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HAWAIIAN ELECTRIC INDUSTRIES INC - Quarter Report: 2021 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, 2021
 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, 2021
Hawaiian Electric Industries, Inc. (Without Par Value) 109,311,289 Shares
Hawaiian Electric Company, Inc. ($6-2/3 Par Value) 17,324,376 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, 2021
 
TABLE OF CONTENTS
 
Page No. 
  
 
  
 
three and nine months ended September 30, 2021 and 2020
 
three and nine months ended September 30, 2021 and 2020
 
 
three and nine months ended September 30, 2021 and 2020
 
nine months ended September 30, 2021 and 2020
  
 
three and nine months ended September 30, 2021 and 2020
 
three and nine months ended September 30, 2021 and 2020
 
 
three and nine months ended September 30, 2021 and 2020
 
nine months ended September 30, 2021 and 2020
 
 
 
 
  
 
 
i

Hawaiian Electric Industries, Inc. and Subsidiaries
Hawaiian Electric Company, Inc. and Subsidiaries
Form 10-Q—Quarter ended September 30, 2021
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.
AOCI Accumulated other comprehensive income/(loss)
ARAAnnual revenue adjustment
ASB American Savings Bank, F.S.B., a wholly owned subsidiary of ASB Hawaii, Inc.
ASB Hawaii ASB Hawaii, 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 (listed under Pacific Current); 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
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
EPRMExceptional Project Recovery Mechanism
ERP/EAMEnterprise Resource Planning/Enterprise Asset Management
EPS Earnings per share
ESGEnvironmental, Social & Governance
ESMEarnings Sharing Mechanism
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
FitchFitch Ratings, Inc.
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
Moody’sMoody’s Investors Service’s
MPIRMajor Project Interim Recovery
MW Megawatt/s (as applicable)
MRPMulti-year rate period
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 Current
Pacific Current, LLC, a wholly owned subsidiary of HEI and parent company of Hamakua Holdings, LLC, Mauo, LLC, ‘Alenuihāhā Developments, LLC, Ka‘ie‘ie Waho Company, LLC and Kaʻaipuaʻa 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
REIPRenewable Energy Infrastructure Program
RFP Request for proposals
ROACE Return on average common equity
RORB Return on rate base
RPS Renewable portfolio standards
S&PStandard & Poor’s
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
VIEs Variable interest entities
 
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 due to new variants or insufficient vaccinations, 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 or ability to pay for the Company’s goods and services, all of which could be affected by the pace of distribution, administration, and efficacy of COVID-19 vaccines over the short- and long-term, as well as the proportion of the population vaccinated;
•ability to adequately address risks and capitalize on opportunities related to our environmental, social and governance (ESG) priority areas, which currently include decarbonization, economic health and affordability, reliability and resilience, secure digitalization, diversity, equity and inclusion, employee engagement, and climate-related risks and opportunities;
•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 or stakeholder activism that 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 renewable portfolio standards (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 Biden and his administration;
•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 resilience and reliability and cost of 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, or higher borrowing costs;
•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);
iv

•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, biofuels, environmental assessments required to meet RPS goals; the impacts of implementation of the renewable energy proposals on future costs of electricity and potential penalties imposed by the PUC for delays in the commercial operations of renewable energy projects;
•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;
•the ability of the Utilities to recover undepreciated cost of fossil fuel generating units, if they are retired before the end of their expected useful life;
•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, 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 the annual revenue adjustment (ARA);
•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, including use of digital currencies, which could include a central bank digital currency;
•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 remaining cost savings commitment related to the Enterprise Resource Planning/Enterprise Asset Management (ERP/EAM) project-related benefits and the management audit committed savings of $33 million over the 2021 to 2025 multi-year rate period (MRP);
•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);
v

•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);
•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 a decrease in net interest income and portfolio yields, 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), and the risks associated with the operation of transmission and distribution assets and power generation facilities, including public and employee safety issues, and assets causing or contributing to wildfires;
•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)2021202020212020
Revenues    
Electric utility$679,499 $562,568 $1,846,242 $1,694,225 
Bank76,208 78,644 230,599 233,096 
Other1,197 215 3,266 237 
Total revenues756,904 641,427 2,080,107 1,927,558 
Expenses    
Electric utility604,307 474,050 1,634,252 1,493,948 
Bank51,151 63,144 130,440 189,700 
Other4,130 4,672 18,212 13,091 
Total expenses659,588 541,866 1,782,904 1,696,739 
Operating income (loss)    
Electric utility75,192 88,518 211,990 200,277 
Bank25,057 15,500 100,159 43,396 
Other(2,933)(4,457)(14,946)(12,854)
Total operating income97,316 99,561 297,203 230,819 
Retirement defined benefits credit (expense)—other than service costs1,058 (1,102)4,709 (2,970)
Interest expense, net—other than on deposit liabilities and other bank borrowings
(23,477)(22,086)(70,530)(66,474)
Allowance for borrowed funds used during construction827 801 2,386 2,241 
Allowance for equity funds used during construction2,427 2,347 6,995 6,556 
Gain on sale of investment securities, net— — 528 9,275 
Income before income taxes78,151 79,521 241,291 179,447 
Income taxes14,265 14,018 48,229 30,691 
Net income63,886 65,503 193,062 148,756 
Preferred stock dividends of subsidiaries471 471 1,417 1,417 
Net income for common stock$63,415 $65,032 $191,645 $147,339 
Basic earnings per common share$0.58 $0.60 $1.75 $1.35 
Diluted earnings per common share$0.58 $0.59 $1.75 $1.35 
Weighted-average number of common shares outstanding109,311 109,181 109,272 109,126 
Net effect of potentially dilutive shares264 155 316 261 
Weighted-average shares assuming dilution109,575 109,336 109,588 109,387 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2020 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)2021202020212020
Net income for common stock$63,415 $65,032 $191,645 $147,339 
Other comprehensive income (loss), net of taxes:    
Net unrealized gains (losses) on available-for-sale investment securities:    
Net unrealized gains (losses) on available-for-sale investment securities arising during the period, net of taxes of $(4,212), $360, $(14,614) and $7,836, respectively
(11,507)984 (39,921)21,405 
Reclassification adjustment for net realized gains included in net income, net of taxes of nil, nil, $(142) and $(599), respectively
— — (387)(1,638)
Derivatives qualifying as cash flow hedges:    
Unrealized interest rate hedging gains (losses) arising during the period, net of taxes of $48, $(51), $347 and $(739), respectively
139 (147)1,000 (2,129)
Reclassification adjustment for net realized losses included in net income, net of taxes of $3, nil, $3 and nil, respectively
9 — 9 — 
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 $985, $2,202, $5,155 and $6,169, respectively
2,853 6,324 14,871 17,720 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $(971), $(1,985), $(5,002) and $(5,563), respectively
(2,799)(5,721)(14,421)(16,038)
Other comprehensive income (loss), net of taxes(11,305)1,440 (38,849)19,320 
Comprehensive income attributable to Hawaiian Electric Industries, Inc.
$52,110 $66,472 $152,796 $166,659 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2020 Form 10-K.

2

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets (unaudited) 
(dollars in thousands)September 30, 2021December 31, 2020
Assets  
Cash and cash equivalents$227,923 $341,421 
Restricted cash9,412 17,558 
Accounts receivable and unbilled revenues, net331,752 281,216 
Available-for-sale investment securities, at fair value2,580,830 1,970,417 
Held-to-maturity investment securities, at amortized cost491,871 226,947 
Stock in Federal Home Loan Bank, at cost10,000 8,680 
Loans held for investment, net5,046,180 5,232,642 
Loans held for sale, at lower of cost or fair value53,998 28,275 
Property, plant and equipment, net of accumulated depreciation of $3,040,153 and $2,903,144 at September 30, 2021 and December 31, 2020, respectively
5,335,130 5,265,735 
Operating lease right-of-use assets141,816 153,069 
Regulatory assets757,204 766,708 
Other691,857 629,149 
Goodwill82,190 82,190 
Total assets$15,760,163 $15,004,007 
Liabilities and shareholders’ equity  
Liabilities  
Accounts payable$195,223 $182,347 
Interest and dividends payable33,307 23,547 
Deposit liabilities7,976,538 7,386,957 
Short-term borrowings—other than bank92,246 129,379 
Other bank borrowings129,305 89,670 
Long-term debt, net—other than bank2,244,795 2,119,129 
Deferred income taxes378,139 395,089 
Operating lease liabilities155,608 160,432 
Regulatory liabilities975,512 959,786 
Defined benefit pension and other postretirement benefit plans liability543,285 567,438 
Other618,369 618,438 
Total liabilities13,342,327 12,632,212 
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: 109,311,289 shares and 109,181,124 shares at September 30, 2021 and December 31, 2020, respectively
1,683,090 1,678,368 
Retained earnings740,566 660,398 
Accumulated other comprehensive loss, net of tax benefits(40,113)(1,264)
Total shareholders’ equity2,383,543 2,337,502 
Total liabilities and shareholders’ equity$15,760,163 $15,004,007 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2020 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, 2020109,181 $1,678,368 $660,398 $(1,264)$2,337,502 
Net income for common stock— — 64,358 — 64,358 
Other comprehensive loss, net of tax benefits— — — (44,016)(44,016)
Share-based expenses and other, net100 605 — — 605 
Common stock dividends (34¢ per share)
— — (37,156)— (37,156)
Balance, March 31, 2021109,281 1,678,973 687,600 (45,280)2,321,293 
Net income for common stock— — 63,872 — 63,872 
Other comprehensive income, net of taxes— — — 16,472 16,472 
Share-based expenses and other, net30 2,847 — — 2,847 
Common stock dividends (34¢ per share)
— — (37,155)— (37,155)
Balance, June 30, 2021109,311 1,681,820 714,317 (28,808)2,367,329 
Net income for common stock— — 63,415 — 63,415 
Other comprehensive loss, net of tax benefits— — — (11,305)(11,305)
Share-based expenses and other, net— 1,270 — — 1,270 
Common stock dividends (34¢ per share)
— — (37,166)— (37,166)
Balance, September 30, 2021109,311 $1,683,090 $740,566 $(40,113)$2,383,543 
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 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2020 Form 10-K.

