired and applied a discount rate to calculate its discounted cash flows. A capitalization of earnings method was used to calculate a terminal value for the discounted cash flow method. The income approach was weighted 75%, the publicly traded company valuation method was weighted 20% and the sale transaction valuation method was weighted 5%. More weight was given to the income approach as this approach uses the projected performance of ASB in the stressed environment and would be more indicative of the current fair value of the Bank. The impairment test for ASB as of the third quarter of 2020 resulted in no goodwill impairment, since the estimated fair value of the reporting unit exceeded its carrying value by more than 35%. The calculation of fair value of the reporting unit requires significant estimates and assumptions by management, including but not limited to, forecasted net income, tangible assets, cost savings, control premiums and discount rate. Should the estimates and assumptions regarding the fair value of the reporting unit prove to be incorrect, the Company may be required to record impairments to goodwill in future periods and such impairments could be material.

Following are discussions of the results of operations, liquidity and capital resources of the electric utility and bank segments.
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Electric utility
Recent developments—COVID-19
See also Recent developments—COVID-19 in HEI’s MD&A.
Economic conditions in Hawaii continue to be severely impacted by the COVID-19 pandemic. Statewide daily passenger counts remain depressed, and unemployment stood at 15.1% as of September 30, 2020. As a consequence of the significant decline in economic activity, the demand for electricity was adversely impacted. In the third quarter of 2020, kWh sales were down 13.1% compared with the same quarter in 2019. For the nine months ended September 30, 2020, sales were down 7.3% compared to the same period last year. For the full year, the Utilities expect the level of kWh sales to be 6%-12% below sales levels achieved in 2019. The Utilities expect continued lower sales due to COVID-19 and that the RPS achievement will exceed the 30% statutory requirement as of December 31, 2020.
While the Utilities do not expect electric energy revenues to be significantly impacted due to the decoupling mechanism, which allows recovery of the difference between PUC approved target revenues and recorded adjusted revenues regardless of the level of kWh sales, the timing of customer collections would be delayed (or accelerated) if the level of kWh sales decreases below (or increases above) the estimated kWh sales. See “Decoupling” in Note 3 of the Condensed Consolidated Financial Statements for a discussion of decoupling. Annually, the Utilities submit a decoupling filing to the PUC, which requests recovery by the utility (or refund to customers) of the difference between recorded adjusted revenues and target revenues under the RBA. The difference is collected or refunded through an adjustment to customer rates in the following year based on estimated sales, starting on June 1st of that following year, which has an impact on the timing of the Utilities’ cash flow. Additionally, although the Utilities’ decoupling mechanism allows for collection under the RBA, the RBA balance accrues interest only at the short-term debt rate from the last rate case (1.75% for Hawaiian Electric, 1.5% for Hawaii Electric Light and 3.0% for Maui Electric). As of September 30, 2020, the RBA credit balance related to decoupling revenues was approximately $0.5 million, a decrease in the credit balance by $16.5 million, or 97% since June 30, 2020. While the billed accounts receivable balances as of September 30, 2020 of $138 million is 9.7% lower than the billed accounts receivable balances as of December 31, 2019, due to lower fuel prices resulting in lower bills, the past due accounts receivable balance has increased by $10 million or 32% since December 31, 2019. The increase is primarily driven by the state mandated stay-at-home order, which was lifted on July 1, 2020, reinstated on August 27, 2020, and lifted again on September 24, 2020, the pandemic’s impact on the tourism industry, resulting in a higher unemployment rate, the moratorium on customer disconnections (which moratorium is currently in place through December 31, 2020) and, for certain customers, the inability to make payment on their accounts. To address the financing requirement related to the delayed timing of cash flows collected under the decoupling mechanism through the RBA and the modest slowing or reduction in accounts receivable collections from customers, the Utilities have completed a number of steps to enhance their liquidity position. See “Financial Condition—Liquidity and capital resources” for additional information.
The Utilities provide an essential service to the State of Hawaii, and have continued to operate to protect the health and safety of employees and customers and to ensure system reliability, and have been following the Governor’s directive that the Utilities take necessary measures to ensure they can operate in the normal course. The Utilities have also implemented certain aspects of their business continuity plans, which includes the activation of its Incident Management Team to closely manage the response to the pandemic and have implemented practices related to employee and facilities hygiene in order to ensure the reliability and resilience of their operations. For example, plant operators and operations crews have been separated into distinct teams with no overlap of personnel in order to mitigate transmission risk amongst critical personnel and to minimize the risk of not having appropriate backup personnel available to perform essential functions. Plans have been developed in the event sequestration of critical personal is required. In the second quarter of 2020, the PUC approved the deferral of certain COVID-19 related expenses, such as higher bad debt expense, higher financing costs, non-collection of late payment fees, increased personal protective equipment costs, and sequestration costs for mission-critical employees. As of September 30, 2020, these costs, which have been deferred and recorded as a regulatory asset, totaled approximately $12.4 million (see also discussion under Item 1A. “Risk Factors” and “Regulatory assets for COVID-19 costs” in Note 3 of the Condensed Consolidated Financial Statements). Looking forward, the prolonged impact of COVID-19 could adversely affect the ability of the Utilities’ contractors, suppliers, IPPs, and other business partners to perform or fulfill their obligations, or require modifications to existing contracts, which could adversely affect the Utilities’ business, increase expenses, and impact the Utilities’ ability to achieve their RPS goals beyond 2020. Additionally, while the state’s aggressive response to the pandemic has dramatically reduced the spread of the coronavirus, the measures taken have had a severe economic impact on the state’s businesses and residents, which may influence the PUC’s actions regarding requested rate increases. See “Item 1A. Risk Factors” in Part II for additional discussion of risks.
At this time, the Utilities are not able to predict what the full impact of the COVID-19 pandemic will have on its results of operations, financial position and cash flows because it is uncertain the extent to which the virus can be contained and the extent to which protective measures to prevent the spread of the virus will be effective.
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For a discussion regarding the impact of the economic conditions caused by the COVID-19 pandemic on the Utilities’ liquidity and capital resources, see discussion under “Financial Condition–Liquidity and capital resources.”
RESULTS OF OPERATIONS
Three months ended September 30Increase
20202019(decrease)(dollars in millions, except per barrel amounts)
$563 $688 $(126)
Revenues. Net decrease largely due to:
$(104)
lower fuel oil prices and lower kWh generated1
(24)
lower purchased power energy prices and lower kWh purchased2
(4)
lower PPAC revenue2
(2)higher cost savings from ERP system implementation to be returned to customers in future rates
1 higher MPIR revenue (increase for West Loch PV project and Grid Modernization project)
7 higher electric rates
105 199 (94)
Fuel oil expense1. Decrease largely due to lower fuel oil prices and lower kWh generated, offset in part by higher fuel handling costs
149 175 (26)
Purchased power expense1, 2. Decrease largely due to lower purchased power energy prices, lower kWh purchased and lower capacity and non-fuel O&M charges
111 124 (13)
Operation and maintenance expenses. Net decrease largely due to:
(7)fewer generating unit overhauls performed in 2020
(3)lower labor due to lower staffing and reduction in overtime
(1)lower vegetation management costs
(1)lower outside services for system support (Distribution Node Mapping and development of portal for CBRE)
(1)less substation and meter maintenance work performed
109 118 (9)
Other expenses. Decrease due to lower revenue taxes offset in part by higher depreciation in 2020 for plant investment in 2019
89 72 17 
Operating income. Increase due to lower operation and maintenance expense, coupled with higher electric rates and higher MPIR revenue, offset in part by higher depreciation expenses
74 58 16 
Income before income taxes. Increase due to lower operation and maintenance expense, higher electric rates, higher MPIR revenue, and lower interest expense due to refinancing of revenue bonds in July 2019 at lower rates, offset in part by higher depreciation expense and lower AFUDC
60 47 13 
Net income for common stock. Increase due to lower operating expenses, coupled with higher electric rates and higher MPIR revenue
2,099 2,414 (315)
Kilowatthour sales (millions)3
$49.71 $82.30 $(32.59)Average fuel oil cost per barrel
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Nine months ended September 30Increase 
20202019(decrease)(dollars in millions, except per barrel amounts)
$1,694 $1,901 $(207)
Revenues. Net decrease largely due to:
$(167)
lower fuel oil prices and lower kWh generated1
(45)
lower purchased power energy prices and lower kWh purchased2
(6)
lower PPAC revenue2
(6)higher cost savings from ERP system implementation to be returned to customers in future rates
3 higher MPIR revenue (increase for West Loch PV project and Grid Modernization project)
14 higher electric rates
391 541 (150)
Fuel oil expense1. Decrease largely due to lower fuel oil prices and lower kWh generated, offset in part by higher fuel handling costs
426 472 (46)
Purchased power expense1 ,2. Decrease largely due to lower purchased power energy prices, lower kWh purchased and lower capacity and non-fuel O&M charges
349 362 (13)
Operation and maintenance expenses. Net decrease largely due to:
(12)fewer generating unit overhauls performed in 2020
(5)lower labor due to lower staffing and reduction in overtime
(3)less station maintenance work performed
1 higher medical premium costs
1 demolition costs for leased office space
1 higher consulting costs for Electrification of Transportation initiatives
1 increase in Pearl Harbor environmental and general liability reserves
3 2019 PUC approval of deferral treatment for previously-incurred expense to modify existing generating units on Maui to run at lower loads in order to accept more renewable generation
329 341 (12)
Other expenses. Decrease due to lower revenue taxes offset in part by higher depreciation expense in 2020 for plant investments in 2019
200 184 16 
Operating income. Increase due to lower operation and maintenance expenses, coupled with higher electric rates and higher MPIR revenue, offset in part by higher depreciation expense
157 141 16 
Income before income taxes. Increase due to lower operation and maintenance expense, higher electric rates, higher MPIR revenue and lower interest expense due to the hybrid securities redemption replaced with lower cost debt (in May 2019) and refinancing of revenue bonds (in July 2019) at lower rates, offset by higher depreciation expense and lower AFUDC
126 111 15 
Net income for common stock. Increase due to lower operating expenses, coupled with higher electric rate and higher MPIR revenue. See below for effective tax rate explanation
5,979 6,449 (470)
Kilowatthour sales (millions)3
$64.70 $83.64 $(18.94)Average fuel oil cost per barrel
466,943 464,892 2,051 Customer accounts (end of period)
1The rate schedules of the electric utilities currently contain ECRCs through which changes in fuel oil prices and certain components of purchased energy costs are passed on to customers.
2The rate schedules of the electric utilities currently contain PPACs through which changes in purchased power expenses (except purchased energy costs) are passed on to customers.
3 kWh sales were lower when compared to the same periods in the prior year largely due to the effects of the COVID-19 pandemic. The enormous reduction to visitor arrivals due to the mandatory in-bound and inter-island travel quarantine has significantly impacted the tourism industry, led to record unemployment claims, and shuttered many businesses and hotels. As restrictions are lifted and visitors begin to arrive, sales are expected to slowly rebound but at lower levels than the prior year.