4

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows (unaudited)
Nine months ended September 30
(in thousands)20212020
Cash flows from operating activities  
Net income$193,062 $148,756 
Adjustments to reconcile net income to net cash provided by operating activities  
Depreciation of property, plant and equipment184,389 178,674 
Other amortization24,511 39,580 
Provision for credit losses(22,367)39,504 
Loans originated, held for sale(281,744)(380,864)
Proceeds from sale of loans, held for sale304,820 387,247 
Gain on sale of investment securities, net(528)(9,275)
Gain on sale of loans, net(7,497)(15,933)
Deferred income taxes(13,473)(14,464)
Share-based compensation expense6,727 5,449 
Allowance for equity funds used during construction(6,995)(6,556)
Other(7,046)(4,773)
Changes in assets and liabilities  
Decrease (increase) in accounts receivable and unbilled revenues, net(58,758)11,252 
Decrease (increase) in fuel oil stock(42,612)31,899 
Decrease (increase) in regulatory assets(4,952)10,012 
Increase (decrease) in regulatory liabilities8,806 (15,755)
Increase (decrease) in accounts, interest and dividends payable36,850 (20,794)
Change in prepaid and accrued income taxes, tax credits and utility revenue taxes11,133 (32,750)
Decrease in defined benefit pension and other postretirement benefit plans liability(5,288)(1,398)
Change in other assets and liabilities(51,833)(37,543)
Net cash provided by operating activities267,205 312,268 
Cash flows from investing activities  
Available-for-sale investment securities purchased(1,318,520)(985,874)
Principal repayments on available-for-sale investment securities449,459 331,238 
Proceeds from sale of available-for-sale investment securities197,354 169,157 
Purchases of held-to-maturity investment securities(314,327)(28,602)
Proceeds from repayments or maturities of held-to-maturity investment securities49,074 34,740 
Purchase of stock from Federal Home Loan Bank (32,980)(24,006)
Redemption of stock from Federal Home Loan Bank31,660 21,520 
Net decrease (increase) in loans held for investment157,619 (374,307)
Proceeds from sale of residential loans17,398 — 
Capital expenditures(219,252)(296,172)
Proceeds from sale of low-income housing investments— 6,725 
Contributions to low income housing investments(12,402)(3,951)
Other10,078 4,899 
Net cash used in investing activities(984,839)(1,144,633)
(continued)

5

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows (unaudited) (continued)
Nine months ended September 30
(in thousands)20212020
Cash flows from financing activities  
Net increase in deposit liabilities589,581 766,235 
Net increase (decrease) in short-term borrowings with original maturities of three months or less27,755 (112,710)
Net increase in other bank borrowings with original maturities of three months or less39,635 6,765 
Proceeds from issuance of short-term debt— 165,000 
Repayment of short-term debt(65,000)(100,000)
Proceeds from issuance of other bank borrowings— 30,000 
Proceeds from issuance of long-term debt206,988 365,146 
Repayment of long-term debt(80,607)(178,291)
Withheld shares for employee taxes on vested share-based compensation(2,006)(5,700)
Common stock dividends(111,477)(108,066)
Preferred stock dividends of subsidiaries(1,417)(1,417)
Other(7,462)(7,275)
Net cash provided by financing activities595,990 819,687 
Net decrease in cash, cash equivalents and restricted cash(121,644)(12,678)
Cash, cash equivalents and restricted cash, beginning of period358,979 227,685 
Cash, cash equivalents and restricted cash, end of period237,335 215,007 
Less: Restricted cash(9,412)(21,881)
Cash and cash equivalents, end of period$227,923 $193,126 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2020 Form 10-K.
6

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Statements of Income (unaudited)
Three months ended September 30Nine months ended September 30
(in thousands)2021202020212020
Revenues$679,499 $562,568 $1,846,242 $1,694,225 
Expenses    
Fuel oil180,682 105,042 447,245 390,714 
Purchased power185,759 149,025 490,520 425,679 
Other operation and maintenance116,468 111,243 349,180 348,831 
Depreciation57,386 55,689 172,122 167,235 
Taxes, other than income taxes64,012 53,051 175,185 161,489 
Total expenses604,307 474,050 1,634,252 1,493,948 
Operating income75,192 88,518 211,990 200,277 
Allowance for equity funds used during construction2,427 2,347 6,995 6,556 
Retirement defined benefits credit (expense)—other than service costs877 (432)2,918 (1,195)
Interest expense and other charges, net(18,148)(16,836)(54,126)(50,768)
Allowance for borrowed funds used during construction827 801 2,386 2,241 
Income before income taxes61,175 74,398 170,163 157,111 
Income taxes10,335 13,835 33,066 29,316 
Net income50,840 60,563 137,097 127,795 
Preferred stock dividends of subsidiaries228 228 686 686 
Net income attributable to Hawaiian Electric50,612 60,335 136,411 127,109 
Preferred stock dividends of Hawaiian Electric270 270 810 810 
Net income for common stock$50,342 $60,065 $135,601 $126,299 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2020 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)2021202020212020
Net income for common stock$50,342 $60,065 $135,601 $126,299 
Other comprehensive income, 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 $1,007, $2,001, $5,062 and $5,597, respectively
2,905 5,769 14,596 16,137 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $(971), $(1,985), $(5,002) and $(5,563), respectively
(2,799)(5,721)(14,421)(16,038)
Other comprehensive income, net of taxes106 48 175 99 
Comprehensive income attributable to Hawaiian Electric Company, Inc.
$50,448 $60,113 $135,776 $126,398 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2020 Form 10-K.
7

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets (unaudited)
(dollars in thousands, except par value)September 30, 2021December 31, 2020
Assets  
Property, plant and equipment
Utility property, plant and equipment  
Land$51,610 $51,611 
Plant and equipment7,669,720 7,509,343 
Less accumulated depreciation(2,947,715)(2,819,079)
Construction in progress221,518 188,342 
Utility property, plant and equipment, net4,995,133 4,930,217 
Nonutility property, plant and equipment, less accumulated depreciation of $58 and $115 as of September 30, 2021 and December 31, 2020, respectively
6,950 6,953 
Total property, plant and equipment, net5,002,083 4,937,170 
Current assets  
Cash and cash equivalents36,467 47,360 
Restricted cash6,313 15,966 
Customer accounts receivable, net174,237 147,832 
Accrued unbilled revenues, net129,079 101,036 
Other accounts receivable, net6,116 7,673 
Fuel oil stock, at average cost100,801 58,238 
Materials and supplies, at average cost72,997 67,344 
Prepayments and other53,961 44,083 
Regulatory assets56,224 30,435 
Total current assets636,195 519,967 
Other long-term assets  
Operating lease right-of-use assets119,624 127,654 
Regulatory assets700,980 736,273 
Other144,026 136,309 
Total other long-term assets964,630 1,000,236 
Total assets$6,602,908 $6,457,373 
Capitalization and liabilities  
Capitalization  
Common stock ($6 2/3 par value, authorized 50,000,000 shares; outstanding 17,324,376 shares at
September 30, 2021 and December 31, 2020)
$115,515 $115,515 
Premium on capital stock746,987 746,987 
Retained earnings1,334,161 1,282,335 
Accumulated other comprehensive loss, net of tax benefits-retirement benefit plans(2,744)(2,919)
Common stock equity2,193,919 2,141,918 
Cumulative preferred stock — not subject to mandatory redemption34,293 34,293 
Long-term debt, net1,676,223 1,561,302 
Total capitalization3,904,435 3,737,513 
Commitments and contingencies (Note 3)
Current liabilities  
Current portion of operating lease liabilities64,894 64,730 
Short-term borrowings from non-affiliates— 49,979 
Accounts payable146,875 133,849 
Interest and preferred dividends payable28,610 20,350 
Taxes accrued, including revenue taxes196,368 192,524 
Regulatory liabilities32,261 37,301 
Other84,506 74,262 
Total current liabilities553,514 572,995 
Deferred credits and other liabilities  
Operating lease liabilities67,802 69,494 
Deferred income taxes396,553 397,798 
Regulatory liabilities943,251 922,485 
Unamortized tax credits106,378 111,915 
Defined benefit pension and other postretirement benefit plans liability509,972 530,532 
Other121,003 114,641 
Total deferred credits and other liabilities2,144,959 2,146,865 
Total capitalization and liabilities$6,602,908 $6,457,373 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2020 Form 10-K.
8

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, 202017,324 $115,515 $746,987 $1,282,335 $(2,919)$2,141,918 
Net income for common stock— — — 43,358 — 43,358 
Other comprehensive income, net of taxes— — — — 34 34 
Common stock dividends— — — (27,925)— (27,925)
Balance, March 31, 202117,324 115,515 746,987 1,297,768 (2,885)2,157,385 
Net income for common stock— — — 41,901 — 41,901 
Other comprehensive income, net of taxes— — — — 35 35 
Common stock dividends— — — (27,925)— (27,925)
Balance, June 30, 202117,324 115,515 746,987 1,311,744 (2,850)2,171,396 
Net income for common stock— — — 50,342 — 50,342 
Other comprehensive income, net of taxes— — — — 106 106 
Common stock dividends— — — (27,925)— (27,925)
Balance, September 30, 202117,324 $115,515 $746,987 $1,334,161 $(2,744)$2,193,919 
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 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2020 Form 10-K.


9

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows (unaudited)
Nine months ended September 30
(in thousands)20212020
Cash flows from operating activities  
Net income$137,097 $127,795 
Adjustments to reconcile net income to net cash provided by operating activities  
Depreciation of property, plant and equipment172,122 167,235 
Other amortization17,058 24,929 
Deferred income taxes(12,333)(9,827)
State refundable credit(7,955)(7,589)
Bad debt expense1,303 1,401 
Allowance for equity funds used during construction(6,995)(6,556)
Other991 1,614 
Changes in assets and liabilities  
Decrease (increase) in accounts receivable(33,621)7,076 
Decrease (increase) in accrued unbilled revenues(27,491)9,842 
Decrease (increase) in fuel oil stock(42,563)31,494 
Increase in materials and supplies(5,653)(8,092)
Decrease (increase) in regulatory assets(4,952)10,012 
Increase (decrease) in regulatory liabilities8,806 (15,755)
Increase (decrease) in accounts payable27,210 (34,874)
Change in prepaid and accrued income taxes, tax credits and revenue taxes2,934 (34,768)
Decrease in defined benefit pension and other postretirement benefit plans liability(3,902)(3,064)
Change in other assets and liabilities(23,800)(15,918)
Net cash provided by operating activities198,256 244,955 
Cash flows from investing activities  
Capital expenditures(203,746)(267,482)
Other6,157 7,295 
Net cash used in investing activities(197,589)(260,187)
Cash flows from financing activities  
Common stock dividends(83,775)(80,352)
Preferred stock dividends of Hawaiian Electric and subsidiaries(1,496)(1,496)
Proceeds from issuance of short-term debt— 100,000 
Repayment of short-term debt(50,000)(100,000)
Proceeds from issuance of long-term debt115,000 255,000 
Repayment of long-term debt— (109,000)
Net decrease in short-term borrowings from non-affiliates and affiliates with original maturities of three months or less— (38,987)
Other(942)(1,569)
Net cash provided by (used in) financing activities(21,213)23,596 
Net increase (decrease) in cash and cash equivalents(20,546)8,364 
Cash, cash equivalents and restricted cash, beginning of period63,326 41,894 
Cash, cash equivalents and restricted cash, end of period42,780 50,258 
Less: Restricted cash(6,313)(20,458)
Cash and cash equivalents, end of period$36,467 $29,800 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2020 Form 10-K.

10

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, 2020.
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, 2021 and December 31, 2020 and the results of their operations for the three and nine months ended September 30, 2021 and 2020 and cash flows for the nine months ended September 30, 2021 and 2020. 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.
Income Taxes. In December 2019, Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes,” which removes specific exceptions to the general principles in Topic 740, improves financial statement preparers’ application of income tax-related guidance and simplifies GAAP under certain situations. ASU No. 2019-12 is effective for public business entities for fiscal years beginning after December 15, 2020, and interim periods within those fiscal years. The Company adopted the ASU as of January 1, 2021 with no material impact on its consolidated financial statements and related disclosures.
Leases. On July 19, 2021 FASB issued ASU No. 2021-05, “Leases (Topic 842): Lessors–Certain Leases with Variable Lease Payments.” The ASU allows lessors to treat sales-type leases with variable payments to be classified as operating leases if the sales-type lease treatment under Topic 842 would result in a selling loss at lease commencement (day-one loss). The Company early adopted ASU No. 2021-05 as of September 30, 2021 retrospectively to leases that commenced on or after the adoption of ASU No. 2016-02, “Leases (Topic 842)”. The adoption of ASU No. 2021-05 did not have a material impact on the Company’s consolidated financial statements and related disclosures.
11

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Note 2 · Segment financial information
(in thousands) Electric utilityBankOtherTotal
Three months ended September 30, 2021    
Revenues from external customers$679,482 $76,208 $1,214 $756,904 
Intersegment revenues (eliminations)17 — (17)— 
Revenues$679,499 $76,208 $1,197 $756,904 
Income (loss) before income taxes$61,175 $25,241 $(8,265)$78,151 
Income taxes (benefit)10,335 5,976 (2,046)14,265 
Net income (loss)50,840 19,265 (6,219)63,886 
Preferred stock dividends of subsidiaries498 — (27)471 
Net income (loss) for common stock$50,342 $19,265 $(6,192)$63,415 
Nine months ended September 30, 2021    
Revenues from external customers$1,846,206 $230,599 $3,302 $2,080,107 
Intersegment revenues (eliminations)36 — (36)— 
Revenues$1,846,242 $230,599 $3,266 $2,080,107 
Income (loss) before income taxes$170,163 $102,335 $(31,207)$241,291 
Income taxes (benefit)33,066 23,230 (8,067)48,229 
Net income (loss)137,097 79,105 (23,140)193,062 
Preferred stock dividends of subsidiaries1,496 — (79)1,417 
Net income (loss) for common stock$135,601 $79,105 $(23,061)$191,645 
Total assets (at September 30, 2021)
$6,602,908 $9,010,419 $146,836 $15,760,163 
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 December 31, 2020)$6,457,373 $8,396,533 $150,101 $15,004,007 
 
Intercompany electricity sales of the Utilities to ASB 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.
Hamakua Energy, LLC’s (Hamakua Energy’s) sales to Hawaii Electric Light (a regulated affiliate) are eliminated in consolidation.
12

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Note 3 · Electric utility segment
Unconsolidated variable interest entities.
Power purchase agreements.  As of September 30, 2021, the Utilities had five PPAs for firm capacity (including the Puna Geothermal Venture (PGV) PPA that went offline in May 2018 due to lava flow on Hawaii Island, but returned to service with firm capacity of 13 MW in the first quarter of 2021 and ramped up to 23.9 MW in the second quarter of 2021) 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. 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)2021202020212020
Kalaeloa$56 $39 $142 $111 
AES Hawaii32 33 98 96 
HPOWER20 18 51 52 
Hamakua Energy15 12 38 36 
Puna Geothermal Venture9 — 20 — 
Wind IPPs38 30 95 83 
Solar IPPs12 17 40 45 
Other IPPs 1
4 — 7 3 
Total IPPs$186 $149 $491 $426 
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 had been negotiating an extension to the PPA, and the PPA had automatically extended on a month-to-month basis as long as the parties were still negotiating in good faith. In October 2021, Hawaiian Electric and Kalaeloa signed the Amended and Restated Power Purchase Agreement for Firm Dispatchable Capacity and Energy (Amended and Restated PPA) to extend the PPA for an additional term of 10 years. Hawaiian Electric will be submitting an application for approval of the Amended and Restated PPA to the PUC.
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
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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. Hawaiian Electric does not intend to extend the term of the PPA which will expire on September 1, 2022.
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 greenhouse 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. As a result, the PUC reopened the docket for further proceedings, including re-examining all of the issues in the proceedings. On July 9, 2020, the PUC issued an order denying 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 September 9, 2020, the PUC denied Hu Honua’s motion for reconsideration of the PUC’s order. Hu Honua filed its notice of appeal to the Hawaii Supreme Court of the PUC’s order denying Hu Honua’s motion for reconsideration. On May 24, 2021, the Hawaii Supreme Court vacated the PUC’s decision and remanded the matter back to the PUC for further proceedings. On June 30, 2021, the PUC issued an order reopening the docket consistent with the Hawaii Supreme Court’s order. A contested case hearing has been scheduled for January 2022.
Molokai New Energy Partners (MNEP). In July 2018, the PUC approved Maui Electric’s PPA with MNEP to purchase solar energy from a photovoltaic (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. Currently, the discovery phase is ongoing.
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 or community support 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. The PUC required the benefit savings of the project to be passed on to customers.
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, 2021, the Utilities’ regulatory liability was $9.9 million ($5.8 million for Hawaiian Electric, $1.6 million for Hawaii Electric Light and $2.5 million for Maui Electric) for the O&M expense savings that are being amortized or to be included in future rates. As part of the settlement agreement approved in the Hawaiian Electric 2020 test year rate case, the regulatory liability for Hawaiian Electric will be amortized over five years, beginning in November 2020, and the O&M benefits for Hawaiian Electric was considered flowed through to customers. As part of the PBR proceeding, the regulatory
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liability as of December 31, 2020 of approximately $1.6 million and $2.3 million, respectively, for Hawaii Electric Light and Maui Electric was flowed to customers as part of the customer dividend in the annual revenue adjustment in 2021.
On July 7, 2021, the PUC issued an order modifying the reporting frequency of the Semi-Annual Enterprise System Benefits (SAESB) reports to an Annual Enterprise System Benefits (AESB) report on the achieved benefits savings. The most recent SAESB report was filed on February 26, 2021 for the period July 1 through December 31, 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 federal 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, 2021, 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, 2021, the reserve account balance recorded by Hawaiian Electric to address the PCB contamination was $10.4 million. The reserve balance represents the probable and reasonably estimable undiscounted cost for the onshore and offshore investigation and remediation. The final remediation costs will depend on the actual onshore and 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. Prior to the implementation of the performance-based regulation framework (PBR Framework), the decoupling mechanism had 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 kWh sales, (2) rate adjustment mechanism (RAM) revenues for escalation in certain O&M expenses and rate base changes, (3) major project interim recovery (MPIR) adjustment mechanism, (4) performance incentive mechanisms (PIMs), and (5) an earnings sharing mechanism (ESM), which would provide for a reduction of revenues between rate cases in the event the utility exceeds the authorized rate-making return on average common equity (ROACE) allowed in its most recent rate case.
Performance-based regulation framework. On December 23, 2020, the PUC issued a D&O (PBR D&O) approving the new PBR Framework. Under the PBR Framework, the Utilities’ decoupling will continue to be used with modifications, as described below. The existing cost recovery mechanisms will continue as currently implemented (e.g., the Energy Cost Recovery Clause (ECRC), Purchased Power Adjustment Clause (PPAC), Demand Side Management surcharge (DSM), Renewable Energy Infrastructure Program (REIP), Demand Response Adjustment Clause (DRAC), Pension and Other Post-Employment Benefits (OPEB) tracking mechanisms). In addition to annual revenues provided by the annual revenue adjustment (ARA), the Utilities may seek relief for extraordinary projects or programs through the Exceptional Project Recovery Mechanism (EPRM) (formerly known as the MPIR adjustment mechanism) and earn financial rewards for exemplary performance as provided through a portfolio of PIMs and Shared Savings Mechanisms (SSMs). The PBR Framework will incorporate a variety of other performance mechanisms, including Scorecards, Reported Metrics, and an expedited Pilot Process. The PBR Framework also contains a number of safeguards, including a symmetric ESM which protects the Utilities and customers from excessive earnings or losses, as measured by the Utilities’ achieved rate-making ROACE and a Re-Opener
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mechanism, under which the PUC will open an examination, at its discretion, to determine if adjustments or modifications to specific PBR mechanisms are appropriate. The new PBR Framework became fully effective on June 1, 2021.
On September 17, 2021, the PUC issued an order including a proposed new set of potential PIMs to address these areas of PUC concern:
•Grid reliability,
•Timely retirement of fossil fuel generation units,
•Interconnection of large-scale renewable energy projects,
•Cost control for fossil fuel, purchased power, and other non-ARA costs, and
•Expedient utilization of grid services from demand-side resources
The order established a procedural schedule by which a PBR Working Group (consisting of parties from the docket in which the new PBR Framework was established) will comment upon and evaluate the potential new PIMs and potentially propose alternatives. The schedule included procedural steps for technical conferences, statements of position filings and an evidentiary hearing. The PUC has not stated when any new PIMs might become effective. On November 2, 2021, the PUC suspended the previous procedural schedule, pending review of schedule modifications.
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). All Utilities were limited to the RAM Cap in 2020. Under the PBR Framework, the ARA mechanism replaced the RAM, and became effective on June 1, 2021. The transition to the ARA includes the continuation of the 2020 RAM revenue adjustment.
Annual revenue adjustment mechanism. The PBR Framework established a five-year multi-year rate period during which there will be no general rate cases. Target revenues will be adjusted according to an index-driven ARA based on (i) an inflation factor, (ii) a predetermined X-factor to encompass productivity, which is set at zero, (iii) a Z-factor to account for exceptional circumstances not in the Utilities’ control and (iv) a customer dividend consisting of a negative adjustment of 0.22% compounded annually and a flow through of the “pre-PBR” savings commitment from the management audit recommendations developed in a prior docket.
As a result of an Order issued by the PUC pursuant to a motion for partial reconsideration the customer dividend for “pre-PBR” savings commitment portion to be delivered to customers will be at a rate of $6.6 million per year from 2021 to 2025, and the Enterprise Resource Planning system benefits savings of $3.9 million, to be delivered to customers in 2021. The implementation of the ARA occurred on June 1, 2021.
Earnings sharing mechanism. A symmetrical ESM for achieved rate-making ROACE outside of a 300 basis points dead band above or below the current authorized ROACE of 9.5% for each of the Utilities. There is a 50/50 sharing between customers and Utilities for the achieved rate-making ROACE falling within 150 basis points outside of the dead band in either direction, and a 90/10 sharing for any further difference. A reopening or review of the PBR terms will be triggered if the Utilities credit rating outlook indicates a potential credit downgrade below investment grade status, or if its achieved rate-making ROACE enters the outer most tier of the ESM.
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 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.
On May 26, 2021, the PUC approved 2021 MPIR amounts totaling $21.8 million, including revenue taxes, for the Schofield Generating Station ($17.6 million), West Loch PV Project ($3.3 million), and Grid Modernization Strategy (GMS) Phase 1 project ($0.9 million for all three utilities) for the accrual of revenues effective January 1, 2021, that included the 2021
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return on project amount (based on approved amounts) in rate base, depreciation and incremental O&M expenses. Under the PBR framework, the Utilities began recovery of the annualized 2021 MPIR amounts effective June 1, 2021 through the RBA rate adjustment.
On September 27, 2021, the PUC issued an order rejecting the Utilities’ August 31, 2021 request to update target revenues resulting from the GMS Phase 1 Meter Data Management System (MDMS) deferred software go‑live and completion of implementation through July 2021, as it inappropriately relied on an automatic approval provision in Hawaii Administrative Rules. The PUC did not rule on the merits of the Utilities’ request and offered the Utilities to file an amended request as soon as practicable. On October 7, 2021, the Utilities filed an amended request, requesting PUC approval of RBA tariff sheets reflecting the change to target revenues associated with the GMS Phase 1 MDMS deferred software go-live and completion of implementation through July 2021.
Exceptional project recovery mechanism. Under the PBR Framework, the existing MPIR adjustment mechanism was renamed EPRM to include deferred and O&M expense projects and to permit the Utilities to include the full amount of approved costs in the EPRM for recovery in the first year the project goes into service, pro-rated for the portion of the year the project is in service. Any pending application for MPIR relief submitted by the Utilities prior to the PBR D&O will be grandfathered under the MPIR Guidelines. The Utilities may alternatively request that pending MPIR applications be reviewed under EPRM Guidelines. EPRM recovery will be in accordance with the EPRM Guidelines limited to the lesser of actual incurred project costs or PUC-approved amounts, net of savings. Currently, the Utilities are seeking EPRM recovery of eight projects with total project costs of $324 million, subject to PUC approval.
Pilot process. The PBR D&O approved a Pilot Process to foster innovation by establishing an expedited implementation process for pilots that test new technologies, programs, business models, and other arrangements. This is intended to support initiatives by the Utilities to test new programs and ideas quickly and elevate any successful pilots for consideration of full-scale implementation. The proposed pilots would be subject to PUC approval with a total annual cap of $10 million. The Pilot Process will feature the two primary activities: an initial “Workplan Development” phase, during which the Utilities identify and scope areas of interests, so as to inform the subsequent “Implementation” phase, during which the Utilities submit specific pilot proposals for expedited review by the PUC and implement the pilot upon approval. The PUC will issue an order, approving, denying, or modifying a proposed Pilot within 45 days of receiving notice of a specific pilot project.
On July 9, 2021, the PUC issued an order approving the Utilities’ proposed Pilot Process submitted in April 2021 with modifications, including a cost recovery process that generally allows the Utilities to defer and recover total annual expenditures of approved pilot projects in full over twelve months beginning June 1 of the year following implementation through the RBA rate adjustment, although the Utilities may determine on a case-by-case basis that a particular project’s deferred costs should be amortized over a period greater than twelve months. On July 28, 2021, the Utilities submitted the finalized Pilot Process to govern the review of the pilot project proposals in accordance with the July 9, 2021 order.
Performance incentive mechanisms. The PUC has established the following PIMs: (1) Service Quality performance incentives, (2) Phase 1 Request for proposal (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 shall remain constant in interim periods, unless otherwise amended by order of the PUC.
•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 2020, the Utilities accrued $0.9 million in estimated rewards for call center performance, net of service reliability penalties, for 2020. The net service quality performance rewards related to 2020 was reflected in the 2021
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annual decoupling filing which was approved by the PUC on May 26, 2021, resulting in an increase to customer rates effective June 1, 2021.
•Phase 1 RFP PIM. Procurement of low-cost variable renewable resources through the RFP process in 2018 is measured by comparison of the procurement price to target prices. Half of the incentive was earned upon PUC approval of the PPAs. Based on the seven PPAs approved in 2019, the Utilities recognized $1.7 million in 2019 with the remaining award to be recognized in the year following the in-service date of the projects, which is estimated to occur from 2023 to 2024.
•Phase 2 RFP PIMs. The PUC order issued on October 9, 2019 establishes pricing thresholds, timelines to complete contracting, and other performance criteria for the performance incentive eligibility. The PIMs provide incentives only without penalties. 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 that potentially qualify for a demand response PIM, however, details of the incentive metrics will be determined by the 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. On February 16, 2021, the Utilities filed one additional power purchase agreement that qualifies for the declining PIM, which was approved on September 15, 2021. The first allocation of incentives is earned upon PUC approval of the contact and the remaining PIM allocations begin after the project achieves commercial operations and are earned based on delivered energy for the prior year, through 2025. The Utilities accrued $0.1 million in incentives in September 2021. On December 31, 2020, the PUC approved the two Grid Services Purchase Agreements without further clarification regarding the demand response PIM. The Utility filed a letter in January 2021 with the PUC seeking guidance on the next steps to define the demand response incentive metric details.
•The PUC established the following two new PIMs in its PBR D&O, which were approved in an order issued on March 23, 2021 and became effective on June 1, 2021.
•Renewable portfolio standard (RPS)-A PIM that provides a financial reward for accelerating the achievement of RPS goals. The Utilities may earn a reward for the amount of system generation above the interpolated statutory RPS goal at $20/MWh in 2021 and 2022, $15/MWh in 2023, and $10/MWh for the remainder of the multi-year rate period (MRP). Penalties are already prescribed in the RPS as $20/MWh for failing to meet RPS targets in 2030, 2040 and 2045. The evaluation period commenced on January 1, 2021.
•Grid Services Procurement PIM that provides financial rewards for grid services acquired in 2021 and 2022. The Utilities can earn a total maximum reward of $1.5 million over 2021 and 2022. The evaluation period commenced on January 1, 2021.
•The PUC also established the following three new PIMs in its PBR D&O, which were approved by the PUC on May 17, 2021 and became effective on June 1, 2021.
•Interconnection Approval PIM that provides financial rewards and penalties for interconnection times for distributed energy resources systems <100 kW in size. The Utilities can earn a total annual maximum reward of $3.0 million or a total annual maximum penalty of $0.9 million. The evaluation period commenced on January 1, 2021.
•Low-to-Moderate Income (LMI) Energy Efficiency PIM that provides financial reward for collaboration between the Utilities and the third-party Public Benefits Fee Administrator to deliver energy savings for low- and moderate-income customers. The Utilities can earn a total annual maximum reward of $2.0 million. The PIM will initially have a duration of three years and be subject to an annual review. The evaluation period is based on Hawaii Energy’s program year with the initial evaluation year being the period of July 1, 2021 through June 30, 2022.
•Advanced Metering Infrastructure Utilization PIM that provides financial rewards for leveraging grid modernization investments and engaging customers beyond what is already planned in the Phase 1 Grid Modernization program. The Utilities can earn a total annual maximum reward of $2.0 million. The PIM will initially have a duration of three years after which it will be re-evaluated. The evaluation period commenced on January 1, 2021.
Annual review cycle. PBR D&O established an annual review cycle for revenue adjustments under the PBR Framework, including the biannual submission of the revenue reports. The Utilities filed the fall revenue report on October 29,
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2021, which is subject to PUC approval. The filing reflected ARA revenues for 2022 to be collected from January 1 through December 31, 2022, as follows:
(in millions)Hawaiian ElectricHawaii Electric LightMaui ElectricTotal
2022 ARA revenues$19.8 $4.9 $4.8 $29.5 
Management Audit savings commitment(4.6)(1.0)(1.0)(6.6)
Net 2022 ARA revenues$15.2 $3.9 $3.8 $22.9 