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The Utilities’ effective tax rate for the third quarters of 2020 and 2019 was 19% for both periods. The Utilities’ effective tax rates for the first nine months of 2020 and 2019 were at 19% and 20%, respectively. The effective tax rate was lower for the nine months ended September 30, 2020 compared to the same period in 2019 due primarily to higher 2020 amortization of the Utilities’ regulatory liability related to certain excess deferred income taxes resulting from the Tax Act’s decrease in federal income tax rate. The resulting benefit of lower tax expense is passed on to customers.
Hawaiian Electric’s consolidated ROACE was 8.4% and 7.6% for the twelve months ended September 30, 2020 and September 30, 2019, respectively.
The net book value (cost less accumulated depreciation) of utility property, plant and equipment (PPE) as of September 30, 2020 amounted to $4.7 billion, of which approximately 28% related to generation PPE, 64% related to transmission and distribution PPE, and 8% related to other PPE. Approximately 10% of the total net book value relates to generation PPE that has been deactivated or that the Utilities plan to deactivate or decommission. 
See “Economic conditions” in the “HEI Consolidated” section above.
Executive overview and strategy.  The Utilities provide electricity on all the principal islands in the state, other than Kauai, to approximately 95% of the state’s population and operate five separate grids. The Utilities’ mission is to provide innovative energy leadership for Hawaii, to meet the needs and expectations of customers and communities, and to empower them with affordable, reliable and clean energy. The goal is to create a modern, resilient, flexible and dynamic electric grid that enables an optimal mix of distributed energy resources, such as private rooftop solar, demand response and grid-scale resources to enable the creation of smart, sustainable, resilient communities and achieve the statutory goal of 100% renewable energy by 2045.
Transition to renewable energy.  The Utilities are fully committed to a 100 percent renewable energy future for Hawaii and are partnering with the State of Hawaii in achieving their Renewable Portfolio Standard goal of 100% renewable energy by 2045. Hawaii’s RPS law requires electric utilities to meet an RPS of 30%, 40%, 70% and 100% by December 31, 2020, 2030, 2040 and 2045, respectively.
The Utilities have made significant progress on the path to clean energy and have been successful in adding significant amounts of renewable energy resources to their electric systems and exceeded the 2015 RPS goal two years early. The Utilities’ RPS for 2019 was approximately 28% and the Utilities are on track to achieve the 2020 RPS goal of 30%. The Utilities will continue to actively procure additional renewable energy post-2020 and expect to meet or exceed the next statutory RPS goal of 40% in advance of the 2030 compliance year. (See “Developments in renewable energy efforts” below).
If the Utilities are not successful in meeting the RPS targets as mandated by law, the PUC could assess a penalty of $20 for every MWh that an electric utility is deficient. Based on the level of electricity sales in 2019, a 1% shortfall in meeting the 2020 RPS requirement of 30% would translate into a penalty of approximately $1.75 million. The PUC has the discretion to reduce the penalty due to events or circumstances that are outside an electric utility’s reasonable control, to the extent the event or circumstance could not be reasonably foreseen and ameliorated. In addition to penalties under the RPS law, failure to meet the mandated RPS targets would be expected to result in a higher proportion of fossil fuel-based generation than if the RPS target had been achieved, which in turn would be expected to subject Hawaiian Electric and Maui Electric to limited commodity fossil fuel price exposure under a fuel cost risk-sharing mechanism. Currently, the fuel cost risk-sharing mechanism apportions 2% of the fuel cost risk to the utilities (and 98% to ratepayers) and has a maximum exposure (or benefit) of $3.1 million.
The Utilities are fully aligned with, and supportive of, state policy to achieve a 100% renewable energy future and have made significant progress in its transformation. This alignment with state policy is reflected in management compensation programs and the Utilities’ long-range plans, which include aspirational targets in order to catalyze action and accelerate the transition away from fossil fuels at a pace more rapid than dictated by current law. The long-range plans, including aspirational targets, serve as guiding principles in the Utilities’ continued transformation, and are updated regularly to adapt to changing technology, costs and other factors. While there is no financial penalty for failure to achieve the Utilities’ long-range aspirational objectives, the Utilities recognize that there is an environmental and social cost from the continued use of fossil fuels.
The State of Hawaii’s policy is supported by the regulatory framework and includes a number of mechanisms designed to maintain the Utilities’ financial stability during the transition toward the State’s 100% renewable energy future. Under the sales decoupling mechanism, the Utilities are allowed to recover from customers, target test year revenues, independent of the level of kWh sales, which have generally declined (with the exception of 2019 and the first quarter of 2020), as privately-owned distributed energy resources have been added to the grid and energy efficiency measures have been put into place. Other regulatory mechanisms reduce regulatory lag, such as the rate adjustment mechanism to provide revenues for escalation in certain O&M expenses and rate base changes between rate cases, and the major project interim recovery mechanism, which allow the Utilities to recover and earn on certain approved major capital projects placed into service in between rate cases. See “Decoupling” in Note 3 of the Consolidated Financial Statements.
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Integrated Grid Planning. Achieving 100% renewable energy will require modernizing the grid through coordinated energy system planning in partnership with local communities and stakeholders. To accomplish this, the Utilities filed their Integrated Grid Planning (IGP) Report with the PUC on March 1, 2018, which provides an innovative systems approach to energy planning intended to yield the most cost-effective renewable energy pathways that incorporates customer and stakeholder input.
The PUC opened a docket to review the IGP process that the Utilities had proposed, and the resulting plans. In March 2019, the PUC accepted the Utilities’ IGP Work plan submitted on December 14, 2018, which describes the timing and scope of major activities that will occur in the IGP process. The IGP utilizes an inclusive and transparent Stakeholder Engagement model to provide an avenue for interested parties to engage with the Utilities and contribute meaningful input throughout the IGP process. The IGP Stakeholder Council, Technical Advisor Panel and Working groups have been established and meet regularly to provide feedback and input on specific issues and process steps in the IGP. In March 2020, the Utilities launched a broad public engagement program, which consisted of a combination of in-person and online engagement. This provided customers opportunities to connect with the IGP team.
Demand response programs. Pursuant to PUC orders, the Utilities are developing an integrated Demand Response (DR) Portfolio Plan that will enhance system operations and reduce costs to customers. The reduction in cost for the customer will take the form of either rates or incentive-based programs that will compensate customers for their participation individually, or by way of engagements with turnkey service providers that contract with the Utilities to aggregate and deliver various grid services on behalf of participating customers and their distributed assets.
In October 2017, the PUC approved the Utilities’ request made in December 2015 to defer and recover certain computer software and software development costs for a DR Management System in an amount not to exceed $3.9 million, exclusive of allowance for funds used during construction, through the Renewable Energy Infrastructure Program (REIP) Surcharge. The Utilities placed the DR Management System in service in the first quarter of 2019. On October 30, 2019, the Utilities filed the final cost report, reflecting total project costs of $3.7 million. On February 27, 2020, the PUC approved the Utilities’ request to recover deferred and other related costs of the DR Management System through the REIP Surcharge effective March 1, 2020 until such costs are included in determining base rates. On June 26, 2020, the Utilities submitted an updated REIP rate effective August 1, 2020 to the PUC.
On January 25, 2018, the PUC approved the Utilities’ revised DR Portfolio tariff structure. The PUC supported the approach of working with aggregators to implement the DR portfolio. In 2019, the Utilities signed a multi-year Grid Services Purchase Agreement (GSPA) with a third party aggregator. These contracts pay service providers to aggregate grid-supporting capabilities from customer-sited Distributed Energy Resources. The first of these five-year contracts has been executed (PUC approval obtained on August 9, 2019) and is expected to deliver not only benefits through efficient grid operations, but also avoided fuel costs over that 5-year period. The Utilities selected the next set of aggregators in the first quarter of 2020, commenced GSPA contract negotiations, and filed two executed contracts on July 9, 2020. This complements the Utilities’ transformation and supports customer choice.
Grid modernization. The overall goal of the Grid Modernization Strategy is to deploy modern grid investments at an appropriate priority, sequence and pace to cost-effectively maximize flexibility, minimize the risk of redundancy and obsolescence, deliver customer benefits and enable greater DER and renewable energy integration. Under the Grid Modernization Strategy, the Utilities expects that new technology will help increase adoption of private rooftop solar and make use of rapidly evolving products, including storage and advanced inverters. The Utilities have begun work to implement the Grid Modernization Strategy Phase 1, which received PUC approval on March 25, 2019. The estimated cost for this initial phase is approximately $86 million and is expected to be incurred over five years. As of September 30, 2020, approximately $13.5 million has been incurred to date under Phase 1. The Utilities submitted a proportional advanced meter opt-out deployment filing on September 30, 2020 in an effort toward broader and faster deployment.
The Utilities filed an application with the PUC on September 30, 2019 for an Advanced Distribution Management System (ADMS) as part of the second phase of their Grid Modernization Strategy implementation. The estimated cost for the implementation over five years of the Advanced Distribution Management System, which includes capital, deferred and O&M costs, is $46 million. However, on December 30, 2019, the PUC suspended the Utilities’ application for the Advanced Distribution Management System pending the Utilities’ filing of a supplemental application for the broad deployment of field devices. This Phase 2 field devices application will be filed at the end of first quarter of 2021, at which time the ADMS filing could be resumed and unsuspended.
The Utilities acquired spectrum licenses in the Federal Communications Commission Citizens Broadband Radio Service Auction which concluded in August. The licenses represent the first step in facilitating the development of a Private LTE (PLTE) communications network that provides another option for the growing demand of connectivity to all parts of the electric grid in order to better serve our customers, and facilitate Grid Modernization and our renewable goals. Use cases for an PLTE
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network include backhaul for advanced metering infrastructure, switches, monitoring devices, falling conductor protection systems, surveillance equipment, mobile radios, and supervisory control and data acquisition systems. With respect to the Grid Modernization strategy, PLTE provides optionality to ubiquitously connect devices that are in less densely congregated service areas and/or not accessible with existing telecommunications infrastructure.
Community-based renewable energy. In December 2017, the PUC adopted a community-based renewable energy (CBRE) program framework which allows customers who cannot, or chose not to, take advantage of private rooftop solar to receive the benefits of renewable energy to help offset their monthly electric bills and support clean energy for Hawaii. The program has two phases.
The first phase, which commenced in July 2018, totals 8 MW of solar photovoltaic (PV) only with one credit rate for each island, closed on April 9, 2020.
By PUC order, CBRE Phase 2 commenced on April 9, 2020 with the goal to develop a robust CBRE market with competitive pricing anticipating that clean energy projects and programs, such as CBRE, can meaningfully contribute to the State’s recovery from the COVID-19 emergency. CBRE Phase 2 capacity is substantially larger than Phase 1 and allows up to 235 MW across all Hawaiian Electric service territories in two tranches. The capacities are allocated by island and allow for small (under 250 kW) and large system sizes to encourage a variety of system sizes. In addition to the first-come, first-served process offered in Phase 1, the majority of the 235 MW will be awarded to projects selected through a competitive process. To provide opportunities for low- to moderate-income (LMI) customers to participate in the program, separate project proposals may be submitted specifically targeting LMI customers.
Eight RFPs were required by order: one each for Oahu, Maui, Hawaii Island, Molokai, and Lanai, and LMI-specific RFPs for Oahu, Maui, and Hawaii Island. Draft RFPs for the three LMI RFPs and the RFPs for Molokai, and Lanai were filed on July 9, 2020, along with a revised tariff and associated contract models. LMI projects do not have a size cap nor do they decrease the 235 MW capacity available to other projects. In addition to its administrative role, the Utilities and their affiliates are eligible to participate in the solicitations, with the exception of the LMI-specific RFPs, where the PUC will only consider a utility self-build option if there are no successful competitive bids for an LMI project on one island or more. The Utilities will also have opportunities to earn based on shared savings mechanisms for specific solicitations. Comments were received during and after a Technical Conference hosted by the PUC on July 28, 2020. Proposed final drafts of the RFPs, tariff, and contracts were filed on September 8, 2020. Depending on the timing of PUC approval, the Utilities may issue these RFPs before the end of the year.
For Lanai, the Utilities proposed to combine the previously issued Variable Renewable Dispatchable Generation Paired with Energy Storage RFP and the CBRE RFP to optimize the benefits of procuring renewable energy, spurring development and increasing the likelihood of success of the CBRE Program on Lanai. As proposed, the Lanai CBRE RFP allows the Utilities to continue collaborating with the majority landowner, Pulama Lanai, who has designated a new larger predetermined site to facilitate expeditious development of a renewable energy project that meets the objectives of both RFPs, while reducing the cost of a project by leveraging economies of scale and coordinating interconnection to the grid.