The proposed net incremental amounts between the 2021 spring and fall revenue reports are as follows. The amounts are to be collected (refunded) from January 1 through December 31, 2022 under the RBA rate tariffs, which was proposed in the 2021 fall revenue report filing and is subject to PUC approval.
(in millions)Hawaiian ElectricHawaii Electric LightMaui ElectricTotal
Incremental RAM revenues and ARA revenues$41.7 $8.9 $10.9 $61.5 
Incremental accrued RBA balance through September 30, 2021 (and associated revenue taxes)21.9 2.5 (0.1)24.3 
Incremental Performance Incentive Mechanisms (net)
— — 0.1 0.1 
Incremental MPIR/EPRM Revenue Adjustment9.8 0.3 0.3 10.4
Net incremental amount to be collected under the RBA rate tariffs$73.4 $11.7 $11.1 $96.2 
Note: Columns may not foot due to rounding.
Most recent rate proceedings.
Hawaiian Electric 2020 test year rate case. 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 an authorized 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. See “Annual revenue adjustment mechanism” under “Performance-based regulation framework” above, regarding the PUC’s decision on the treatment of Hawaiian Electric’s Management Audit savings commitment. Hawaiian Electric’s proposed RBA provision tariff and ECRC tariff submitted on November 6, 2020 were approved by the PUC on December 11, 2020 and took effect on January 1, 2021.
Hawaii Electric Light 2019 test year rate case. 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 authorized 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. The proposed final tariffs and PIM tariffs took effect on November 1, 2020, and the ECRC tariff took effect on January 1, 2021.
Regulatory assets for COVID-19 related costs. 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 costs through December 31, 2020. On October 1, 2021, the PUC approved the Utilities’ request to extend the deferral period to December 31, 2021. The Utilities are required to file quarterly reports to update the Utilities’ financial condition, report measures in place to assist their customers during the COVID-19 emergency situation, identify the planned deferred costs and details for the deferred costs, and identify 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 and management believes the deferred costs are probable of recovery. In addition, starting in December 2020 and monthly moving forward until otherwise ordered by the PUC, the Utilities are required to file information on, among other things, number of customers, arrears balances, payment arrangements entered into, and available assistance used to assist customer bill payments. The monthly report is intended to assist the PUC in determining next
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
steps regarding appropriate regulatory measures. As of September 30, 2021, the Utilities recorded a total of $28.7 million in regulatory assets pursuant to the orders.
Collective bargaining agreement. As of September 30, 2021, approximately 47% of the Utilities’ employees are members of the International Brotherhood of Electrical Workers, AFL-CIO, Local 1260. The current collective bargaining agreement with the union that was set to expire on October 31, 2021 was extended to January 3, 2022. The Utilities continue to renegotiate the contract with the union.
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, 2021 and 2020, and as of September 30, 2021 and December 31, 2020.
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.
20

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Three months ended September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other subsidiaries
Consolidating adjustments
Hawaiian Electric
Consolidated
Revenues$478,046 100,313 101,141 — (1)$679,499 
Expenses
Fuel oil126,909 21,104 32,669 — — 180,682 
Purchased power136,688 31,159 17,912 — — 185,759 
Other operation and maintenance75,191 19,964 21,313 — — 116,468 
Depreciation38,912 10,050 8,424 — — 57,386 
Taxes, other than income taxes45,239 9,333 9,440 — — 64,012 
   Total expenses422,939 91,610 89,758 — — 604,307 
Operating income55,107 8,703 11,383 — (1)75,192 
Allowance for equity funds used during construction1,999 131 297 — — 2,427 
Equity in earnings of subsidiaries12,028 — — — (12,028)— 
Retirement defined benefits expense—other than service costs741 166 (30)— — 877 
Interest expense and other charges, net(12,943)(2,590)(2,616)— 1 (18,148)
Allowance for borrowed funds used during construction676 44 107 — — 827 
Income before income taxes57,608 6,454 9,141 — (12,028)61,175 
Income taxes6,996 1,433 1,906 — — 10,335 
Net income50,612 5,021 7,235 — (12,028)50,840 
Preferred stock dividends of subsidiaries— 133 95 — — 228 
Net income attributable to Hawaiian Electric
50,612 4,888 7,140 — (12,028)50,612 
Preferred stock dividends of Hawaiian Electric270 — — — — 270 
Net income for common stock$50,342 4,888 7,140 — (12,028)$50,342 


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Three months ended September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net income for common stock$50,342 4,888 7,140 — (12,028)$50,342 
Other comprehensive income, 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 benefits2,905 393 393 — (786)2,905 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes(2,799)(391)(393)— 784 (2,799)
Other comprehensive income, net of taxes106 2 — — (2)106 
Comprehensive income attributable to common shareholder
$50,448 4,890 7,140 — (12,030)$50,448 


21

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

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 



22

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Nine months ended September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiariesConsolidating adjustmentsHawaiian Electric
Consolidated
Revenues$1,301,297 276,974 267,992 — (21)$1,846,242 
Expenses
Fuel oil306,982 57,175 83,088 — — 447,245 
Purchased power370,240 76,992 43,288 — — 490,520 
Other operation and maintenance230,429 57,350 61,401 — — 349,180 
Depreciation116,733 30,151 25,238 — — 172,122 
Taxes, other than income taxes124,167 25,865 25,153 — — 175,185 
   Total expenses1,148,551 247,533 238,168 — — 1,634,252 
Operating income152,746 29,441 29,824 — (21)211,990 
Allowance for equity funds used during construction5,677 403 915 — — 6,995 
Equity in earnings of subsidiaries35,282 — — — (35,282)— 
Retirement defined benefits expense—other than service costs2,511 503 (96)— — 2,918 
Interest expense and other charges, net(38,604)(7,744)(7,799)— 21 (54,126)
Allowance for borrowed funds used during construction1,921 136 329 — — 2,386 
Income before income taxes159,533 22,739 23,173 — (35,282)170,163 
Income taxes23,122 5,152 4,792 — — 33,066 
Net income136,411 17,587 18,381 — (35,282)137,097 
Preferred stock dividends of subsidiaries— 400 286 — — 686 
Net income attributable to Hawaiian Electric136,411 17,187 18,095 — (35,282)136,411 
Preferred stock dividends of Hawaiian Electric810 — — — — 810 
Net income for common stock$135,601 17,187 18,095 — (35,282)$135,601 


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Nine months ended September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiariesConsolidating adjustmentsHawaiian Electric Consolidated
Net income for common stock$135,601 17,187 18,095 — (35,282)$135,601 
Other comprehensive income, 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 taxes14,596 2,062 1,915 — (3,977)14,596 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes(14,421)(2,059)(1,915)— 3,974 (14,421)
Other comprehensive income, net of taxes175 3 — — (3)175 
Comprehensive income attributable to common shareholder$135,776 17,190 18,095 — (35,285)$135,776 