Drafts of the remaining RFPs on Oahu, Maui, and Hawaii Island were filed on October 9, 2020. A technical conference was held on October 28, 2020 and proposed final drafts are due on December 1, 2020. Pending PUC approval, the Utilities anticipate issuing these RFPs during the first quarter of 2021.
For small CBRE projects less than 250 kW in size, the Utilities are planning to accept projects over a four-month period on a first-come, first served basis as soon as the PUC approves the Utilities’ final tariff and contracts, filed on September 8, 2020. The PUC reserved 30 MW as well as a small amount of unallocated capacity from Phase 1 for small projects in Phase 2 on Oahu, Maui and Hawaii Island. If applications exceed the program capacity for that island, then a reverse auction process called Competitive Credit Rate Procurement will be triggered to allocate project capacity and determine the credit rate. The Utilities have developed a CBRE Portal where customers can subscribe to a project once the Subscriber Organization has added their project to the portal.
Microgrid services tariff proceeding. In July 2018, the PUC originally issued an order instituting a proceeding to investigate establishment of a microgrid services tariff, pursuant to Act 200 of 2018. The PUC granted motions to intervene in the docket by eight parties (there are currently four parties) and completed its initial procedural schedule in March 2019. In August 2019, the PUC issued an order stating that the focus for the remainder of the docket is to facilitate the ability of microgrids to disconnect from the grid and provide backup power to customers and critical energy uses during contingency events.
The PUC also required the parties to form two Working Groups: (1) a Market Facilitation Working Group to recommend draft tariff language for the Microgrid Services Tariff; and (2) an Interconnection Standards Working Group to develop a new section of Rule 14H specific to interconnection and islanding/reconnection of microgrids. The Utilities filed a Draft Microgrid
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Services Tariff and updated language for various DER Rules on March 30, 2020. Parties to the docket filed comments on and proposed revisions to the Draft Tariff on April 27, 2020.
Decoupling. See "Decoupling" in Note 3 of the Condensed Consolidated Financial Statements for a discussion of decoupling.
As part of decoupling, the Utilities also track their rate-making ROACEs as calculated under the earnings sharing mechanism, which includes only items considered in establishing rates. At year-end, each utility’s rate-making ROACE is compared against its ROACE allowed by the PUC to determine whether earnings sharing has been triggered. Annual earnings of a utility over and above the ROACE allowed by the PUC are shared between the utility and its ratepayers on a tiered basis. Earnings sharing credits are included in the annual decoupling filing for the following year. Results for 2019, 2018 and 2017 did not trigger the earnings sharing mechanism for the Utilities.
Regulated returns. Actual and PUC-allowed returns, as of September 30, 2020, were as follows:
%Rate-making Return on rate base (RORB)*ROACE**Rate-making ROACE***
Twelve months ended 
September 30, 2020
Hawaiian ElectricHawaii Electric LightMaui ElectricHawaiian ElectricHawaii Electric LightMaui ElectricHawaiian ElectricHawaii Electric LightMaui Electric
Utility returns7.10 7.18 6.58 8.44 8.84 7.76 9.25 9.14 8.53 
PUC-allowed returns7.57 7.52 7.43 9.50 9.50 9.50 9.50 9.50 9.50 
Difference(0.47)(0.34)(0.85)(1.06)(0.66)(1.74)(0.25)(0.36)(0.97)
*      Based on recorded operating income and average rate base, both adjusted for items not included in determining electric rates.
**    Recorded net income divided by average common equity.
***  ROACE adjusted to remove items not included by the PUC in establishing rates, such as incentive compensation.
The gap between PUC-allowed ROACEs and the ROACEs actually achieved is primarily due to: the consistent exclusion of certain expenses from rates (for example, incentive compensation and charitable contributions), the recognition of annual RAM revenues on June 1 annually rather than on January 1, and O&M increases and return on capital additions since the last rate case in excess of indexed escalations.
Most recent rate proceedings.  As of September 30, 2020, the status of ongoing rate case for each utility was as follows:
Test year
(dollars in millions)		DateAmount% over 
rates in 
effect		ROACE
(%)		RORB
(%)		Rate
 base		Common
equity
%		Stipulated agreement 
reached with
Consumer Advocate
Hawaiian Electric        
2020 1
Request8/21/19$77.6 4.1 10.50 7.97 $2,477 57.15 Yes
Final Decision and Order10/22/200.00.09.507.37NA57.15
Hawaii Electric Light        
2019 2
Request 12/14/18$13.4 3.4 10.50 8.30 $537 56.91 Yes
Interim Decision and Order11/13/190.00.09.507.5253456.83
Final Decision and Order7/28/200.00.09.507.5253456.83
 Note:  The “Request” date reflects the application filing date for the rate proceeding. The date of “Interim Decision and Order” or “Final Decision and Order” reflects the issuance date of the PUC order.
1 A final D&O issued on October 22, 2020 ordered final rates for the 2020 test year to remain at current effective rates, which provides for no increase to base rates. Hawaiian Electric is required to file revised tariff sheets within fifteen days of this final D&O. The effective date of the final tariffs is subject to PUC approval.
2 A final D&O issued on July 28, 2020 ordered final rates for the 2019 test year to remain at current effective rates, such that there is a zero increase in rates. The proposed final tariffs and PIM tariffs took effect on November 1, 2020, and the ECRC tariff will take effect on January 1, 2021.
See also “Most recent rate proceedings” in Note 3 of the Condensed Consolidated Financial Statements.
Performance-based regulation.  See “Performance incentive mechanisms” and “Performance-based regulation proceeding” in Note 3 of the Condensed Consolidated Financial Statements.
Developments in renewable energy efforts.  Developments in the Utilities’ efforts to further their renewable energy strategy include renewable energy projects discussed in Note 3 of the Condensed Consolidated Financial Statements and the following:
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New renewable PPAs.
•In December 2014, the PUC approved a PPA for Renewable As-Available Energy dated October 3, 2013 between Hawaiian Electric and Na Pua Makani Power Partners, LLC (NPM) for a proposed 24-MW wind farm on Oahu. In August 2020, the project was energized and commissioning of all wind turbines was completed. However, the project was paused due to a conductor deficiency. Reconductoring work is in progress and the Utilities are evaluating if further testing can continue.
NPM received its Incidental Take Permit from the Department of Fish and Wildlife Service on September 7, 2018. Keep the North Shore Country (KNSC) has appealed this decision and the case has been transferred to the Hawaii Supreme Court. On June 17, 2020, KNSC filed a Motion for Stay Upon Appeal. On August 10, 2020, KNSC’s Motion for Stay Upon Appeal was denied. KNSC and Kahuku Community Association (KCA) have also petitioned to appeal NPM’s Conditional Use Permits. On August 6, 2020, the Zoning Board of Appeals (ZBA) granted NPM’s Motions to Dismiss the Appeal Petitions of KNSC and KCA.
Life of the Land (LOL) filed a Motion for Relief to argue the PUC’s approval for NPM PPA was invalid and should be revised. Hawaiian Electric and the Consumer Advocate filed an opposition to this motion for relief. A hearing on the motion for relief was held on November 22, 2019. On April 16, 2020, the PUC issued an order denying LOL’s Motion for Relief. On April 27, 2020, LOL filed a Notice of Appeal of the PUC’s order with the Supreme Court of the State of Hawaii. The parties are presently briefing the matter before the Supreme Court, but the Court has yet to set a date for oral arguments.
•On December 31, 2019, Hawaii Electric Light and PGV entered into an Amended and Restated Power Purchase Agreement (ARPPA), subject to approval by the PUC. The ARPPA extends the term of the existing PPA by 25 years to 2052, expands the firm capacity of the facility to 46 MW and delinks the pricing for energy delivered from the facility from fossil fuel prices to reduce cost to customers. The existing PPA (except for lower-tiered pricing for certain energy dispatched above 30 MW) will remain in effect until it is superseded by the ARPPA when the expanded capacity is in commercial operation.
Tariffed renewable resources.
•As of September 30, 2020, there were approximately 504MW, 108 MW and 122 MW of installed distributed renewable energy technologies (mainly PV) at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively, for tariff-based private customer generation programs, namely Standard Interconnection Agreement, Net Energy Metering, Net Energy Metering Plus, Customer Grid Supply, Customer Self Supply, Customer Grid Supply Plus and Interim Smart Export. As of September 30, 2020, an estimated 30% of single family homes on the islands of Oahu, Hawaii and Maui have installed private rooftop solar systems, and approximately 19% of the Utilities’ total customers have solar systems.   
•The Utilities began accepting energy from feed-in tariff projects in 2011. As of September 30, 2020, there were 40 MW, 2 MW and 5 MW of installed feed-in tariff capacity from renewable energy technologies at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively.
Biofuel sources.
•In July 2018, the PUC approved Hawaiian Electric’s 3-year biodiesel supply contract with Pacific Biodiesel Technologies, LLC (PBT) to supply 2 million to 4 million gallons of biodiesel at Hawaiian Electric’s Schofield Generating Station and the Honolulu International Airport Emergency Power Facility (HIA Facility) and any other generating unit on Oahu, as necessary. The PBT contract became effective on November 1, 2018. Hawaiian Electric also has a spot buy contract with PBT to purchase additional quantities of biodiesel at or below the price of diesel. Some purchases of “at parity” biodiesel have been made under the spot purchase contract, which was extended through June 2022.
•Hawaiian Electric has a contingency supply contract with REG Marketing & Logistics Group, LLC to also supply biodiesel to any generating unit on Oahu in the event PBT is not able to supply necessary quantities. This contingency contract has been extended to November 2021, and will continue with no volume purchase requirements.
Requests for renewable proposals, expressions of interest, and information.
•Under a request for proposal process governed by the PUC and monitored by independent observers, in February 2018, the Utilities issued RFPs for 220 MW of renewable generation on Oahu, 50 MW of renewable generation on
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Hawaii Island, and 60 MW of renewable generation on Maui. The Utilities selected a final award group for Hawaii Island in August 2018 and for Maui and Oahu in September 2018.
In December 2018, the Utilities executed a total of seven renewable generation PPAs utilizing photovoltaic technology paired with a battery storage system for a total of 262 MW, of which six PPAs were approved by the PUC in March 2019 and one PPA for Maui Electric was approved on October 5, 2020. In February 2019, Hawaiian Electric filed an additional PPA for a proposed 12.5 MW PV plus battery storage project, which was approved by the PUC on August 20, 2019. Summarized information for a total of 8 PPAs, including the one most recently approved for Maui Electric, is as follows:
UtilitiesNumber of contractsTotal photovoltaic size (MW)BESS Size (MW/MWh)Guaranteed commercial operation datesContract term (years)Total projected annual payment (in millions)
Hawaiian Electric4139.5139.5/5589/30/21 & 12/31/2120 & 25$30.9 
Hawaii Electric Light26060/2407/20/21 & 6/30/222514.1 
Maui Electric27575/3007/20/21 & 6/30/222517.6 
Total8274.5274.5/1,098$62.6 
In March 2019 and August 2019, the Utilities received PUC approval to recover the total projected annual payment of $57.8 million for 7 PPAs through the PPAC to the extent such costs are not included in base rates. The remaining $4.8 million of total projected annual payments for the remaining PPA was approved on October 5, 2020.
•In continuation of its February 2018 request for proposal process, the Utilities issued its Stage 2 Renewable RFPs for Oahu, Maui and Hawaii Island and Grid Services RFP on August 22, 2019. This procurement plan sought approximately 900 MW of renewable energy, including 594 MW on Oahu, 135 MW on Maui and a range between 32 to 203 MW on Hawaii Island. This second phase, as approved by the PUC, was open to all renewable and storage resources, including efforts to add more renewable generation, renewable plus storage, standalone storage and grid services. The scope of these RFPs has been expanded to accelerate renewable energy procurement beyond the remainder of the 2022 targets identified in Stage 1 to include the energy requirement associated with the planned retirement of the Kahului Power Plant on Maui and the upcoming expiration of the agreement for the AES Hawaii facility on Oahu. For the Grid Services RFP, the targets had been expanded in alignment with the Renewable RFPs Utility proposals were submitted on November 4, 2019. Proposals from third parties for these RFPs were submitted on November 5, 2019. Final awards for the renewable projects were made on May 8, 2020. Final awards for the grid services projects were made starting in January 2020. On Oahu, seven solar-plus-storage projects and one standalone storage project totaling approximately 281 MW of generation and 1.8 GWh of storage advanced were selected. On Maui Island, three solar-plus-storage projects and one standalone storage project totaling approximately 100 MW of generation and 560 MWh of storage were selected. On Hawaii Island, two solar-plus-storage projects and one standalone storage project totaling approximately 72 MW of generation and 492 MWh of storage were selected. Two Utility Self-Build projects were among those selected; a 40-MW, 160-MWh standalone energy storage system on Maui and a 12-MW, 12-MWh storage system on Hawaii Island. Since selection, four renewable plus storage projects have voluntarily withdrawn from the process from the process for various reasons, including change in circumstances for the developer and a misunderstanding of contract requirements. To date, the Utilities have filed 8 PPAs, 2 grid services purchase agreements (GSPA) and 2 applications for commitments of funds for capital expenditures for approval of the utility self-build projects with the PUC. Contract negotiations continue for the remaining projects.
A summary of the 8 PPAs that were filed with the PUC, is as follows:
UtilitiesNumber of contractsTotal photovoltaic size (MW)BESS Size (MW/MWh)Guaranteed commercial operation datesContract term (years)Total projected annual payment (in millions)
Hawaiian Electric5232232/1,0555/31/2022, 5/17/2023, 10/30/2023, 12/29/2023 & 12/31/202320 & 25$62.0 
Hawaiian Electric1N/A185/56506/01/20222024.0 
Maui Electric26060/2404/30/2023 & 12/29/20232516.7 
Total8292477/1,860$102.7 

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A summary of the GSPAs that were filed with the PUC is as follows:
UtilitiesFast Frequency Response - 1
(MW)		Fast Frequency Response - 2
(MW)		Capacity -
Load Build
(MW)		Capacity -
Load Reduction
(MW)
Hawaiian Electric—26.714.519.4
Hawaii Electric Light6.0—3.24.0
Maui Electric6.1—1.94.7
Total12.126.719.628.1

A summary of the utility self-build projects that were filed with the PUC is as follows:
UtilitiesNumber of contractsBESS Size (MW/MWh)Guaranteed commercial operation dates
Hawaii Electric Light112/1212/30/2022
Maui Electric140/1604/28/2023
Total252/172

•On November 27, 2019, the Utilities issued RFPs for renewable generation paired with energy storage on the islands of Lanai and Molokai. Projects may come online as early as 2023. The Utilities are seeking PV paired with storage or small wind (specified as 100 kW turbines or smaller) on Molokai and PV paired with storage on Lanai. Proposals for the Molokai RFP were received on February 14, 2020. The Lanai RFP was temporarily postponed, while the Utilities reevaluated the system needs. The Utilities filed an update to the Lanai RFP on March 10, 2020. In light of a PUC order issued on April 9, 2020 in the CBRE docket, the Utilities proposed in their July 9, 2020 filing to combine the previously issued Lanai RFP with the CBRE RFP described in the order to optimize the benefits of procuring renewable energy, spurring development and increasing the likelihood of success of the CBRE program on Lanai. On October 15, 2020, the Utilities selected one project from the Molokai RFP for a total of 4.5 MW of solar and 24 MWh of storage. The developer, however, declined to accept the award. The Utilities are currently evaluating next steps.
Legislation and regulation. Congress and the Hawaii legislature periodically consider legislation that could have positive or negative effects on the Utilities and their customers. Also see “Environmental regulation” in Note 3 of the Condensed Consolidated Financial Statements.
Fuel contracts. The fuel contract entered into in January 2019, by the Utilities and PAR Hawaii Refining, LLC (PAR Hawaii), for the Utilities’ low sulfur fuel oil (LSFO), high sulfur fuel oil (HSFO), No. 2 diesel, and ultra-low sulfur diesel (ULSD) requirements was approved by the PUC, and became effective on April 28, 2019 and terminates on December 31, 2022. This contract is a requirement contract with no minimum purchases. If PAR is unable to provide LSFO, HSFO, diesel and/or ULSD the contract allows the Utilities to purchase LSFO, HSFO, diesel and/or ULSD from another supplier. The contract will automatically renew upon the conclusion of the original term for successive terms of 1 year beginning on January 1, 2023 unless a party gives written termination notice at least 120 days before the beginning of an extension. The costs incurred under the contract with PAR Hawaii are recovered in the Utilities’ respective ECRCs.
On June 9, 2020, the Utilities and Par Hawaii entered into a First Amendment to the fuel contract. The First Amendment amends only the pricing to create a two-tiered structure based on volume, with all tier-1 LSFO up to the tier-1 maximum to be purchased exclusively from PAR at the established pricing, and purchases in excess of that volume (tier-2) either from PAR at the established pricing, or from an alternative supplier. On August 4, 2020, the PUC approved the First Amendment, which has an effective date of July 15, 2020, on an interim basis. The PUC’s approval order allows the recovery of such costs associated with the First Amendment through the ECRC to the extent that the costs are not recovered in base rates. The PUC intends to review whether the First Amendment is reasonable and in the public interest in the final decision, but it will not subject the recovery of the costs between the interim decision and the final decision to retroactive disallowances.
Army privatization. On October 30, 2020, the PUC approved Hawaiian Electric’s 50-year contract with the U.S. Army to own, operate and maintain the electric distribution system serving the U.S. Army’s 12 installations on Oahu, including Schofield Barracks, Wheeler Army Airfield, Tripler Army Medical Center, Fort Shafter, and Army housing areas. Hawaiian Electric will acquire the Army’s existing distribution system for a purchase price of $16.3 million and will pay the Army in the form of a monthly credit against the monthly utility services charge over the 50-year term of the contract.
Hawaiian Electric will take ownership and all responsibilities for operation and maintenance of the system in late 2021 for a 50-year term after a one-year transition period. Under the contract, Hawaiian Electric will make initial capital upgrades over
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the first six years of the contract and replacements of aging infrastructure over the 50-year term. In addition to its regular monthly electricity bill, the Army will pay Hawaiian Electric a monthly utility services charge to cover operations and maintenance expenses and provide recovery for capital upgrades, capital replacements, and the existing distribution system based on a rate of return determined by the PUC for regulated utility investments, as well as depreciation expense. A preliminary assessment estimated the capital needs of approximately $40 million in the first six years of the contract. The PUC requires Hawaiian Electric to file regular periodic reports on the activities and investments in fulfillment of the contract and will review the major projects planned on behalf of the Army. The annual impact on Hawaiian Electric’s earnings is not expected to be material and will depend on a number of factors, including the amount and timing of capital upgrades and capital
replacement.
FINANCIAL CONDITION
Liquidity and capital resources. In response to the COVID-19 pandemic, many countries, states, and cities have imposed strict social distancing measures that have had a significant impact on global economic activity. As a result, the capital markets, including the commercial paper markets, have experienced high levels of volatility, and in some cases, disruption. However, in March 2020, the Commercial Paper Funding Facility was announced by the Federal Reserve Board, and the program was launched in April 2020. As a result, commercial paper rates began to decrease and returned to levels that existed before the start of the COVID-19 pandemic. As a result, there was a significant increase in liquidity in the commercial paper market as many companies found other sources of liquidity; however, Hawaiian Electric has not needed to access the commercial paper market since closing on its private placement transaction in May 2020 (see Note 5 of Condensed Consolidated Financial Statements). As of September 30, 2020, there were no amounts outstanding on Hawaiian Electric’s revolving credit facilities.
To preserve and enhance the Utilities’ liquidity position, given the significant and ongoing uncertainty regarding the potential scale and duration of the COVID-19 pandemic, the Utilities have taken a number of steps. First, on April 20, 2020, Hawaiian Electric added an incremental $75 million in committed revolving credit capacity with a 364-day revolving credit facility (see Note 5 of the Condensed Consolidated Financial Statements). The Utilities also issued $160 million of notes through a private placement of taxable debt in May 2020, the proceeds of which were used to finance capital expenditures, repay short-term debt used to finance or refinance capital expenditures and/or reimburse funds for payment of capital expenditures. Secondly, $50 million of an existing 364-day term loan was refinanced with a new $50 million term loan maturing in April 2021. In addition, the Utilities executed a $115 million private placement of taxable debt on October 29, 2020, to finance their capital expenditures and/or to reimburse funds used for the payment of capital expenditures. The private placement has a delayed draw feature, which allows the Utilities to draw the funds at any time on or before January 15, 2021. As of September 30, 2020, the total amount of available borrowing capacity under the Utilities’ committed lines of credit was $275 million. The Utilities had $14 million of long-term debt that was paid off when it matured on July 1, 2020.
In addition to the foregoing financing transactions, in order to further enhance the Utilities’ liquidity position, the Utilities are deferring, pursuant to section 2302 of the CARES Act, the payment of the applicable employer portion of Old-Age, Survivors and Disability Insurance payroll tax deposits that are due in 2020, but arose subsequent to the enactment of the CARES Act, which is estimated to be approximately $10 million. Fifty percent of the deferred payroll taxes will be paid in each of December 2021 and December 2022. Starting in the second quarter of 2020, the Utilities also deferred approximately $5.7 million per month in planned monthly pension contributions to further strengthen is liquidity position. These deferred contributions were paid in September 2020. If further liquidity is necessary, the Utilities could also reduce the pace of capital spending related to non-essential projects.
The Utilities believe that their ability to generate cash, both internally from operations and externally from issuances of equity and debt securities, as well as bank borrowings, is adequate to maintain sufficient liquidity to fund their contractual obligations and commercial commitments, their forecasted capital expenditures and investments, their expected retirement benefit plan contributions and other cash requirements. However, the COVID-19 pandemic is a rapidly evolving situation, and the Utilities cannot predict the extent or duration of the outbreak, the future effects that it will have on the global, national or local economy, including the impacts on the Utilities’ ability, as well as the cost, to access additional capital, or the future impacts on the Utilities’ financial position, results of operations, and cash flows. See Item 1A. “Risk Factors” in Part II for further discussion of risks and uncertainties.
Hawaiian Electric’s consolidated capital structure was as follows:
(dollars in millions)September 30, 2020December 31, 2019
Short-term borrowings$50 1 %$89 2 %
Long-term debt, net1,561 42 1,498 41 
Preferred stock34 1 34 1 
Common stock equity2,093 56 2,047 56 
$3,738 100 %$3,668 100 %
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Information about Hawaiian Electric’s commercial paper borrowings, borrowings from HEI and line of credit facility were as follows:
 Average balanceBalance
(in millions)Nine months ended September 30, 2020September 30, 2020December 31, 2019
Short-term borrowings 1
   
Commercial paper$24 $— $39 
Borrowings from HEI— — — 
Line of credit draws21 — — 
Undrawn capacity under line of credit facilities— 275 200 
 
1   The maximum amount of external short-term borrowings by Hawaiian Electric during the first nine months of 2020 was approximately $210 million. As of September 30, 2020, Hawaii Electric Light and Maui Electric had short-term borrowings from Hawaiian Electric of $26.5 million and $2 million, respectively, which intercompany borrowings are eliminated in consolidation. In addition to the short-term borrowings above, on May 19, 2020, Hawaiian Electric paid off and terminated the $100 million term loan facility dated as of December 23, 2019 and entered into a 364-day, $50 million term loan facility as of May 19, 2020. Hawaiian Electric drew the full $50 million on May 19, 2020.
Hawaiian Electric has a $200 million line of credit facility and a $75 million 364-day revolving credit facility with no amounts outstanding at September 30, 2020. See Note 5 of the Condensed Consolidated Financial Statements.
SPRBs. Special purpose revenue bonds (SPRBs) have been issued by the Department of Budget and Finance of the State of Hawaii (DBF) to finance (and refinance) capital improvement projects of Hawaiian Electric and its subsidiaries, but the sources of their repayment are the non-collateralized obligations of Hawaiian Electric and its subsidiaries under loan agreements and notes issued to the DBF, including Hawaiian Electric’s guarantees of its subsidiaries’ obligations.
On May 24, 2019, the PUC approved the Utilities’ request to issue SPRBs in the amounts of up to $70 million, $2.5 million and $7.5 million for Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively, prior to June 30, 2020, to finance the Utilities’ capital improvement programs. Pursuant to this approval, on October 10, 2019, the DBF issued, at par, Series 2019 SPRBs in the aggregate principal amount of $80 million with a maturity of October 1, 2049. As of September 30, 2020, Hawaiian Electric had $20 million of undrawn funds remaining with the trustee. Hawaii Electric Light and Maui Electric had no undrawn funds as of September 30, 2020.
On June 10, 2019, the Hawaii legislature authorized the issuance of up to $700 million of SPRBs ($400 million for Hawaiian Electric, $150 million for Hawaii Electric Light and $150 million for Maui Electric), with PUC approval, prior to June 30, 2024, to finance the Utilities’ multi-project capital improvement programs (2019 Legislative Authorization).
On May 4, 2020, the Utilities requested PUC approval to issue up to $700 million of SPRBs (under the 2019 Legislative Authorization) in the amounts of up to $400 million, $150 million and $150 million for Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively, prior to June 30, 2024 to finance the Utilities’ multi-project capital improvement programs.
Bank loans. On May 19, 2020, Hawaiian Electric paid off and terminated the $100 million term loan credit agreement dated as of December 23, 2019. In addition, Hawaiian Electric entered into a 364-day, $50 million term loan credit agreement that matures on April 19, 2021. Hawaiian Electric drew the full $50 million on May 19, 2020.
Taxable debt. On January 31, 2019, the Utilities received PUC approval (January 2019 Approval) to issue the remaining authorized amounts under the PUC approval received in April 2018 (April 2018 Approval) in 2019 through 2020 (Hawaiian Electric up to $205 million and Hawaii Electric Light up to $15 million of taxable debt), as well as a supplemental increase to authorize the issuance of additional taxable debt to finance capital expenditures, repay long-term and/or short term debt used to finance or refinance capital expenditures, and/or to reimburse funds used for payment of capital expenditures, and to refinance the Utilities’ 2004 junior subordinated deferrable interest debentures (QUIDS) prior to maturity. In addition, the January 2019 Approval authorized the Utilities to extend the period to issue additional taxable debt from December 31, 2021 to December 31, 2022. The new total “up to” amounts of taxable debt requested to be issued through December 31, 2022 are $410 million, $150 million and $130 million for Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively.
Pursuant to this approval, on May 14, 2020, the Utilities issued through a private placement, $160 million of unsecured senior notes bearing taxable interest ($110 million for Hawaiian Electric, $10 million for Hawaii Electric Light and $40 million for Maui Electric) to finance their capital expenditures and/or to reimburse funds used for the payment of capital expenditures. See Note 5 of the Condensed Consolidated Financial Statements.
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On September 30, 2020, the Utilities received PUC approval to issue, prior to December 31, 2021, $115 million of unsecured senior notes bearing taxable interest (Hawaiian Electric up to $60 million, Hawaii Electric Light up to $30 million and Maui Electric up to $25 million) to finance capital expenditures, repay long-term and/or short term debt used to finance or refinance capital expenditures, and/or to reimburse funds used for payment of capital expenditures.
Pursuant to this approval, on October 29, 2020, the Utilities executed through a private placement, $115 million of unsecured senior notes bearing taxable interest ($60 million for Hawaiian Electric, $30 million for Hawaii Electric Light and $25 million for Maui Electric) to finance their capital expenditures and/or to reimburse funds used for the payment of capital expenditures. The private placement has a delayed draw feature, which allows the Utilities to draw the funds at any time on or before January 15, 2021. See Note 5 of the Condensed Consolidated Financial Statements.
As of October 29, 2020, Hawaiian Electric, Hawaii Electric Light, and Maui Electric have $135 million, $85 million, and $45 million, respectively, of remaining taxable debt to issue prior to December 31, 2022. See summary table below.
(in millions)Hawaiian ElectricHawaii Electric LightMaui Electric
Total “up to” amounts of taxable debt authorized through 2022$410 $150 $130 
Less:
Taxable debt authorized and issued in 2018 under April 2018 Approval75 15 10 
Taxable debt issuance to refinance the 2004 QUIDS in 201930 10 10 
Taxable debt issuance in May 2020110 10 40 
Taxable debt executed in October 2020, but to be issued on or before January 15, 202160 30 25 
Remaining authorized amounts $135 $85 $45 

Equity. In October 2018, the Utilities received PUC approval for the supplemental increase to issue and sell additional common stock in the amounts of up to $280 million for Hawaiian Electric and up to $100 million each for Hawaii Electric Light and Maui Electric, with the new total “up to” amounts of $430 million for Hawaiian Electric and $110 million each for Hawaii Electric Light and Maui Electric, and to extend the period authorized by the PUC to issue and sell common stock from December 31, 2021 to December 31, 2022. As of September 30, 2020, Hawaiian Electric, Hawaii Electric Light, and Maui Electric have $309.8 million, $110 million, and $98.8, respectively, of remaining common stock to issue prior to December 31, 2022. See summary table below.
(in millions)Hawaiian ElectricHawaii Electric LightMaui Electric
Total “up to” amounts of common stock authorized to issue and sell through 2021$150.0 $10.0 $10.0 
Supplemental increase authorized280.0 100.0 100.0 
Total “up to” amounts of common stock authorized to issue and sell through 2022430.0 110.0 110.0 
Common stock authorized and issued in 2017, 2018 and 2019120.2 — 11.2 
Remaining authorized amounts $309.8 $110.0 $98.8 

Cash flows. The following table reflects the changes in cash flows for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019:
Nine months ended September 30
(in thousands)20202019Change
Net cash provided by operating activities$244,955 $282,618 $(37,663)
Net cash used in investing activities(260,187)(295,145)34,958 
Net cash provided by financing activities23,596 9,157 14,439 