23

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 

24

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Balance Sheet
September 30, 2021
(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$42,410 5,606 3,594 — — $51,610 
Plant and equipment5,063,487 1,375,782 1,230,451 — — 7,669,720 
Less accumulated depreciation(1,766,707)(619,003)(562,005)— — (2,947,715)
Construction in progress172,417 17,966 31,135 — — 221,518 
Utility property, plant and equipment, net3,511,607 780,351 703,175 — — 4,995,133 
Nonutility property, plant and equipment, less accumulated depreciation
5,303 115 1,532 — — 6,950 
Total property, plant and equipment, net3,516,910 780,466 704,707 — — 5,002,083 
Investment in wholly owned subsidiaries, at equity639,900 — — — (639,900)— 
Current assets      
Cash and cash equivalents25,981 3,788 6,621 77 — 36,467 
Restricted cash6,313 — — — — 6,313 
Advances to affiliates700 — — — (700)— 
Customer accounts receivable, net118,776 29,371 26,090 — — 174,237 
Accrued unbilled revenues, net93,949 17,660 17,470 — — 129,079 
Other accounts receivable, net20,732 3,843 3,616 — (22,075)6,116 
Fuel oil stock, at average cost71,072 13,079 16,650 — — 100,801 
Materials and supplies, at average cost43,094 10,107 19,796 — — 72,997 
Prepayments and other41,706 5,232 7,023 — — 53,961 
Regulatory assets47,004 2,966 6,254 — — 56,224 
Total current assets469,327 86,046 103,520 77 (22,775)636,195 
Other long-term assets      
Operating lease right-of-use assets96,026 23,271 327 — — 119,624 
Regulatory assets489,746 108,093 103,141 — — 700,980 
Other112,298 19,008 18,448 — (5,728)144,026 
Total other long-term assets698,070 150,372 121,916 — (5,728)964,630 
Total assets$5,324,207 1,016,884 930,143 77 (668,403)$6,602,908 
Capitalization and liabilities      
Capitalization      
Common stock equity$2,193,919 323,691 316,132 77 (639,900)$2,193,919 
Cumulative preferred stock—not subject to mandatory redemption
22,293 7,000 5,000 — — 34,293 
Long-term debt, net1,176,477 246,360 253,386 — — 1,676,223 
Total capitalization3,392,689 577,051 574,518 77 (639,900)3,904,435 
Current liabilities      
Current portion of operating lease liabilities61,505 3,354 35 — — 64,894 
Short-term borrowings from affiliate— 700 — — (700)— 
Accounts payable101,685 24,640 20,550 — — 146,875 
Interest and preferred dividends payable20,390 3,750 4,471 — (1)28,610 
Taxes accrued, including revenue taxes136,016 31,338 29,014 — — 196,368 
Regulatory liabilities21,257 4,164 6,840 — — 32,261 
Other71,738 14,488 20,503 — (22,223)84,506 
Total current liabilities412,591 82,434 81,413 — (22,924)553,514 
Deferred credits and other liabilities      
Operating lease liabilities47,585 19,917 300 — — 67,802 
Deferred income taxes284,245 51,822 60,486 — — 396,553 
Regulatory liabilities672,712 177,877 92,662 — — 943,251 
Unamortized tax credits78,215 14,577 13,586 — — 106,378 
Defined benefit pension and other postretirement benefit plans liability
364,749 74,183 76,619 — (5,579)509,972 
Other71,421 19,023 30,559 — — 121,003 
Total deferred credits and other liabilities1,518,927 357,399 274,212 — (5,579)2,144,959 
Total capitalization and liabilities$5,324,207 1,016,884 930,143 77 (668,403)$6,602,908 

25

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Balance Sheet
December 31, 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$42,411 5,606 3,594 — — $51,611 
Plant and equipment4,960,470 1,352,885 1,195,988 — — 7,509,343 
Less accumulated depreciation(1,677,256)(597,606)(544,217)— — (2,819,079)
Construction in progress143,616 13,043 31,683 — — 188,342 
Utility property, plant and equipment, net3,469,241 773,928 687,048 — — 4,930,217 
Nonutility property, plant and equipment, less accumulated depreciation
5,306 115 1,532 — — 6,953 
Total property, plant and equipment, net3,474,547 774,043 688,580 — — 4,937,170 
Investment in wholly owned subsidiaries, at equity
626,890 — — — (626,890)— 
Current assets      
Cash and cash equivalents42,205 3,046 2,032 77 — 47,360 
Restricted cash15,966 — — — — 15,966 
Advances to affiliates26,700 — — — (26,700)— 
Customer accounts receivable, net102,736 23,989 21,107 — — 147,832 
Accrued unbilled revenues, net73,628 13,631 13,777 — — 101,036 
Other accounts receivable, net17,984 3,028 2,856 — (16,195)7,673 
Fuel oil stock, at average cost38,777 8,471 10,990 — — 58,238 
Materials and supplies, at average cost38,786 9,896 18,662 — — 67,344 
Prepayments and other34,306 5,197 4,580 — — 44,083 
Regulatory assets22,095 1,954 6,386 — — 30,435 
Total current assets413,183 69,212 80,390 77 (42,895)519,967 
Other long-term assets      
Operating lease right-of-use assets125,858 1,443 353 — — 127,654 
Regulatory assets513,192 114,461 108,620 — — 736,273 
Other98,307 17,992 20,010 — — 136,309 
Total other long-term assets737,357 133,896 128,983 — — 1,000,236 
Total assets$5,251,977 977,151 897,953 77 (669,785)$6,457,373 
Capitalization and liabilities      
Capitalization
Common stock equity$2,141,918 317,451 309,363 77 (626,891)$2,141,918 
Cumulative preferred stock—not subject to mandatory redemption
22,293 7,000 5,000 — — 34,293 
Long-term debt, net1,116,426 216,447 228,429 — — 1,561,302 
Total capitalization3,280,637 540,898 542,792 77 (626,891)3,737,513 
Current liabilities     
Current portion of operating lease liabilities64,599 98 33 — — 64,730 
Short-term borrowings-non-affiliate49,979 — — — — 49,979 
Short-term borrowings-affiliate— 18,800 7,900 — (26,700)— 
Accounts payable97,102 19,570 17,177 — — 133,849 
Interest and preferred dividends payable14,480 3,138 2,790 — (58)20,350 
Taxes accrued, including revenue taxes135,018 29,869 27,637 — — 192,524 
Regulatory liabilities20,224 8,785 8,292 — — 37,301 
Other57,926 13,851 18,621 — (16,136)74,262 
Total current liabilities439,328 94,111 82,450 — (42,894)572,995 
Deferred credits and other liabilities     
Operating lease liabilities67,824 1,344 326 — — 69,494 
Deferred income taxes282,685 54,108 61,005 — — 397,798 
Regulatory liabilities656,270 173,938 92,277 — — 922,485 
Unamortized tax credits82,563 15,363 13,989 — — 111,915 
Defined benefit pension and other postretirement benefit plans liability
373,112 77,679 79,741 — — 530,532 
Other69,558 19,710 25,373 — — 114,641 
Total deferred credits and other liabilities1,532,012 342,142 272,711 — — 2,146,865 
Total capitalization and liabilities$5,251,977 977,151 897,953 77 (669,785)$6,457,373 

26

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, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Balance, December 31, 2020$2,141,918 317,451 309,363 77 (626,891)$2,141,918 
Net income for common stock135,601 17,187 18,095 — (35,282)135,601 
Other comprehensive income, net of taxes175 3 — — (3)175 
Common stock dividends(83,775)(10,950)(11,326)— 22,276 (83,775)
Balance, September 30, 2021$2,193,919 323,691 316,132 77 (639,900)$2,193,919 
 
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 

27

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, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net cash provided by operating activities$157,191 32,698 30,643 — (22,276)$198,256 
Cash flows from investing activities      
Capital expenditures(137,916)(33,511)(32,319)— — (203,746)
Advances from affiliates26,000 — — — (26,000)— 
Other4,136 1,121 900 — — 6,157 
Net cash used in investing activities(107,780)(32,390)(31,419)— (26,000)(197,589)
Cash flows from financing activities      
Common stock dividends(83,775)(10,950)(11,326)— 22,276 (83,775)
Preferred stock dividends of Hawaiian Electric and subsidiaries(810)(400)(286)— — (1,496)
Repayment of short-term debt(50,000)— — — — (50,000)
Proceeds from issuance of long-term debt60,000 30,000 25,000 — — 115,000 
Net decrease in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less— (18,100)(7,900)— 26,000 — 
Other(703)(116)(123)— — (942)
Net cash provided by (used in) financing activities(75,288)434 5,365 — 48,276 (21,213)
Net increase (decrease) in cash and cash equivalents(25,877)742 4,589 — — (20,546)
Cash, cash equivalents and restricted cash, beginning of period58,171 3,046 2,032 77 — 63,326 
Cash, cash equivalents and restricted cash, end of period32,294 3,788 6,621 77 — 42,780 
Less: Restricted cash(6,313)— — — — (6,313)
Cash and cash equivalents, end of period$25,981 3,788 6,621 77 — $36,467 

28

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 (used in) 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 

29

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)2021202020212020
Interest and dividend income    
Interest and fees on loans$49,445 $52,419 $150,418 $161,505 
Interest and dividends on investment securities11,996 7,221 31,709 22,939 
Total interest and dividend income61,441 59,640 182,127 184,444 
Interest expense    
Interest on deposit liabilities1,176 2,287 3,919 8,945 
Interest on other borrowings5 61 55 449 
Total interest expense1,181 2,348 3,974 9,394 
Net interest income60,260 57,292 178,153 175,050 
Provision for credit losses(1,725)13,970 (22,367)39,504 
Net interest income after provision for credit losses61,985 43,322 200,520 135,546 
Noninterest income    
Fees from other financial services4,800 4,233 15,337 11,906 
Fee income on deposit liabilities4,262 3,832 12,029 11,842 
Fee income on other financial products2,124 1,524 6,767 4,608 
Bank-owned life insurance2,026 1,965 6,211 4,432 
Mortgage banking income1,272 7,681 7,497 15,933 
Gain on sale of investment securities, net— — 528 9,275 
Other income, net283 (231)631 (69)
Total noninterest income14,767 19,004 49,000 57,927 
Noninterest expense    
Compensation and employee benefits30,888 26,431 86,595 77,287 
Occupancy5,157 5,693 15,226 16,402 
Data processing4,278 3,366 13,162 11,052 
Services2,272 2,624 7,609 7,907 
Equipment2,373 2,001 6,989 6,630 
Office supplies, printing and postage1,072 1,187 3,094 3,577 
Marketing995 727 2,308 1,908 
FDIC insurance808 714 2,412 1,567 
Other expense1
3,668 4,556 9,790 15,813 
Total noninterest expense51,511 47,299 147,185 142,143 
Income before income taxes25,241 15,027 102,335 51,330 
Income taxes5,976 2,877 23,230 9,405 
Net income19,265 12,150 79,105 41,925 
Other comprehensive income (loss), net of taxes(11,684)1,393 (40,439)20,960 
Comprehensive income $7,581 $13,543 $38,666 $62,885 

1 The three- and nine-month periods ended September 30, 2021 include approximately $0.1 million and $0.5 million, respectively, of certain direct and incremental COVID-19 related costs. The three and nine-month periods ended September 30, 2020 include approximately $0.7 million and $4.5 million, respectively, of certain significant direct and incremental COVID-19 related costs. These costs for the first nine months of 2020, which have been recorded in Other expense, include $2.4 million of compensation expense and $1.7 million of enhanced cleaning and sanitation costs.
30

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)2021202020212020
Interest and dividend income$61,441 $59,640 $182,127 $184,444 
Noninterest income14,767 19,004 49,000 57,927 
Less: Gain on sale of investment securities, net— — 528 9,275 
*Revenues-Bank76,208 78,644 230,599 233,096 
Total interest expense1,181 2,348 3,974 9,394 
Provision for credit losses(1,725)13,970 (22,367)39,504 
Noninterest expense51,511 47,299 147,185 142,143 
Less: Retirement defined benefits expense (credit)—other than service costs(184)473 (1,648)1,341 
*Expenses-Bank51,151 63,144 130,440 189,700 
*Operating income-Bank25,057 15,500 100,159 43,396 
Add back: Retirement defined benefits expense (credit)—other than service costs(184)473 (1,648)1,341 
Add back: Gain on sale of investment securities, net— — 528 9,275 
Income before income taxes$25,241 $15,027 $102,335 $51,330 


31

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
American Savings Bank, F.S.B.
Balance Sheets Data
(in thousands)September 30, 2021December 31, 2020
Assets    
Cash and due from banks $109,942  $178,422 
Interest-bearing deposits80,007 114,304 
Cash and cash equivalents189,949 292,726 
Investment securities
Available-for-sale, at fair value 2,580,830  1,970,417 
Held-to-maturity, at amortized cost (fair value of $484,654 and $229,963, respectively)
491,871 226,947 
Stock in Federal Home Loan Bank, at cost 10,000  8,680 
Loans held for investment 5,122,124  5,333,843 
Allowance for credit losses (75,944) (101,201)
Net loans 5,046,180  5,232,642 
Loans held for sale, at lower of cost or fair value 53,998  28,275 
Other 555,401  554,656 
Goodwill 82,190  82,190 
Total assets $9,010,419  $8,396,533 
Liabilities and shareholder’s equity    
Deposit liabilities—noninterest-bearing $2,931,394  $2,598,500 
Deposit liabilities—interest-bearing 5,045,144  4,788,457 
Other borrowings 129,305  89,670 
Other 168,064  183,731 
Total liabilities 8,273,907  7,660,358 
  
Common stock 1  1 
Additional paid-in capital353,429 351,758 
Retained earnings 408,575  369,470 
Accumulated other comprehensive income (loss), net of taxes    
Net unrealized gains (losses) on securities$(20,322) $19,986 
Retirement benefit plans(5,171)(25,493)(5,040)14,946 
Total shareholder’s equity736,512  736,175 
Total liabilities and shareholder’s equity $9,010,419  $8,396,533 
Other assets    
Bank-owned life insurance $166,486  $163,265 
Premises and equipment, net 205,624  206,134 
Accrued interest receivable 22,036  24,616 
Mortgage-servicing rights 10,272  10,020 
Low-income housing investments84,728 83,435 
Other 66,255  67,186 
  $555,401  $554,656 
Other liabilities    
Accrued expenses $59,270  $62,694 
Federal and state income taxes payable —  6,582 
Cashier’s checks 37,451  38,011 
Advance payments by borrowers 5,129  10,207 
Other 66,214  66,237 
  $168,064  $183,731 
    
32

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 of $129.3 million and $89.7 million at September 30, 2021 and December 31, 2020, respectively.
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, 2021        
Available-for-sale
U.S. Treasury and federal agency obligations$90,831 $1,334 $(90)$92,075 1 $19,851 $(90)— $— $— 
Mortgage-backed securities*2,471,650 11,193 (41,160)2,441,683 105 1,772,753 (36,561)9 123,882 (4,599)
Corporate bonds30,684 961 — 31,645 — — — — — — 
Mortgage revenue bonds15,427 — — 15,427 — — — — — — 
 $2,608,592 $13,488 $(41,250)$2,580,830 106 $1,792,604 $(36,651)9 $123,882 $(4,599)
Held-to-maturity
U.S. Treasury and Federal agency obligations$40,064 $100 $(13)$40,151 1 $19,941 $(13)— $— $— 
Mortgage-backed securities*451,807 2,387 (9,691)444,503 23 325,907 (8,278)2 23,860 (1,413)
 $491,871 $2,487 $(9,704)$484,654 24 $345,848 $(8,291)2 $23,860 $(1,413)
December 31, 2020
Available-for-sale
U.S. Treasury and federal agency obligations$60,260 $2,062 $— $62,322 — $— $— — $— $— 
Mortgage-backed securities*1,825,893 26,817 (3,151)1,849,559 22 373,924 (3,151)— — — 
Corporate bonds29,776 1,575 — 31,351 — — — — — — 
Mortgage revenue bonds27,185 — — 27,185 — — — — — — 
 $1,943,114 $30,454 $(3,151)$1,970,417 22 $373,924 $(3,151)— $— $— 
Held-to-maturity
Mortgage-backed securities* $226,947 $3,846 $(830)$229,963 7 $114,152 $(830)— $— $— 
 $226,947 $3,846 $(830)$229,963 7 $114,152 $(830)— $— $— 
* 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, 2021 and December 31, 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, 2021 and December 31, 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.
33

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The contractual maturities of investment securities were as follows:
September 30, 2021Amortized costFair value
(in thousands)  
Available-for-sale
Due in one year or less$— $— 
Due after one year through five years76,247 78,071 
Due after five years through ten years45,268 45,649 
Due after ten years15,427 15,427 
 136,942 139,147 
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies2,471,650 2,441,683 
Total available-for-sale securities$2,608,592 $2,580,830 
Held-to-maturity
Due in one year or less$— $— 
Due after one year through five years— — 
Due after five years through ten years40,064 40,151 
Due after ten years— — 
40,064 40,151 
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies451,807 444,503 
Total held-to-maturity securities$491,871 $484,654 
The proceeds, gross gains and losses from sales of available-for-sale securities were as follows:
Three months ended September 30Nine months ended September 30
2021202020212020
(in thousands)
Proceeds $— $— $197,354 $169,157 
Gross gains — — 975 9,312 
Gross losses— — 447 37 
Tax expense on realized gains— — 142 2,492 
The components of loans were summarized as follows:
September 30, 2021December 31, 2020
(in thousands)  
Real estate:  
Residential 1-4 family$2,172,073 $2,144,239 
Commercial real estate1,090,816 983,865 
Home equity line of credit851,416 963,578 
Residential land19,399 15,617 
Commercial construction109,716 121,424 
Residential construction9,170 11,022 
Total real estate4,252,590 4,239,745 
Commercial758,338 936,748 
Consumer122,656 168,733 
Total loans5,133,584 5,345,226 
Less: Deferred fees and discounts(11,460)(11,383)
          Allowance for credit losses (75,944)(101,201)
Total loans, net$5,046,180 $5,232,642 
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
34

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
property purchases, the loan-to-value ratio may not exceed 75% of the lower of the appraised value or purchase price at origination.
Allowance for credit losses.  The allowance for credit losses (balances and changes) 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, 2021        
Allowance for credit losses:         
Beginning balance$5,518 $28,708 $5,335 $618 $1,629 $16 $20,058 $16,370 $78,252 
Charge-offs(47)— (5)— — — (266)(1,597)(1,915)
Recoveries5 — 7 35 — — 417 1,118 1,582 
Provision522 (2,750)441 (19)104 (3)(758)488 (1,975)
Ending balance$5,998 $25,958 $5,778 $634 $1,733 $13 $19,451 $16,379 $75,944 
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 
Nine months ended September 30, 2021        
Allowance for credit losses:         
Beginning balance$4,600 $35,607 $6,813 $609 $4,149 $11 $25,462 $23,950 $101,201 
Charge-offs(67)— (45)— — — (1,356)(6,388)(7,856)
Recoveries59 — 83 56 — — 1,056 3,312 4,566 
Provision1,406 (9,649)(1,073)(31)(2,416)2 (5,711)(4,495)(21,967)
Ending balance$5,998 $25,958 $5,778 $634 $1,733 $13 $19,451 $16,379 $75,944 
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. 2016-132,150 208 (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 

35

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, 2021
Allowance for loan commitments:
Beginning balance$400 $2,400 $850 $3,650 
Provision— 300 (50)250 
Ending balance$400 $2,700 $800 $3,900 
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, 2021
Allowance for loan commitments:
Beginning balance$300 $3,000 $1,000 $4,300 
Provision100 (300)(200)(400)
Ending balance$400 $2,700 $800 $3,900 
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.
36

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)20212020201920182017PriorRevolvingConverted to term loansTotal
September 30, 2021
Residential 1-4 family
Current$541,140 $471,759 $150,704 $75,827 $142,235 $778,048 $— $— $2,159,713 
30-59 days past due— — — — — 2,224 — — 2,224 
60-89 days past due— 276 — — — 1,308 — — 1,584 
Greater than 89 days past due— — 3,949 424 — 4,179 — — 8,552 
541,140 472,035 154,653 76,251 142,235 785,759 — — 2,172,073 
Home equity line of credit
Current— — — — — — 809,566 39,932 849,498 
30-59 days past due— — — — — — 126 129 255 
60-89 days past due— — — — — — 107 101 208 
Greater than 89 days past due— — — — — — 1,029 426 1,455 
— — — — — — 810,828 40,588 851,416 
Residential land
Current8,905 7,341 1,659 647 268 182 — — 19,002 
30-59 days past due— — — — — 97 — — 97 
60-89 days past due— — — — — — — — — 
Greater than 89 days past due— — — — — 300 — — 300 
8,905 7,341 1,659 647 268 579 — — 19,399 
Residential construction
Current4,664 4,238 — — 268 — — — 9,170 
30-59 days past due— — — — — — — — — 
60-89 days past due— — — — — — — — — 
Greater than 89 days past due— — — — — — — — — 
4,664 4,238 — — 268 — — — 9,170 
Consumer
Current27,059 18,662 38,546 16,378 907 283 13,745 3,819 119,399 
30-59 days past due206 152 523 282 21 — 126 117 1,427 
60-89 days past due24 58 368 198 43 — 61 28 780 
Greater than 89 days past due29 140 396 158 44 — 149 134 1,050 
27,318 19,012 39,833 17,016 1,015 283 14,081 4,098 122,656 
Commercial real estate
Pass142,977 278,941 62,907 60,174 55,824 257,110 11,288 — 869,221 
Special Mention1,360 4,237 34,617 46,447 23,027 42,850 — — 152,538 
Substandard— — 14,021 1,872 1,838 51,326 — — 69,057 
Doubtful— — — — — — — — — 
144,337 283,178 111,545 108,493 80,689 351,286 11,288 — 1,090,816 
Commercial construction
Pass11,225 39,137 25,913 11,342 — — 22,099 — 109,716 
Special Mention— — — — — — — — — 
Substandard— — — — — — — — — 
Doubtful— — — — — — — — — 
11,225 39,137 25,913 11,342 — — 22,099 — 109,716 
Commercial
Pass218,541 112,545 78,076 53,829 19,043 60,661 93,979 16,334 653,008 
Special Mention52 27,498 11,810 279 2,682 19,495 20,459 21 82,296 
Substandard427 214 4,273 1,824 5,318 3,188 5,845 1,945 23,034 
Doubtful— — — — — — — — — 
219,020 140,257 94,159 55,932 27,043 83,344 120,283 18,300 758,338 
Total loans$956,609 $965,198 $427,762 $269,681 $251,518 $1,221,251 $978,579 $62,986 $5,133,584 
37