Net cash provided by operating activities. The decrease in net cash provided by operating activities was primarily driven by lower cash from a decrease in accounts payable due to timing, and lower cash receipts from customers due to lower customer bills as a result of lower fuel oil prices.
Net cash used in investing activities. The decrease in net cash used in investing activities was primarily driven by a decrease in capital expenditures related to construction activities.
Net cash provided by financing activities. The increase in net cash provided by financing activities was primarily driven by higher net cash proceeds from long-term borrowings.
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Forecast capital expenditures. The Utilities continuously monitor the impact of COVID-19, and for the three-year period 2021 through 2023, the Utilities forecast up to $1.3 billion of net capital expenditures, which could change over time based upon external factors such as the timing and scope of environmental regulations, unforeseen delays in permitting and timing of PUC decisions. Proceeds from the issuance of equity and long-term debt, cash flows from operating activities, temporary increases in short-term borrowings and existing cash and cash equivalents are expected to provide the funds needed for the net capital expenditures, to pay down commercial paper or other short-term borrowings, as well as to fund any unanticipated expenditures not included in the 2020 to 2022 forecast (such as increases in the costs or acceleration of capital projects, or unanticipated capital expenditures that may be required by new environmental laws and regulations).
Management periodically reviews capital expenditure estimates and the timing of construction projects. These estimates may change significantly as a result of many considerations, including changes in economic conditions, changes in forecasts of kWh sales and peak load, the availability of purchased power and changes in expectations concerning the construction and ownership of future generation units, the availability of generating sites and transmission and distribution corridors, the need for fuel infrastructure investments, the ability to obtain adequate and timely rate increases, escalation in construction costs, the effects of opposition to proposed construction projects and requirements of environmental and other regulatory and permitting authorities.
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Bank
Recent Developments—COVID-19
See also Recent developments—COVID-19 in HEI’s MD&A.
ASB continues to be impacted by the economic slowdown caused by COVID-19, including significant disruption to the global financial markets and impacts to the capital markets, which has resulted in lower interest rates across the curve. The bank’s net interest margin of 3.12% for the quarter ended September 30, 2020 was 9 basis points lower than the net interest margin for the prior quarter and 70 basis points lower than the net interest margin for the same period last year. The lower interest rate environment will continue to have a negative impact on ASB’s net interest income and net interest margin in future quarters and could have an impact on the inputs and assumptions used in significant accounting estimates, such as assessing goodwill and long-lived assets for impairment. ASB’s funding of short-term loans at a fixed rate of 1% under the Paycheck Protection Program (PPP) had reduced net interest margin modestly, but the income impact was partially offset by the receipt of processing fees under the program.
The state and local responses to the COVID-19 pandemic included a statewide stay-at-home order and a mandatory 14-day self-quarantine for any person traveling to Hawaii, which had a severe adverse economic impact to businesses and residents. Although many businesses have begun to reopen on a modified basis in compliance with applicable government orders, the mandatory 14-day self-quarantine order for travelers that have not provided a negative pre-arrival COVID-19 test result will continue to impact the tourism industry and the unemployment rate in the state of Hawaii.
ASB’s provision for credit losses increased due to forecasted credit deterioration as a result of the COVID-19 pandemic. For the three months ended September 30, 2020, the provision for credit losses was $14.0 million, compared to $3.3 million for the three months ended September 30, 2019. In response to COVID-19, ASB made short-term loan modifications to borrowers who were generally payment current at the time of relief. As of the end of September 2020, short-term loan modifications were made to approximately 3% of the total loans outstanding. These loans were not classified as past due or as a TDR under various provisions of the regulatory framework, as further described below.
In addition to lower net interest income and higher provision for credit losses, ASB collected lower fee income as certain fees were waived during the quarter to accommodate the hardships facing its customers. Through September 2020, ASB also had higher direct and incremental operating expenses related to COVID-19 as the Bank had purchased additional safety protection equipment to ensure its employees were protected and cleaning supplies to sanitize its facilities. The bank also provided additional compensation to frontline employees that serviced customers in the open branches and accrued expenses to purchase excess paid leave that employees will not be able to use during the remainder of 2020. ASB did realize lower expenses in other areas such as marketing, travel, business development and entertainment due to the bank delaying or reducing marketing efforts while focusing on the PPP loan program and there were restrictions on travel and dining at restaurants as result of the COVID-19 pandemic. Through September 30, 2020, the higher operating expenses, which were considered direct and incremental COVID-19 related costs, were approximately $4.5 million. For the balance of the year, ASB expects that direct and incremental COVID-19 related operating expenses will moderate from the levels experienced in the first half of 2020.
In April 2020, ASB had temporarily closed 15 of its 49 branches and reduced banking hours at the branches that remained open in an effort to reduce social gathering and protect employees and customers. The bank has reopened five of the branches that were temporarily closed and permanently closed six branches. Further branch closures may occur if the negative impacts of COVID-19 accelerate. The reduction in ASB’s branch network should not have a significant impact to the bank’s customers as there are other branches nearby and other channels such as online and mobile banking.
ASB’s senior management team continues to meet on a regular basis to manage the response to the pandemic and discuss key focus areas such as the safety of the bank’s employees and customers as well as any impacts to the operations of the bank. Senior management also continues to meet weekly with ASB’s board of directors to keep them apprised of the impacts of the COVID-19 pandemic.
The CARES Act was signed into law by President Trump on March 27, 2020. The CARES Act provides over $2 trillion in economic assistance for American workers, families, and small businesses, and job preservation for American industries. The PPP was established under the CARES Act and implemented by the United States Small Business Administration (SBA) to provide a direct incentive for small businesses to keep their workers on the payroll as a result of the COVID-19 crisis. The Paycheck Protection Program Flexibility Act was signed into law on June 5, 2020, which amended some of the prior rules and guidelines of the CARES Act. Loans issued through the PPP are 100% federally guaranteed and have a maturity of 2-5 years, depending on when the loan was made, at a fixed interest rate of 1%. Loan payments will be deferred until the earlier of (a) the date that the forgiven amount is remitted to the lender by the SBA; or (b) 10 months from the date the covered period ends. The SBA will forgive all loan amounts to a particular small business if such small business is compliant with the terms and conditions of the PPP. Small businesses have the earlier of 24 weeks from disbursement of the loan or December 31, 2020 to
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incur allowable expenses such as payroll costs, interest on mortgages, rent and utility expenses that would be covered by the loan forgiveness rules, with 60% of the loan forgiveness needing to be for payroll costs. There is a partial forgiveness if less than 60% of the loan disbursement was spent on payroll costs. Employers will have until December 31, 2020 to restore their workforce. Lenders will process and approve the PPP loans under delegated authority of the SBA. As an existing SBA certified lender, ASB worked with a number of small businesses, both customers and non-customers, to complete the loan application forms so that these businesses could participate in the program. The Bank has secured more than $370 million in PPP loans for approximately 4,100 small businesses that support over 40,000 jobs, ASB received processing fees totaling approximately $13 million and will recognize these fees over the life of the loans.
To bolster the effectiveness of the SBA’s PPP, the Federal Reserve supplied liquidity to participating financial institutions through term financing backed by PPP loans to small businesses. The Paycheck Protection Program Liquidity Facility (PPPLF), authorized under section 13(3) of the Federal Reserve Act, lends to eligible borrowers on a non-recourse basis, taking PPP loans as collateral. The maturity date of an extension of credit under this facility will equal the maturity date of the PPP loan pledged to secure the extension of credit. The maturity date of the facility’s extension of credit will be accelerated if the underlying PPP loan goes into default and ASB sells the loan to the SBA to realize on the SBA guarantee. The maturity date of the facility’s extension of credit also will be accelerated to the extent of any loan forgiveness reimbursement received by ASB from the SBA.
Other provisions of the CARES Act provides that a financial institution may elect to suspend the requirements under GAAP for certain loan modifications that would otherwise be categorized as a TDR and any related impairment for accounting purposes. See Note 4 of the Condensed Consolidated Financial Statements and “Economic conditions” in the “HEI Consolidated” section above.
ASB continues to maintain its low-risk profile, strong balance sheet and straightforward community banking business model.
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Three months ended September 30Increase
(in millions)20202019(decrease)Primary reason(s)
Interest income$60 $67 $(7)
The decrease in interest income was primarily the result of lower earning asset yields partly offset by an increase in the balances of the loan and investment portfolios. ASB’s average loan portfolio balance for the three months ended September 30, 2020 increased by $383 million compared to the same period in 2019 due to increases in the average commercial and commercial real estate loan portfolio balances of $424 million and $80 million, respectively. Included in the commercial loan portfolio growth were the PPP loans with an average balance of $358 million. The consumer and residential loan portfolio average balances decreased by $71 million and $39 million, respectively. The decrease in the consumer loan portfolio average balance was due to ASB’s decision to reduce its production of personal unsecured loans in the current economic environment. The decrease in the residential loan portfolio average balance was due to ASB’s decision to sell its low interest rate saleable loan production. The yield on the loan portfolio was 82 basis points lower than the yield on the loan portfolio in the prior year. The decrease was primarily due to the declining interest rate environment which started in the second half of 2019 and has continued this year. ASB’s average investment securities portfolio balance for the three months ended September 30, 2020 increased by $225 million compared to the same period in 2019 as ASB purchased investment securities with excess liquidity. The yield on the investment securities portfolio decreased by 40 basis points due to the lower interest rate environment. The average balance of interest-earning deposits increased by $243 million for the three months ended September 30, 2020 compared to the same period in 2019 as cash balances grew due to deposit growth, which outpaced loan growth.
Noninterest income19 16 3 
Noninterest income increased for the three months ended September 30, 2020 compared to noninterest income for the three months ended September 30, 2019 primarily due to an increase in mortgage banking income, partly offset by lower fee income from other financial services and deposit liabilities. The increase in mortgage banking income was due to the increase in residential mortgage loan sales in the secondary market as a result of higher loan production volumes. The lower fee income from other financial services and deposit liabilities was due to ASB’s decision to partially waive overdraft and other deposit account fees to accommodate the hardships customers are experiencing during the COVID-19 pandemic.
Less: gain on sale of investment securities, net— — — Gain on sale of investment securities, net, which is included in Noninterest income above and in the Bank’s statements of income and comprehensive income in Note 4, is classified as gain on sale of investment securities, net in the condensed consolidated statements of income, and accordingly, is reflected below following operating income as a separate line item and excluded from Revenues.
Revenues79 83 (4)
The decrease in revenues for the three months ended September 30, 2020 compared to the same period in 2019 was primarily due to lower interest income, partly offset by higher noninterest income.
Interest expense2 5 (3)
The decrease in interest expense for the three months ended September 30, 2020 compared to the same period in 2019 was due to a decrease in term certificate balances and lower yields on costing liabilities. Average deposit balances for the three months ended September 30, 2020 increased by $826 million compared to the same period in 2019 due to an increase in core deposits of $1.1 billion, partly offset by a decrease in average term certificate balances of $225 million. Average cost of deposits for the three months ended September 30, 2020 was 13 basis points, or 15 basis points lower than the cost of deposits for the same period in 2019. Average other borrowings for the three months ended September 30, 2020 was $19 million lower compared to the same period in 2019 and the rate was 120 basis points lower. The interest-bearing liability rate for the three months ended September 30, 2020 of 20 basis points decreased 23 basis points compared to the same period in 2019.
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Three months ended September 30Increase
(in millions)20202019(decrease)Primary reason(s)
Provision for credit losses14 3 11 
The provision for credit losses increased for the three months ended September 30, 2020 compared to the provision for loan losses for the three months ended September 30, 2019. The provision for credit losses for 2020 was primarily for increased reserves in the commercial, commercial real estate and consumer loan portfolios for expected credit deterioration due to the COVID-19 pandemic of $12.3 million and additional loss reserves to cover net charge-offs, partly offset by lower loss reserves for the consumer unsecured loan portfolio due to lower portfolio balances and loss rates. The provision for credit losses for 2019 was primarily for additional loan loss reserves for the consumer loan portfolio and growth in the loan portfolio, partly offset by the release of commercial and commercial real estate loan loss reserves due to a loan payoff and upgrades in those portfolios, and the release of loan loss reserves resulting from improving credit trends throughout the loan portfolio. Delinquency rates have decreased from 0.41% at September 30, 2019 to 0.31% at September 30, 2020, which exclude loans that were modified due to COVID-19. These loans were generally payment current at the time of the modification and qualify to not be treated as past due or as a TDR under relevant regulatory relief. The annualized net charge-off ratio for the three months ended September 30, 2020 was 0.32% compared to an annualized net charge-off ratio of 0.69% for the same period in 2019. The annualized net charge-off for 2019 was impacted by the partial charge-off of a commercial credit.
Noninterest expense47 46 1 
Noninterest expense for the three months ended September 30, 2020 increased compared to the same period in 2019. The increase in expenses were due to higher compensation and benefit expenses and additional expenses related to the COVID-19 pandemic of approximately $0.7 million1. See Recent Developments-COVID-19 for a discussion of the additional expenses incurred due to the COVID-19 pandemic.
Expenses63 54 9 
The increase in expenses for the three months ended September 30, 2020 compared to the same period in 2019 was due to higher provision for loan losses and higher noninterest expenses, partly offset by lower interest expense.
Operating income16 28 (12)
The decrease in operating income for the three months ended September 30, 2020 compared to the same period in 2019 was primarily due to lower interest income and higher provision for credit losses, partly offset by higher noninterest income and lower interest expense.
Gain on sale of investment securities, net— 1 (1)Prior year gain on sale of investment securities
Net income12 23 (11)
The decrease in net income for the three months ended September 30, 2020 compared to the same period in 2019 was primarily due to lower operating income, partly offset by lower income tax expense.

1 Higher operating expenses, which were considered direct and incremental COVID-19 related costs, included approximately $0.1 million of incremental compensation expense and $0.5 million of enhanced cleaning and sanitation costs.
 Nine months ended September 30Increase 
(in millions)20202019(decrease)Primary reason(s)
Interest income$184 $202 $(18)
The decrease in interest income was primarily the result of a decrease in yield on earning assets, partly offset by higher loan portfolio balances. ASB’s average loan portfolio balance for the nine months ended September 30, 2020 increased by $382 million compared to the same period in 2019 due to increases in the average commercial, commercial real estate and home equity line of credit loan portfolio balances of $305 million, $74 million and $54 million, respectively. Included in the commercial loan portfolio growth were the PPP loans with an average balance of $209 million. The average consumer loan portfolio balance decreased by $43 million due to ASB’s decision to reduce its production of personal unsecured loans in the current economic environment. The yield on loans was impacted by the declining interest rate environment which started during the last half of 2019 and has continued this year, resulting in a decrease in yields from the total loan portfolio of 70 basis points. The average investment portfolio balance for the nine months ended September 30, 2020 increased slightly compared to the same period in 2019 and the portfolio yield for September 30, 2020 was 26 basis points lower than the investment portfolio yield in the prior year. The average interest-earning deposit balance for the nine months ended September 30, 2020 increased by $163 million compared to the same period in 2019 as cash balances grew due to deposit growth, which outpaced loan growth.
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 Nine months ended September 30Increase 
(in millions)20202019(decrease)Primary reason(s)
Noninterest income58 46 12 
The increase in noninterest income for the nine months ended September 30, 2020 compared to noninterest income for the nine months ended September 30, 2019 was primarily due to gains on sales of investment securities and higher mortgage banking income, partly offset by lower fee income from financial services and deposit liabilities and lower bank owned life insurance income. In 2020, ASB sold all of its Visa Class B restricted shares and $160 million of investment securities portfolio for a pretax gain of $9.3 million. The sale of the investment securities reduced yield volatility and credit risk within the investment portfolio. The higher mortgage banking income in 2020 was due to an increase in residential mortgage loans sold in the secondary market as a result of higher loan production volumes. The lower fee income from financial services and deposit liabilities was due to ASB’s decision to waive overdraft and other deposit account fees to accommodate the hardships customers are experiencing during the COVID-19 pandemic. 2019 bank owned life insurance income included higher policy payouts.
Less: gain on sale of investment securities, net(9)— (9)Gain on sale of investment securities, net, which is included in Noninterest income above and in the Bank’s statements of income and comprehensive income in Note 4, is classified as gain on sale of investment securities, net in the condensed consolidated statements of income, and accordingly, is reflected below following operating income as a separate line item and excluded from Revenues.
Revenues233 248 (15)
The decrease in revenues for the nine months ended September 30, 2020 compared to the same period in 2019 was primarily due to lower interest income, partly offset by higher noninterest income.
Interest expense9 14 (5)
The decrease in interest expense for the nine months ended September 30, 2020 compared to the same period in 2019 was primarily due to lower term certificate balances and costing liability yields. Average deposit balances for the nine months ended September 30, 2020 increased by $529 million compared to the same period in 2019 due to an increase in core deposits of $650 million, partly offset by a decrease in average term certificate balances of $121 million. Average cost of deposits for the nine months ended September 30, 2020 was 18 basis points, or 10 basis points lower than the cost of deposits for the same period in 2019. Average other borrowings for the nine months ended September 30, 2020 decreased by $11 million compared to the same period in 2019 due to a decrease in FHLB advances of $17 million, partly offset by an increase in repurchase agreements and federal funds purchased of $6 million. The interest-bearing liability rate for the nine months ended September 30, 2020 of 27 basis points decreased by 16 basis points compared to the same period in 2019.
Provision for credit losses40 18 22 
The provision for credit losses increased for the nine months ended September 30, 2020 compared to the provision for credit losses for the nine months ended September 30, 2019. The provision for credit losses for 2020 was primarily due to additional loss reserves for the commercial, commercial real estate and the consumer loan portfolios for expected credit deterioration due to the COVID-19 pandemic and additional loss reserves for the consumer loan portfolio. The provision for credit losses for 2019 was primarily due to additional loss reserves for the consumer loan portfolio, increased reserves for an impaired commercial loan and a commercial real estate loan that was downgraded to substandard. Delinquency rates have decreased from 0.41% at September 30, 2019 to 0.31% at September 30, 2020, which exclude loans that were modified due to COVID-19. These loans were generally payment current at the time of the modification and qualify to not be treated as past due or as a TDR under relevant regulatory relief. The annualized net charge-off ratio for the nine months ended September 30, 2020 was 0.41% compared to an annualized net charge-off ratio of 0.46% for the same period in 2019.
Noninterest expense142 139 3 
Noninterest expense for the nine months ended September 30, 2020 was increased slightly compared to the same period in 2019. Higher expenses1 related to the COVID-19 pandemic, of approximately $4.5 million, were partly offset by lower marketing expenses. See Recent Developments-COVID-19 for a discussion of the additional expenses incurred due to the COVID-19 pandemic.
Expenses191 171 20 
The increase in expenses for the nine months ended September 30, 2020 compared to the same period in 2019 was due to higher provision for credit losses and higher noninterest expenses, partly offset by lower interest expense.
Operating income42 76 (34)
The decrease in operating income for the nine months ended September 30, 2020 compared to the same period in 2019 was primarily due to lower interest income, higher provision for credit losses and higher noninterest expenses, partly offset by lower interest expense and higher noninterest income.
Gain on sale of investment securities, net9 — 9 Increase was due to the sale of ASB’s Visa Class B restricted shares and other investment securities.
Net income42 61 (19)
Net income for the nine months ended September 30, 2020 was lower than the same period in 2019 due to lower operating income, partly offset by gain on sale of investment securities, net and lower income tax expenses.
1 Higher operating expenses, which were considered direct and incremental COVID-19 related costs, included approximately $2.4 million of incremental compensation expense and $1.7 million of enhanced cleaning and sanitation costs.                       
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ASB’s return on average assets, return on average equity and net interest margin were as follows:
Three months ended September 30Nine months ended September 30
(%)2020201920202019
Return on average assets0.61 1.29 0.73 1.14 
Return on average equity6.75 13.75 7.95 12.44 
Net interest margin3.12 3.82 3.34 3.87 

Three months ended September 30
20202019
(dollars in thousands)Average
balance		Interest
income/
expense		Yield/
rate (%)		Average
balance		Interest
income/
expense		Yield/
rate (%)
Assets:
Interest-earning deposits$252,738 $64 0.10 $9,764 $55 2.20 
FHLB stock9,891 83 3.31 10,029 91 3.63 
Investment securities
Taxable1,598,389 6,922 1.73 1,372,821 7,175 2.09 
Non-taxable27,917 193 2.70 28,341 352 4.86 
Total investment securities1,626,306 7,115 1.75 1,401,162 7,527 2.15 
Loans
Residential 1-4 family2,158,258 21,085 3.91 2,196,926 22,550 4.11 
Commercial real estate947,337 8,207 3.41 867,164 10,107 4.58 
Home equity line of credit1,052,607 8,201 3.10 1,064,020 9,961 3.71 
Residential land13,574 187 5.51 14,341 202 5.64 
Commercial1,055,190 8,119 3.06 630,739 7,314 4.58 
Consumer202,844 6,642 13.03 273,629 9,149 13.26 
Total loans 1,2
5,429,810 52,441 3.84 5,046,819 59,283 4.66 
Total interest-earning assets 3
7,318,745 59,703 3.25 6,467,774 66,956 4.11 
Allowance for credit losses(81,055)(58,441)
Noninterest-earning assets764,504 707,733 
Total assets$8,002,194 $7,117,066 
Liabilities and shareholder’s equity:
Savings$2,715,445 $424 0.06 $2,338,580 $504 0.09 
Interest-bearing checking1,130,053 92 0.03 1,041,485 388 0.15 
Money market165,330 86 0.21 141,664 229 0.64 
Time certificates596,601 1,685 1.12 821,711 3,263 1.58 
Total interest-bearing deposits4,607,429 2,287 0.20 4,343,440 4,384 0.40 
Advances from Federal Home Loan Bank30,283 27 0.36 39,880 233 2.32 
Securities sold under agreements to repurchase and federal funds purchased65,988 34 0.20 75,814 189 0.99 
Total interest-bearing liabilities4,703,700 2,348 0.20 4,459,134 4,806 0.43 
Noninterest bearing liabilities:
Deposits2,421,842 1,860,080 
Other156,687 131,832 
Shareholder’s equity719,965 666,020 
Total liabilities and shareholder’s equity$8,002,194 $7,117,066 
Net interest income$57,355 $62,150 
Net interest margin (%) 4
3.12 3.82 

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Nine months ended September 30
20202019
(dollars in thousands)Average
balance		Interest
income/
expense		Yield/
rate (%)		Average
balance
Interest
 income/
expense
Yield/
rate (%)
Assets:      
Interest-earning deposits$173,151 $216 0.16 $9,776 $172 2.32 
FHLB stock9,639 236 3.27 10,052 276 3.67 
Investment securities
Taxable1,444,895 21,919 2.02 1,444,810 24,490 2.26 
Non-taxable28,463 719 3.32 27,476 1,043 5.00 
Total investment securities1,473,358 22,638 2.05 1,472,286 25,533 2.31 
Loans   
Residential 1-4 family2,170,785 64,642 3.97 2,178,214 67,280 4.12 
Commercial real estate927,901 26,014 3.70 854,252 30,393 4.71 
Home equity line of credit1,080,914 25,894 3.20 1,026,440 29,295 3.82 
Residential land13,650 568 5.55 13,658 557 5.44 
Commercial914,431 22,535 3.28 609,732 21,196 4.63 
Consumer228,280 21,917 12.82 271,600 27,058 13.32 
Total loans 1,2
5,335,961 161,570 4.03 4,953,896 175,779 4.73 
Total interest-earning assets 3
6,992,109 184,660 3.52 6,446,010 201,760 4.17 
Allowance for credit losses(77,891)  (55,210)  
Noninterest-earning assets756,882   691,148   
Total assets$7,671,100   $7,081,948   
Liabilities and shareholder’s equity:      
Savings$2,554,376 $1,583 0.08 $2,335,613 $1,392 0.08 
Interest-bearing checking1,091,944 415 0.05 1,041,420 918 0.12 
Money market157,689 425 0.36 146,247 725 0.66 
Time certificates702,030 6,522 1.24 822,483 9,888 1.61 
Total interest-bearing deposits4,506,039 8,945 0.26 4,345,763 12,923 0.40 
Advances from Federal Home Loan Bank25,918 138 0.71 42,601 808 2.54 
Securities sold under agreements to repurchase and federal funds purchased83,148 311 0.50 77,417 553 0.95 
Total interest-bearing liabilities4,615,105 9,394 0.27 4,465,781 14,284 0.43 
Noninterest bearing liabilities:      
Deposits2,204,221   1,835,214   
Other148,547   129,642   
Shareholder’s equity703,227   651,311   
Total liabilities and shareholder’s equity$7,671,100   $7,081,948   
Net interest income $175,266   $187.476  
Net interest margin (%) 4
  3.34   3.87 

1        Includes loans held for sale, at lower of cost or fair value.
2        Includes recognition of net deferred loan fees of $1.5 million and nil for the three months ended September 30, 2020 and 2019 and $2.1 million and $0.2 million for the nine months ended September 30, 2020 and 2019, respectively, together with interest accrued prior to suspension of interest accrual on nonaccrual loans.
3        For the three and nine months ended September 30, 2020 and 2019, the taxable-equivalent basis adjustments made to the table above were not material.
4        Defined as net interest income, on a fully taxable equivalent basis, as a percentage of average total interest-earning assets.
Earning assets, costing liabilities, contingencies and other factors.  Earnings of ASB depend primarily on net interest income, which is the difference between interest earned on earning assets and interest paid on costing liabilities. The interest rate environment has been impacted by disruptions in the financial markets over a period of several years. In the prior year, interest rate increases had resulted in an increase in ASB’s net interest income and net interest margin. However, the recent interest rate reductions have negatively impacted ASB’s net interest income and net interest margin. Future interest reductions may continue to negatively impact ASB’s net interest income and net interest margin.
Loans and mortgage-backed securities are ASB’s primary earning assets.
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 Loan portfolio.  ASB’s loan volumes and yields are affected by market interest rates, competition, demand for financing, availability of funds and management’s responses to these factors. See Note 4 of the Condensed Consolidated Financial Statements for the composition of ASB’s loans.
Home equity — key credit statistics. Attention has been given by regulators and rating agencies to the potential for increased exposure to credit losses associated with home equity lines of credit (HELOC) that were originated during the period of rapid home price appreciation between 2003 and 2007 as they have reached the end of their 10-year, interest-only payment periods. Once the interest-only payment period has ended, payments are reset to include principal repayments along with interest. ASB does not have a large exposure to HELOCs originated between 2003 and 2007. Nearly all of ASB’s HELOC originations prior to 2008 consisted of amortizing equity lines that have structured principal payments during the draw period. These older equity lines represent 1% of the HELOC portfolio and are included in the amortizing balances identified in the loan portfolio table below.
 September 30, 2020December 31, 2019
Outstanding balance of home equity loans (in thousands)$1,028,011 $1,092,125 
Percent of portfolio in first lien position56.3 %53.7 %
Annualized net charge-off (recoveries) ratio(0.01 %)0.01 %
Delinquency ratio0.29 %0.27 %