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Term Loans by Origination YearRevolving Loans
(in thousands)20202019201820172016PriorRevolvingConverted to term loansTotal
December 31, 2020
Residential 1-4 family
Current$567,282 $218,988 $111,243 $203,916 $184,888 $849,788 $— $— $2,136,105 
30-59 days past due— — — — — 2,629 — — 2,629 
60-89 days past due— 476 — — — 2,314 — — 2,790 
Greater than 89 days past due— — — 353 — 2,362 — — 2,715 
567,282 219,464 111,243 204,269 184,888 857,093 — — 2,144,239 
Home equity line of credit
Current— — — — — — 927,106 33,228 960,334 
30-59 days past due— — — — — — 552 298 850 
60-89 days past due— — — — — — 267 75 342 
Greater than 89 days past due— — — — — — 1,463 589 2,052 
— — — — — — 929,388 34,190 963,578 
Residential land
Current8,357 3,427 1,598 939 22 272 — — 14,615 
30-59 days past due— — — — — 702 — — 702 
60-89 days past due— — — — — — — — — 
Greater than 89 days past due— — — — — 300 — — 300 
8,357 3,427 1,598 939 22 1,274 — — 15,617 
Residential construction
Current6,919 3,093 385 625 — — — — 11,022 
30-59 days past due— — — — — — — — — 
60-89 days past due— — — — — — — — — 
Greater than 89 days past due— — — — — — — — — 
6,919 3,093 385 625 — — — — 11,022 
Consumer
Current28,818 67,159 37,072 7,207 293 348 18,351 3,758 163,006 
30-59 days past due406 1,085 727 155 4 — 138 90 2,605 
60-89 days past due191 549 427 165 3 — 97 59 1,491 
Greater than 89 days past due131 532 409 119 7 — 262 171 1,631 
29,546 69,325 38,635 7,646 307 348 18,848 4,078 168,733 
Commercial real estate
Pass270,603 63,301 62,168 28,432 55,089 155,654 11,000 — 646,247 
Special Mention10,261 36,405 57,952 33,763 68,287 48,094 — — 254,762 
Substandard— 14,720 4,181 1,892 4,423 57,640 — — 82,856 
Doubtful— — — — — — — — — 
280,864 114,426 124,301 64,087 127,799 261,388 11,000 — 983,865 
Commercial construction
Pass14,480 31,965 26,990 — 5,562 — 22,517 — 101,514 
Special Mention1,910 — — 18,000 — — — — 19,910 
Substandard— — — — — — — — — 
Doubtful— — — — — — — — — 
16,390 31,965 26,990 18,000 5,562 — 22,517 — 121,424 
Commercial
Pass392,088 117,791 75,533 29,211 12,520 35,770 74,520 11,004 748,437 
Special Mention37,836 23,087 1,920 6,990 30,264 13,250 31,362 11,218 155,927 
Substandard304 7,785 2,043 4,017 7,542 3,113 5,265 1,928 31,997 
Doubtful— — — — — — 387 — 387 
430,228 148,663 79,496 40,218 50,326 52,133 111,534 24,150 936,748 
Total loans$1,339,586 $590,363 $382,648 $335,784 $368,904 $1,172,236 $1,093,287 $62,418 $5,345,226 
38

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Revolving loans converted to term loans during the nine months ended September 30, 2021 in the commercial, home equity line of credit and consumer portfolios were $1.6 million, $13.6 million and $1.9 million, respectively. 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 were $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		 
Greater than
90 days		Total
past due		CurrentTotal
financing
receivables		Amortized cost>
90 days and
accruing
September 30, 2021       
Real estate:       
Residential 1-4 family$2,224 $1,584 $8,552 $12,360 $2,159,713 $2,172,073 $— 
Commercial real estate— — — — 1,090,816 1,090,816 — 
Home equity line of credit255 208 1,455 1,918 849,498 851,416 — 
Residential land97 — 300 397 19,002 19,399 — 
Commercial construction— — — — 109,716 109,716 — 
Residential construction— — — — 9,170 9,170 — 
Commercial937 68 110 1,115 757,223 758,338 — 
Consumer1,427 780 1,050 3,257 119,399 122,656 — 
Total loans$4,940 $2,640 $11,467 $19,047 $5,114,537 $5,133,584 $— 
December 31, 2020       
Real estate:       
Residential 1-4 family$2,629 $2,790 $2,715 $8,134 $2,136,105 $2,144,239 $— 
Commercial real estate— 488 — 488 983,377 983,865 — 
Home equity line of credit850 342 2,052 3,244 960,334 963,578 — 
Residential land702 — 300 1,002 14,615 15,617 — 
Commercial construction— — — — 121,424 121,424 — 
Residential construction— — — — 11,022 11,022 — 
Commercial608 300 132 1,040 935,708 936,748 — 
Consumer2,605 1,491 1,631 5,727 163,006 168,733 — 
Total loans$7,394 $5,411 $6,830 $19,635 $5,325,591 $5,345,226 $— 

The credit risk profile based on nonaccrual loans were as follows:
(in thousands)September 30, 2021December 31, 2020
With a Related ACLWithout a Related ACLTotalWith a Related ACLWithout a Related ACLTotal
Real estate:
Residential 1-4 family$13,307 $7,997 $21,304 $8,991 $2,835 $11,826 
Commercial real estate15,062 1,251 16,313 15,847 2,875 18,722 
Home equity line of credit4,564 1,364 5,928 5,791 1,567 7,358 
Residential land97 300 397 108 300 408 
Commercial construction— — — — — — 
Residential construction— — — — — — 
Commercial 1,573 2,080 3,653 1,819 3,328 5,147 
Consumer 2,198 — 2,198 3,935 — 3,935 
  Total $36,801 $12,992 $49,793 $36,491 $10,905 $47,396 

39

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
The credit risk profile based on loans whose terms have been modified and accruing interest were as follows:
(in thousands)September 30, 2021December 31, 2020
Real estate:
Residential 1-4 family$7,545 $7,932 
Commercial real estate3,136 3,281 
Home equity line of credit6,986 8,148 
Residential land985 1,555 
Commercial construction— — 
Residential construction— — 
Commercial7,251 6,108 
Consumer52 54 
Total troubled debt restructured loans accruing interest$25,955 $27,078 

ASB did not recognize interest on nonaccrual loans for the three and nine months ended September 30, 2021 and 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.
Loan modifications that occurred during the three and nine months ended September 30, 2021 and 2020 were as follows:
Loans modified as a TDRThree months ended September 30, 2021Nine months ended September 30, 2021
(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 $442 $81 16 $10,363 $309 
Commercial real estate— — — — — — 
Home equity line of credit— — — — — — 
Residential land1 247 11 3 802 37 
Commercial construction— — — — — — 
Residential construction— — — — — — 
Commercial1 2,386 212 7 2,678 242 
Consumer — — — — — — 
 3 $3,075 $304 26 $13,843 $588 



40

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Three 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 
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 2021 and 2020.
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, 2021 and December 31, 2020.
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.
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.
41

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Loans considered collateral-dependent were as follows:
Amortized cost
(in thousands)September 30, 2021December 31, 2020Collateral type
Real estate:
   Residential 1-4 family$5,268 $2,541  Residential real estate property
Commercial real estate1,251 2,875  Commercial real estate property
   Home equity line of credit1,364 1,567  Residential real estate property
Residential land300 300  Residential real estate property
     Total real estate8,183 7,283 
Commercial780 934  Business assets
     Total $8,963 $8,217 
ASB had $3.4 million and $3.8 million of mortgage loans collateralized by residential real estate property that were in the process of foreclosure at September 30, 2021 and December 31, 2020, respectively.
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 $38.3 million and $128.0 million for the three months ended September 30, 2021 and 2020, respectively, $304.8 million and $387.2 million for the nine months ended September 30, 2021 and 2020, respectively, and recognized gains on such sales of $1.3 million and $7.7 million for the three months ended September 30, 2021 and 2020, respectively, $7.5 million and $15.9 million for the nine months ended September 30, 2021 and 2020, respectively.
There were no repurchased mortgage loans for the three and nine months ended September 30, 2021 and 2020. The repurchase reserve, which represents ASB’s loss estimate related to mortgage loan repurchases, was $0.1 million as of September 30, 2021 and 2020.
Mortgage servicing fees, a component of other income, net, were $1.0 million and $0.9 million for the three months ended September 30, 2021 and 2020, respectively, and were $2.8 million and $2.5 million for the nine months ended September 30, 2021 and 2020, respectively.
Changes in the carrying value of MSRs were as follows:
(in thousands)
Gross
carrying amount1
Accumulated amortizationValuation allowanceNet
carrying amount
September 30, 2021$22,182 $(11,910)$— $10,272 
December 31, 202022,950 (12,670)(260)10,020 
1     Reflects impact of loans paid in full
42

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Changes related to MSRs were as follows:
Three months ended September 30,Nine months ended September 30
(in thousands)2021202020212020
Mortgage servicing rights
Beginning balance$10,754 $9,911 $10,280 $9,101 
Amount capitalized315 1,119 2,885 3,481 
Amortization(797)(1,095)(2,893)(2,647)
Other-than-temporary impairment— — — — 
Carrying amount before valuation allowance10,272 9,935 10,272 9,935 
Valuation allowance for mortgage servicing rights
Beginning balance— 264 260 — 
Provision— 118 (260)382 
Other-than-temporary impairment— — — — 
Ending balance— 382 — 382 
Net carrying value of mortgage servicing rights$10,272 $9,553 $10,272 $9,553 
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 condensed 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, 2021December 31, 2020
Unpaid principal balance$1,521,966 $1,450,312 
Weighted average note rate3.42 %3.68 %
Weighted average discount rate9.25 %9.25 %
Weighted average prepayment speed11.7 %17.7 %
The sensitivity analysis of fair value of MSRs to hypothetical adverse changes of 25 and 50 basis points in certain key assumptions was as follows:
(dollars in thousands)September 30, 2021December 31, 2020
Prepayment rate:
  25 basis points adverse rate change$(1,045)$(738)
  50 basis points adverse rate change(2,209)(1,445)
Discount rate:
  25 basis points adverse rate change(115)(68)
  50 basis points adverse rate change(229)(135)
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, 2021 and December 31, 2020, ASB had no FHLB advances outstanding or federal funds purchased with the Federal Reserve Bank. ASB was in compliance with all Advances, Pledge and Security Agreement requirements as of September 30, 2021.
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
43

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
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, 2021$129 $— $129 
December 31, 202090 — 90 
 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, 2021$129 $146 $— 
December 31, 202090 92 — 
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.
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. In some cases, a best-efforts forward sale agreement is utilized as the forward commitment. 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, 2021December 31, 2020
(in thousands)Notional amountFair valueNotional amountFair value
Interest rate lock commitments$22,289 $308 $120,980 $4,536 
Forward commitments21,750 109 100,500 (500)
44

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
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, 2021December 31, 2020
(in thousands) Asset derivatives Liability
derivatives 		 Asset derivatives Liability
derivatives
Interest rate lock commitments$308 $— $4,536 $— 
Forward commitments121 12 — 500 
 $429 $12 $4,536 $500 
1 Asset derivatives are included in other assets and liability derivatives are included in other liabilities in the balance sheets.
The following table presents ASB’s derivative financial instruments and the amount and location of the net gains or losses recognized in ASB’s statements of income:
Derivative Financial Instruments Not Designated as Hedging Instruments Location of net gains (losses) recognized in the Statements of IncomeThree months ended September 30,Nine months ended September 30
(in thousands)2021202020212020
Interest rate lock commitmentsMortgage banking income$(63)$2,930 $(4,228)$4,974 
Forward commitmentsMortgage banking income150 44 609 (201)
 $87 $2,974 $(3,619)$4,773 
Low-Income Housing Tax Credit (LIHTC). ASB’s unfunded commitments to fund its LIHTC investment partnerships were $37.8 million and $41.0 million at September 30, 2021 and December 31, 2020, 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, 2021, ASB did not have any impairment losses resulting from forfeiture or ineligibility of tax credits or other circumstances related to its LIHTC investment partnerships.
45