   End of draw period – interest onlyCurrent amortizing
September 30, 2020TotalInterest only2020-20212022-2024Thereafter
Outstanding balance (in thousands)$1,028,011$782,835$26,251$98,202$658,382$245,176
% of total100 %76 %2 %10 %64 %24 %
The HELOC portfolio makes up 19% of the total loan portfolio and is generally an interest-only revolving loan for a 10-year period, after which time the HELOC outstanding balance converts to a fully amortizing variable-rate term loan with a 20-year amortization period. This product type comprises 78% of the total HELOC portfolio and is the current product offering. Borrowers also have a “Fixed Rate Loan Option” to convert a part of their available line of credit into a 5, 7 or 10-year fully amortizing fixed-rate loan with level principal and interest payments. As of September 30, 2020, approximately 21% of the portfolio balances were amortizing loans under the Fixed Rate Loan Option.
Loan portfolio risk elements.  See Note 4 of the Condensed Consolidated Financial Statements.
Investment securities.  ASB’s investment portfolio was comprised as follows:
 September 30, 2020December 31, 2019
(dollars in thousands)Balance% of totalBalance% of total
U.S. Treasury and federal agency obligations$63,588 3 %$117,787 9 %
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies1,759,406 94 1,165,836 85 
Corporate bonds31,337 2 60,057 4 
Mortgage revenue bonds27,185 1 28,597 2 
Total investment securities$1,881,516 100 %$1,372,277 100 %
Currently, ASB’s investment portfolio consists of U.S. Treasury and federal agency obligations, mortgage-backed securities, corporate bonds and mortgage revenue bonds. ASB owns mortgage-backed securities issued or guaranteed by the U.S. government agencies or sponsored agencies, including the Federal National Mortgage Association (FNMA), Federal Home Loan Mortgage Corporation (FHLMC), Government National Mortgage Association (GNMA) and Small Business Administration (SBA). Principal and interest on mortgage-backed securities issued by FNMA, FHLMC, GNMA and SBA are guaranteed by the issuer and, in the case of GNMA and SBA, backed by the full faith and credit of the U.S. government. U.S. Treasury securities are also backed by the full faith of the U.S. government. The increase in the investment securities portfolio was primarily due to the purchase of securities with excess liquidity.
Deposits and other borrowings.  Deposits continue to be the largest source of funds for ASB and are affected by market interest rates, competition and management’s responses to these factors. While deposits have increased by $766 million year-to-date, in part due to PPP loan proceeds and consumer economic impact payments from the CARES Act stimulus program, deposit retention and sustained growth will remain challenging in the current environment due to competition for deposits and the low level of short-term interest rates. Advances from the FHLB of Des Moines, securities sold under agreements to repurchase and federal funds purchased continue to be additional sources of funds. As of September 30, 2020 and December 31,
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2019, ASB’s costing liabilities consisted of 98% deposits and 2% other borrowings. The weighted average cost of deposits for the first nine months of 2020 and 2019 was 0.18% and 0.28%, respectively.
Federal Home Loan Bank of Des Moines. As of September 30, 2020 ASB had advances outstanding at the FHLB of Des Moines of $56 million compared to nil as of December 31, 2019. As of September 30, 2020, the unused borrowing capacity with the FHLB of Des Moines was $2.0 billion. The FHLB of Des Moines continues to be an important source of liquidity for ASB.
In February 2020, the FHLB of Des Moines notified its members that certain assets, which included high-quality home equity lines of credit that were priced off a variable index with a fixed rate option, would no longer qualify as collateral for FHLB Advances. In March 2020, the FHLB of Des Moines provisionally accepted the previously disqualified assets as collateral while they assessed the eligibility of those assets. In July 2020, the FHLB of Des Moines announced the conclusion of their review of home equity lines of credit eligibility and effective October 1, 2020, the FHLB of Des Moines will no longer accept the fixed rate portion of any home equity lines of credit. In addition, on June 12, 2020, the FHLB of Des Moines announced an update to their Loan to Value (LTV), a system-wide percentage applied to eligible pledged collateral to determine borrowing capacity, to reflect ongoing risks in the market due to COVID-19.
Effective July 13, 2020, the LTV was lowered, which reduced ASB’s collateral value of the existing pledged loans and the borrowing capacity by $100 million. To increase the borrowing capacity at the FHLB of Des Moines, ASB pledged commercial real estate loans, which increased the borrowing capacity by $200 million.
Contingencies.  ASB is subject in the normal course of business to pending and threatened legal proceedings. Management does not anticipate that the aggregate ultimate liability arising out of these pending or threatened legal proceedings will be material to its financial position. However, ASB cannot rule out the possibility that such outcomes could have a material adverse effect on the results of operations or liquidity for a particular reporting period in the future.
Other factors.  Interest rate risk is a significant risk of ASB’s operations and also represents a market risk factor affecting the fair value of ASB’s investment securities. Increases and decreases in prevailing interest rates generally translate into decreases and increases in the fair value of the investment securities, respectively. In addition, changes in credit spreads also impact the fair values of the investment securities.
As of September 30, 2020, ASB had an unrealized gain, net of taxes, on available-for-sale investment securities (including securities pledged for repurchase agreements) in AOCI of $22.2 million compared to an unrealized gain, net of taxes, of $2.5 million as of December 31, 2019. See “Item 3. Quantitative and qualitative disclosures about market risk” for a discussion of ASB’s interest rate risk sensitivity.
During the first nine months of 2020, ASB recorded a provision for credit losses related to the allowance for credit losses of $35.2 million primarily due to increased reserves for the commercial, commercial real estate and consumer loan portfolios for expected credit deterioration due to the COVID-19 pandemic and additional loss reserves for the consumer loan portfolio. During the first nine months of 2019, ASB recorded a provision for credit losses of $17.9 million primarily due to increased loss reserves for the consumer loan portfolio and additional reserves for an impaired commercial loan and a commercial real estate loan that was downgraded.
 Nine months ended September 30Year ended
December 31, 2019
(in thousands)20202019
Allowance for credit losses, prior to adoption of ASU No. 2016-13$53,355 $52,119 $52,119 
Impact of adopting ASU No. 2016-1319,441 — — 
Provision for credit losses35,204 17,873 23,480 
Less: net charge-offs16,541 16,952 22,244 
Allowance for credit losses, end of period$91,459 $53,040 $53,355 
Ratio of net charge-offs during the period to average loans outstanding (annualized)0.41 %0.46 %0.45 %
ASB maintains a reserve for credit losses that consists of two components, the allowance for credit losses and an allowance for loan commitments (unfunded reserve). The level of the reserve for unfunded loan commitments is adjusted by recording an expense or recovery in provision for credit losses. For the nine months ended September 30, 2020 and 2019, ASB recorded a provision for credit losses for unfunded commitments of $4.3 million and nil, respectively. As of September 30, 2020 and December 31, 2019, the reserve for unfunded loan commitments was $7.6 million and $1.7 million, respectively.
Legislation and regulation.  ASB is subject to extensive regulation, principally by the OCC and the FDIC. Depending on ASB’s level of regulatory capital and other considerations, these regulations could restrict the ability of ASB to compete with other institutions and to pay dividends to its shareholder. See the discussion below under “Liquidity and capital resources.”
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Changes to Community Bank Leverage Ratio. In April 2020, the federal bank regulatory agencies issued two interim final rules to implement Section 4012 of the CARES Act, which requires the agencies to temporarily lower the community bank leverage ratio to 8 percent. The two rules modify the community bank leverage ratio framework so that:
•Beginning in the second quarter of 2020 and until the end of the year, a banking organization that has a leverage ratio of 8 percent or greater and meets certain other criteria may elect to use the community bank leverage ratio framework; and
•Community banking organizations will have until January 1, 2022 before the community bank leverage ratio requirement is re-established at greater than 9 percent.
Under the interim final rules, the community bank leverage ratio will be 8 percent beginning in the second quarter of 2020 and for the remainder of calendar year 2020, 8.5 percent for calendar year 2021, and 9 percent thereafter. The interim final rules also maintain a two-quarter grace period for a qualifying community banking organization whose leverage ratio falls no more than 1 percent below the applicable community bank leverage ratio.
Beginning in the second quarter of 2020, ASB has adopted the community bank leverage ratio framework.
Covered Savings Associations. On May 24, 2019, the OCC issued a final rule to allow federal savings associations with total consolidated assets of $20 billion or less, as reported by the association to the OCC on its call report as of December 31, 2017, to elect to operate as covered savings associations. A covered savings association generally has the same rights and privileges as a national bank that has its main office situated in the same location as the home office of the covered savings association, with some exceptions. It is subject to the same duties, restrictions, penalties, liabilities, conditions, and limitations that apply to a national bank, with some exceptions, and must comply with certain rules and regulations applicable to the powers and investments of a national bank. A covered savings association is not required to comply with the lending and investment limits in HOLA and is not required to be a qualified thrift lender under HOLA. Finally, a covered savings association is not permitted to retain or engage in any subsidiaries, assets, or activities that are not permissible for a national bank. ASB has initiated a preliminary examination of the benefits and disadvantages of such an election with the preservation of being held by a unitary thrift holding company in mind. ASB is awaiting official FRB commentary and an FRB response to an inquiry letter sent by ASB. The bank has not reached a decision on the election.

FINANCIAL CONDITION
Liquidity and capital resources.
(dollars in millions)September 30, 2020December 31, 2019% change
Total assets$8,076 $7,233 12 
Investment securities1,882 1,372 37 
Loans held for investment, net5,389 5,068 6 
Deposit liabilities7,038 6,272 12 
Other bank borrowings152 115 32 
As of September 30, 2020, ASB was one of Hawaii’s largest financial institutions based on assets of $8.1 billion and deposits of $7.0 billion.
As of September 30, 2020, ASB’s unused FHLB borrowing capacity was approximately $2.0 billion. As of September 30, 2020, ASB had commitments to borrowers for loans and unused lines and letters of credit of $2.0 billion, of which, commitments to lend to borrowers whose loan terms have been modified in troubled debt restructurings were nil. Management believes ASB’s current sources of funds will enable it to meet these obligations while maintaining liquidity at satisfactory levels.
For the nine months ended September 30, 2020, net cash provided by ASB’s operating activities was $75 million. Net cash used during the same period by ASB’s investing activities was $862 million, primarily due to purchases of available-for-sale securities of $986 million, a net increase in loans of $374 million, purchases of held-to-maturity securities of $29 million, additions to premises and equipment of $9 million, contributions to low income housing investments of $4 million and a net increase in stock from the Federal Home Loan Bank of $2 million, partly offset by the receipt of repayments from investment securities of $366 million, proceeds from the sale of investment securities of $169 million and proceeds from the sale of low income housing investments of $7 million. Net cash provided by financing activities during this period was $770 million, primarily due to increases in deposit liabilities of $766 million and proceeds from FHLB advances of $56 million, partly offset by a net decrease in repurchase agreements of $19 million, a net decrease in mortgage escrow deposits of $5 million and $28 million in common stock dividends to HEI (through ASB Hawaii).
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For the nine months ended September 30, 2019, net cash provided by ASB’s operating activities was $71 million. Net cash used during the same period by ASB’s investing activities was $65 million, primarily due to a net increase in loans of $258 million, additions to premises and equipment of $22 million, purchases of available-for-sale securities of $5 million, contributions to low income housing investments of $6 million and purchase of bank owned life insurance of $4 million, partly offset by the receipt of repayments from available-for-sale investment securities of $195 million, proceeds from the sale of investment securities of $20 million, proceeds from the redemption of bank owned life insurance policies of $6 million and the receipt of held-to-maturity investment securities of $9 million. Net cash provided by financing activities during this period was $5 million, primarily due to increases in deposit liabilities of $37 million and a net increase in retail repurchase agreements of $26 million, partly offset by a net decrease in FHLB advances of $7 million, a net decrease in mortgage escrow deposits of $5 million and $47 million in common stock dividends to HEI (through ASB Hawaii).
ASB believes that maintaining a satisfactory regulatory capital position provides a basis for public confidence, affords protection to depositors, helps to ensure continued access to capital markets on favorable terms and provides a foundation for growth. FDIC regulations restrict the ability of financial institutions that are not well-capitalized to compete on the same terms as well-capitalized institutions, such as by offering interest rates on deposits that are significantly higher than the rates offered by competing institutions. Beginning in the second quarter of 2020, ASB has adopted the community bank leverage ratio framework and will be required to report only its leverage ratio. As of September 30, 2020, ASB was well-capitalized (well-capitalized ratio requirements noted in parentheses) with a Tier-1 leverage ratio of 8.3% (5.0%). As of December 31, 2019, ASB was well-capitalized with a common equity Tier-1 ratio of 13.2%, Tier-1 capital ratio of 13.2%, a Total capital ratio of 14.3% and a Tier-1 leverage ratio of 9.1%. All dividends are subject to review by the OCC and FRB and receipt of a letter from the FRB communicating the agencies’ non-objection to the payment of any dividend ASB proposes to declare and pay to HEI (through ASB Hawaii).
Item 3. Quantitative and Qualitative Disclosures About Market Risk
The Company considers interest-rate risk (a non-trading market risk) to be a significant market risk for ASB as it could potentially have material impacts on the Company’s results of operations, financial condition and liquidity. For additional quantitative and qualitative information about the Company’s market risks, see HEI’s and Hawaiian Electric’s Quantitative and Qualitative Disclosures About Market Risk in Part II, Item 7A of HEI’s 2019 Form 10-K (pages 69 to 71).
ASB’s interest-rate risk sensitivity measures as of September 30, 2020 and December 31, 2019 constitute “forward-looking statements” and were as follows:
Change in interest ratesChange in NII
(gradual change in interest rates)		Change in EVE
(instantaneous change in interest rates)
(basis points)September 30, 2020December 31, 2019September 30, 2020December 31, 2019
+3004.0 %2.8 %24.7 %15.3 %
+2002.9 2.1 19.4 12.2 
+1001.6 1.3 11.6 7.5 
-100(1.7)(2.0)(23.1)(12.7)
ASB’s net interest income (NII) sensitivity profile was more asset sensitive as of September 30, 2020 compared to December 31, 2019, primarily driven by the exceptionally low interest rate environment. The decrease in market rates increased prepayment expectations in the bank’s fixed-rate mortgage and mortgage-backed investment portfolios.
Economic value of equity (EVE) sensitivity increased as of September 30, 2020 compared to December 31, 2019 primarily due to strong growth in long duration core deposits. In addition, the downward shift in the yield curve led to faster prepayment expectations and shortened the duration of the fixed-rate mortgage and mortgage-backed investment portfolios.
The computation of the prospective effects of hypothetical interest rate changes on the NII sensitivity and the percentage change in EVE is based on numerous assumptions, including relative levels of market interest rates, loan prepayments, balance changes and pricing strategies, and should not be relied upon as indications of actual results. To the extent market conditions and other factors vary from the assumptions used in the simulation analysis, actual results may differ materially from the simulation results. NII sensitivity analysis measures the change in ASB’s twelve-month, pretax NII in alternate interest rate scenarios, and is intended to help management identify potential exposures in ASB’s current balance sheet and formulate appropriate strategies for managing interest rate risk. The simulation does not contemplate any actions that ASB management might undertake in response to changes in interest rates. Further, the changes in NII vary in the twelve-month simulation period and are not necessarily evenly distributed over the period. These analyses are for analytical purposes only and do not represent management’s views of future market movements, the level of future earnings or the timing of any changes in earnings within the twelve month analysis horizon. The actual impact of changes in interest rates on NII will depend on the magnitude and
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speed with which rates change, actual changes in ASB’s balance sheet and management’s responses to the changes in interest rates.
Item 4. Controls and Procedures
HEI:
Disclosure Controls and Procedures
The Company maintains a set of disclosure controls and procedures designed to provide reasonable assurance that information required to be disclosed by the Company in reports that it files or submits under the Securities Exchange Act of 1934, as amended (Exchange Act), is recorded, processed, summarized and reported within the time periods specified in SEC’s rules and forms, and that such information is accumulated and communicated to the Company’s management, including its Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.
An evaluation was performed under the supervision and with the participation of the Company’s management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures, as defined in Rule 13a-15(e) or Rule 15d-15(e) of the Exchange Act. Management, including the Company’s Chief Executive Officer and Chief Financial Officer, concluded that the Company’s disclosure controls and procedures were effective, as of the end of the period covered by this report, at the reasonable assurance level.
Changes in Internal Control Over Financial Reporting
There have been no changes in internal control over financial reporting during the third quarter of 2020 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.
Hawaiian Electric:
Disclosure Controls and Procedures
Hawaiian Electric maintains a set of disclosure controls and procedures designed to provide reasonable assurance that information required to be disclosed by Hawaiian Electric in reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in SEC’s rules and forms, and that such information is accumulated and communicated to Hawaiian Electric’s management, including its Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.
An evaluation was performed under the supervision and with the participation of Hawaiian Electric’s management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of Hawaiian Electric’s disclosure controls and procedures, as defined in Rule 13a-15(e) or Rule 15d-15(e) of the Exchange Act. Management, including Hawaiian Electric’s Chief Executive Officer and Chief Financial Officer, concluded that Hawaiian Electric’s disclosure controls and procedures were effective, as of the end of the period covered by this report, at the reasonable assurance level.
Changes in Internal Control Over Financial Reporting
There have been no changes in internal control over financial reporting during the third quarter of 2020 that have materially affected, or are reasonably likely to materially affect, Hawaiian Electric’s internal control over financial reporting.
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PART II - OTHER INFORMATION

Item 1. Legal Proceedings
The descriptions of legal proceedings (including judicial proceedings and proceedings before the PUC and environmental and other administrative agencies) in HEI’s and Hawaiian Electric’s 2019 Form 10-K (see “Part I. Item 3. Legal Proceedings” and proceedings referred to therein) and this Form 10-Q (see “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and Notes 3 and 4 of the Condensed Consolidated Financial Statements) are incorporated by reference in this Item 1. With regard to any pending legal proceeding, alternative dispute resolution, such as mediation or settlement, may be pursued where appropriate, with such efforts typically maintained in confidence unless and until a resolution is achieved. Certain HEI subsidiaries (including Hawaiian Electric and its subsidiaries, ASB and Pacific Current and its subsidiaries) may also be involved in ordinary routine PUC proceedings, environmental proceedings and litigation incidental to their respective businesses.
Item 1A. Risk Factors
Our business, financial condition, liquidity and results of operations could be adversely impacted by the ongoing effects of the COVID-19 pandemic. The COVID-19 pandemic has affected nearly all countries and all 50 states within the United States, including Hawaii. Due to the numerous country, state, city and local jurisdictions that have imposed “shelter-in-place” orders, including travel restrictions that directly impact the Hawaii economy, economic activity in the state has been adversely impacted. As a result of the swift economic contraction and reduction in tourism that has occurred in the state to date, the Utilities expect that demand for electricity will remain depressed and the provision for bad debt and write-offs at the Utilities will remain at an elevated level and impact liquidity as long as social-distancing measures, and travel restrictions, and other governmental orders that severely restrict economic activity remain in place. In the third quarter of 2020, overall kWh sales have declined 13.1% as compared to the third quarter of 2019. While the Utilities expect to recover the difference between PUC approved target revenues and recorded adjusted revenues (regardless of the level of kWh sales) through the revenue balancing account under the decoupling mechanism based on estimated sales, starting on June 1st of the following year, the collection occurs on a lagged basis. If the difference to be collected, which needs to be financed in the interim, exceeds the Utilities’ current liquidity sources, there can be no assurance that the Utilities will be able to secure additional liquidity sources at a reasonable cost, or at all, or if the difference becomes so large that it would result in a significant increase in customer bills, whether the PUC will allow recovery of such difference through the revenue balancing account. In addition to lower and lagged collections, the COVID-19 pandemic has also resulted in higher costs and expenses. While the Utilities have been granted deferral treatment of certain COVID-19 related costs, such as higher bad debt expense, non-collection of late payment fees, higher financing costs, sequestration costs for mission-critical employees and other costs and expenses, there can be no assurance that the PUC will grant recovery of such costs, and such costs could be material. Additionally, in light of the significant impact that economic conditions have had on residents and businesses in the state, a stipulated settlement between Hawaiian Electric and the Division of Consumer Advocacy of the Department of Commerce and Consumer Affairs, reflecting no base rate increase, was submitted in the Hawaiian Electric 2020 test year rate case, and approved by the PUC in October 2020. While the Utilities intend to offset the no base rate increase with corresponding cost decreases, such reduction of cost is not assured and, therefore, the inability to achieve targeted cost savings could adversely affect the Utilities’ results of operations.
ASB’s net interest income has also been adversely impacted by lower interest rates across the curve, which are influenced by economic conditions. Accordingly, an extended economic slowdown could have a significant continuing impact on its net interest income and its provision for credit losses.
While the Company believes that it has sufficient liquidity to operate through this crisis, there can be no assurance that sufficient liquidity will be available if the slowdown in economic activity continues for an extended period of time.
The Company is closely monitoring the situation and taking appropriate actions to operate its businesses and protect its workforce while serving customers and the community, but an extended slowdown of economic activity could have a material adverse effect on the Company. These effects could include, but are not limited to:
•Disruptions or restrictions on employees’ ability to work effectively due to illness, travel restrictions, quarantines, shelter-in-place orders or other limitations.
•The inability of customers, IPPs, contractors, suppliers, creditors and other business partners to fulfill their obligations. For example, several IPPs have declared force majeure as a protective measure, citing the pandemic, which could potentially result in significant project delays.
•Disruption and volatility in the global credit and financial markets, which may increase the cost of capital and could adversely impact access to capital for the Company and its customers and suppliers.
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•Further deterioration in economic conditions, or an extension of slow economic activity, which negatively impacts the Company’s earnings and liquidity, could also result in an impairment in the carrying value of goodwill or long-lived assets.
•Actions taken or may be taken, or decisions made or may be made by the Company, as a consequence of the COVID-19 pandemic, may result in legal claims or litigation against the Company.
Due to the unprecedented nature of the pandemic and the significant uncertainty it creates, including the unknown severity and duration of the pandemic and the resulting impact it may have on Hawaii businesses and residents of the state, the Company is unable to predict the full extent of the future impact on the Company’s businesses at this time, and those impacts could have a material adverse effect on the Company’s results of operations, financial position, and cash flows.
The Paycheck Protection Program is a guaranteed loan program and is subject to federal government regulations. The Paycheck Protection Program (PPP), established under the CARES Act and administered by the United States Small Business Administration (SBA), was created to provide a direct incentive for small businesses to keep their workers on the payroll as a result of the COVID-19 crisis. The Paycheck Protection Program Flexibility Act was signed into law on June 5, 2020, which amended some of the prior rules and guidelines of the CARES Act. Loans issued through the PPP are 100% federally guaranteed and have a maturity of 2-5 years, depending on when the loan was made, at a fixed interest rate of 1%. Loan payments will be deferred until the earlier of (a) the date that the forgiven amount is remitted to the lender by the SBA; or (b) 10 months from the date the covered period ends. The SBA will forgive all loan amounts to a particular small business if such small business is compliant with the terms and conditions of the PPP. Small businesses have the earlier of 24 weeks from disbursement of the loan or December 31, 2020 to incur allowable expenses such as payroll costs, interest on mortgages, rent and utility expenses that would be covered by the loan forgiveness rules, with 60% of the loan forgiveness needing to be for payroll costs. There is a partial forgiveness if less than 60% of the loan disbursement was spent on payroll costs. Employers will have until December 31, 2020 to restore their workforce. Lenders will process and approve the PPP loans under delegated authority of the SBA. The Lender assumes all obligations, responsibilities, and requirements associated with delegated processing of covered loans made under PPP. Any change in the terms or conditions stated in the loan authorization shall be made in accordance with PPP loan program requirements. For purposes of making covered loans to an eligible recipient under PPP, the lender is responsible, to the extent set forth in the PPP loan program requirements, for all decisions concerning eligibility of a borrower for a covered loan. Failure to comply with PPP loan program requirements may result in loans losing its 100% federally guaranteed status. In addition, in the event loan proceeds are not used in accordance with PPP loan program requirements, the covered loan will not be forgiven, resulting in ASB carrying the loan on its balance sheet longer than anticipated. Through September 30, 2020, ASB has secured more than $370 million in PPP loans, and due to changes surrounding certain program requirements resulting from the rapid rollout of the program, there may be a risk that certain loans may be ultimately deemed non-compliant, in which case ASB would be subject to the credit risk of those loans.

For additional information about Risk Factors, see pages 17 to 28 of HEI’s and Hawaiian Electric’s 2019 Form 10-K and “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” “Quantitative and Qualitative Disclosures about Market Risk” and the Condensed Consolidated Financial Statements herein. Also, see “Cautionary Note Regarding Forward-Looking Statements” on pages iv through vi herein.
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Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
(c) Purchases of HEI common shares were made on the open market during the third quarter of 2020 to satisfy the requirements of certain plans as follows:
ISSUER PURCHASES OF EQUITY SECURITIES
Period*
Total Number of Shares Purchased **		 
Average
Price Paid
per Share **
 Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plans or Programs
July 1 to 31, 202027,760$36.66—NA
August 1 to 31, 202020,052$35.24—NA
September 1 to 30, 2020208,317$33.71—NA
NA Not applicable.
* Trades (total number of shares purchased) are reflected in the month in which the order is placed.
**The purchases were made to satisfy the requirements of the DRIP, the HEIRSP and the ASB 401(k) Plan for shares purchased for cash or by the reinvestment of dividends by participants under those plans and none of the purchases were made under publicly announced repurchase plans or programs. Average prices per share are calculated exclusive of any commissions payable to the brokers making the purchases for the DRIP, the HEIRSP and the ASB 401(k) Plan. Of the “Total number of shares purchased,” 19,533 of the 27,660 shares, 10,405 of the 20,052 shares and 181,061 of the 208,317 shares were purchased for the DRIP; 7,052 of the 27,660 shares, 8,153 of the 20,052 shares and 22,749 of the 208,317 shares were purchased for the HEIRSP; and the remainder was purchased for the ASB 401(k) Plan. The repurchased shares were issued for the accounts of the participants under registration statements registering the shares issued under these plans.

Item 6. Exhibits
 
Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Constance H. Lau (HEI Chief Executive Officer)
 
Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Gregory C. Hazelton (HEI Chief Financial Officer)
  
HEI Certification Pursuant to 18 U.S.C. Section 1350
HEI Exhibit 101.INSXBRL Instance Document - the instance document does not appear on the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
HEI Exhibit 101.SCHInline XBRL Taxonomy Extension Schema Document
  
HEI Exhibit 101.CALInline XBRL Taxonomy Extension Calculation Linkbase Document
  
HEI Exhibit 101.DEFInline XBRL Taxonomy Extension Definition Linkbase Document
  
HEI Exhibit 101.LABInline XBRL Taxonomy Extension Label Linkbase Document
  
HEI Exhibit 101.PREInline XBRL Taxonomy Extension Presentation Linkbase Document
HEI Exhibit 104Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
  
Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Scott W. H. Seu (Hawaiian Electric Chief Executive Officer)
  
Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Tayne S. Y. Sekimura (Hawaiian Electric Chief Financial Officer)
  
Hawaiian Electric Certification Pursuant to 18 U.S.C. Section 1350

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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. The signature of the undersigned companies shall be deemed to relate only to matters having reference to such companies and any subsidiaries thereof.
 
HAWAIIAN ELECTRIC INDUSTRIES, INC. HAWAIIAN ELECTRIC COMPANY, INC.
(Registrant) (Registrant)
   
   
By/s/ Constance H. Lau By/s/ Scott W. H. Seu
 Constance H. Lau  Scott W. H. Seu
 President and Chief Executive Officer  President and Chief Executive Officer
 (Principal Executive Officer of HEI)  (Principal Executive Officer of Hawaiian Electric)
   
   
By/s/ Gregory C. Hazelton By/s/ Tayne S. Y. Sekimura
 Gregory C. Hazelton  Tayne S. Y. Sekimura
 Executive Vice President  Senior Vice President
 and Chief Financial Officer  and Chief Financial Officer
 (Principal Financial Officer of HEI)  (Principal Financial Officer of Hawaiian Electric)
   
   
Date: November 6, 2020 Date: November 6, 2020

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