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Note 5 · Credit agreements and changes in long-term debt
On May 14, 2021, HEI and Hawaiian Electric (each a Company, and collectively the Companies) each entered into a separate agreement with a syndicate of nine financial institutions (the HEI Facility and Hawaiian Electric Facility, respectively, and together, the Amended Facilities) to amend and restate their respective previously existing revolving unsecured credit agreements. The HEI Facility was increased to $175 million from $150 million and its term was extended to May 14, 2026. The $200 million Hawaiian Electric Facility has an initial term that expires on May 13, 2022, but its term will extend to May 14, 2026 upon approval by the PUC during the initial term, which approval has been requested. In addition to extending the term, Hawaiian Electric also requested PUC approval to exercise its options of two one-year extensions of the commitment termination date and to increase its aggregate revolving commitment amount from $200 million to $275 million, should there be a need.
None of the facilities are collateralized. As of September 30, 2021 and December 31, 2020, 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.
Under the Amended Facilities, draws would generally bear interest, based on each Company’s respective current long-term credit ratings, at the “Adjusted LIBO Rate,” as defined in the Amended Facilities, plus 137.5 and 125.0 basis points for HEI and Hawaiian Electric, respectively, and incur annual fees on undrawn commitments, excluding swingline borrowings, of 20.0 and 17.5 basis points for HEI and Hawaiian Electric, respectively. The Amended Facilities also include provisions to accommodate a transition from the London Interbank Offered Rate (LIBOR) to an alternative reference rate, based on the secured overnight financing rate administered by the Federal Reserve Bank of New York, upon the phase out of LIBOR as a reference rate.
Additionally, the Amended Facilities contain provisions for pricing adjustments in the event of a long-term ratings change based on the respective Facility’s ratings-based pricing grid, which includes the ratings by Fitch Ratings, Inc. (Fitch), Moody’s Investors Service (Moody’s) and Standard & Poor’s (S&P). The Amended Facilities do not contain clauses that would affect access to the Amended Facilities by reason of a ratings downgrade, nor do they have broad “material adverse change” clauses. In addition, the Amended Facilities contain provisions for potential annual pricing adjustments to the Eurodollar or Alternate Base Rate margin on draws and fees on undrawn commitments of up to +/-5 basis points and +/-1 basis point, respectively, based on performance against certain sustainability-linked metrics. The sustainability-linked metrics include achievement of renewable portfolio standards in excess of statutory requirements and increasing cumulative penetration of installed MWs of photovoltaic systems on residential rooftops.
The Amended Facilities also include updated terms and conditions customary for facilities of this type and contain customary conditions that must be met in order to draw on them, including compliance with covenants (such as covenants preventing HEI’s and Hawaiian Electric’s respective subsidiaries from entering into agreements that restrict the ability of such subsidiaries to pay dividends to, or to repay borrowings from, HEI or Hawaiian Electric, as applicable; and a covenant in Hawaiian Electric’s facility restricting Hawaiian Electric’s ability, as well as the ability of any of its subsidiaries, to guarantee additional indebtedness of the subsidiaries if such additional debt would cause the subsidiary’s “Consolidated Subsidiary Funded Debt to Capitalization Ratio” (as defined in the Hawaiian Electric Facility) to exceed 65%).
Under the HEI Facility, it is an event of default if HEI fails to maintain an unconsolidated “Capitalization Ratio” (funded debt) (as defined in the HEI Facility) of 50% or less or if HEI no longer owns Hawaiian Electric or ASB. Under the Hawaiian Electric Facility, it is an event of default if Hawaiian Electric fails to maintain a “Consolidated Capitalization Ratio” (equity) (as defined in the Hawaiian Electric Facility) of at least 35%, or if Hawaiian Electric is no longer owned by HEI.
Hawaiian Electric had a $75 million 364-day revolving credit agreement, under which no amounts had been drawn. On April 19, 2021, the revolving credit agreement terminated and was not renewed.
HEI Private Placement. On September 29, 2021, HEI entered into a note purchase agreement (HEI NPA) under which HEI has authorized the issue and sale of $125 million of unsecured senior notes to be drawn in two tranches at a future date. As defined in the note purchase agreement, at its option, HEI may draw the notes on a delayed basis. The following table displays the required draw date of the HEI notes.
46

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
HEI Series 2021AHEI Series 2021BHEI Series 2021CHEI Series 2022AHEI Series 2022B
Aggregate principal amount
$30 million$25 million$20 million$30 million$20 million
Fixed coupon interest rate
2.48%2.78%3.74%2.98%3.94%
Maturity date12/29/202812/29/203112/29/205111/15/203211/15/2052
Final draw date12/29/202112/29/202112/29/202111/15/202211/15/2022
Proceeds from the notes are expected to be used for general corporate purposes, including investing in the Utilities’ equity to maintain a Utilities’ equity capitalization ratio of approximately 58%, refinancing a portion of $150 million of maturing debt in November 2022, and to repay a portion of HEI commercial paper outstanding. Once drawn, interest on the notes is paid semiannually on June 15th and December 15th. The HEI note purchase agreements contain certain restrictive financial covenants that are substantially the same as the financial covenants contained in HEI’s senior credit facility, as amended. 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 agreements.
Mauo Term Debt. On September 3, 2021, Mauo entered into a $24 million credit agreement under which it has drawn an aggregate of $13 million under a series of notes. The proceeds were used to refinance a portion of a construction loan related to five solar-battery projects. The notes are non-recourse to Pacific Current and HEI, bear interest at LIBOR plus 1.7%, mature in September 2034, and are collateralized by three solar-battery projects. In connection with the non-recourse notes drawn under the credit agreement, Mauo entered into interest rate swaps that effectively convert the rate on the floating rate notes to a fixed rate of 4.9%.
47

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
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, 2020$19,986 $(3,363)$(17,887)$(1,264)$(2,919)
Current period other comprehensive income (loss)(40,308)1,009 450 (38,849)175 
Balance, September 30, 2021$(20,322)$(2,354)$(17,437)$(40,113)$(2,744)
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)

Reclassifications out of AOCI were as follows:
 Amount reclassified from AOCIAffected line item in the
 Statements of Income / Balance Sheets
Three months ended September 30Nine months ended September 30
2021202020212020
(in thousands)
HEI consolidated
Net realized gains on securities included in net income$— $— $(387)$(1,638)Gain on sale of investment securities, net
Net realized losses on derivatives qualifying as cash flow hedges9 — 9 — Interest expense
Retirement benefit plans:     
Amortization of prior service credit and net losses recognized during the period in net periodic benefit cost2,853 6,324 14,871 17,720 
See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets(2,799)(5,721)(14,421)(16,038)
See Note 8 for additional details
Total reclassifications$63 $603 $72 $44  
Hawaiian Electric consolidated
Retirement benefit plans:   
Amortization of prior service credit and net losses recognized during the period in net periodic benefit cost$2,905 $5,769 $14,596 $16,137 
See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets(2,799)(5,721)(14,421)(16,038)
See Note 8 for additional details
Total reclassifications$106 $48 $175 $99  

48

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, 2021Nine months ended September 30, 2021
(in thousands) Electric  utilityBankOtherTotalElectric  utilityBankOtherTotal
Revenues from contracts with customers
Electric energy sales - residential
$228,878 $— $— $228,878 $606,435 $— $— $606,435 
Electric energy sales - commercial
217,468 — — 217,468 578,036 — — 578,036 
Electric energy sales - large light and power
229,129 — — 229,129 607,480 — — 607,480 
Electric energy sales - other 2,779 — — 2,779 7,470 — — 7,470 
Bank fees— 11,186 — 11,186 — 34,133 — 34,133 
Other sales— — 1,178 1,178 — — 3,191 3,191 
Total revenues from contracts with customers678,254 11,186 1,178 690,618 1,799,421 34,133 3,191 1,836,745 
Revenues from other sources
Regulatory revenue$(5,717)$— $— $(5,717)$25,566 $— $— $25,566 
Bank interest and dividend income
— 61,441 — 61,441 — 182,127 — 182,127 
Other bank noninterest income— 3,581 — 3,581 — 14,339 — 14,339 
Other6,962 — 19 6,981 21,255 — 75 21,330 
Total revenues from other sources1,245 65,022 19 66,286 46,821 196,466 75 243,362 
Total revenues$679,499 $76,208 $1,197 $756,904 $1,846,242 $230,599 $3,266 $2,080,107 
Timing of revenue recognition
Services/goods transferred at a point in time
$— $11,186 $— $11,186 $— $34,133 $— $34,133 
Services/goods transferred over time
678,254 — 1,178 679,432 1,799,421 — 3,191 1,802,612 
Total revenues from contracts with customers$678,254 $11,186 $1,178 $690,618 $1,799,421 $34,133 $3,191 $1,836,745 
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 - other1,935 — — 1,935 7,172 — — 7,172 
Bank fees— 9,589 — 9,589 — 28,356 — 28,356 
Other 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 
49

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
There are no material contract assets or liabilities associated with revenues from contracts with customers existing at December 31, 2020 or as of September 30, 2021. Accounts receivable and unbilled revenues related to contracts with 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, 2021, 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 2021, the Company contributed $39 million ($38 million by the Utilities) to its pension and other postretirement benefit plans, compared to $53 million ($52 million by the Utilities) in the first nine months of 2020. The Company’s current estimate of total contributions to its pension and other postretirement benefit plans in 2021 is $52 million ($51 million by the Utilities, $1 million by HEI and nil by ASB), compared to $71 million ($70 million by the Utilities, $1 million by HEI and nil by ASB) in 2020. In addition, the Company expects to pay directly $2 million ($1 million by the Utilities) of benefits in 2021, compared to $2 million ($1 million by the Utilities) paid in 2020.
50

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
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
20212020202120202021202020212020
(in thousands)
HEI consolidated
Service cost$20,102 $18,341 $711 $641 $61,031 $55,066 $2,121 $1,903 
Interest cost18,896 20,660 1,459 1,842 56,497 60,987 4,597 5,553 
Expected return on plan assets(33,022)(28,422)(3,252)(3,023)(99,157)(85,353)(9,717)(9,100)
Amortization of net prior period (gain)/cost
— 2 (383)(474)— 7 (1,150)(1,355)
Amortization of net actuarial (gain)/losses1
10,112 8,944 (140)53 20,099 25,059 158 154 
Net periodic pension/benefit cost (return)
16,088 19,525 (1,605)(961)38,470 55,766 (3,991)(2,845)
Impact of PUC D&Os4,292 4,976 1,483 835 20,972 17,499 3,629 2,389 
Net periodic pension/benefit cost (adjusted for impact of PUC D&Os)
$20,380 $24,501 $(122)$(126)$59,442 $73,265 $(362)$(456)
Hawaiian Electric consolidated
Service cost$19,610 $17,921 $704 $635 $59,597 $53,703 $2,101 $1,886 
Interest cost17,614 19,183 1,398 1,764 52,676 56,613 4,406 5,327 
Expected return on plan assets(31,318)(26,815)(3,202)(2,986)(94,053)(80,527)(9,566)(8,966)
Amortization of net prior period (gain)/cost
— 1 (383)(474)— 6 (1,148)(1,353)
Amortization of net actuarial (gain)/losses1
9,880 8,188 (138)53 20,651 22,925 155 155 
Net periodic pension/benefit cost (return)
15,786 18,478 (1,621)(1,008)38,871 52,720 (4,052)(2,951)
Impact of PUC D&Os4,292 4,976 1,483 835 20,972 17,499 3,629 2,389 
Net periodic pension/benefit cost (adjusted for impact of PUC D&Os)
$20,078 $23,454 $(138)$(173)$59,843 $70,219 $(423)$(562)
1 Nine months ended September 30, 2021 amounts include the one-time cumulative impact of the change in accounting principle for the plans’ fixed income securities from the calculated market-related value method to the fair value method, which was recorded in the first quarter of 2021.
HEI consolidated recorded retirement benefits expense of $35 million ($35 million by the Utilities) in the first nine months of 2021 and $46 million ($43 million by the Utilities) in the first nine months of 2020 and charged the remaining net periodic benefit cost primarily to electric utility plant.
Effective January 1, 2021, the Company adopted a change in accounting principle for the plans’ fixed income securities from the calculated market-related value method to the fair value method in the calculation of the expected return on plan assets component of NPPC and NPBC. The remaining plan assets continue to use the calculated market-related value methodology. The Company considers the fair value approach to be preferable for its fixed-income securities portfolio because it results in a current reflection of the changes in the value of plan assets in a way similar to the obligations it is intended to hedge. The Company evaluated the effect of this change in accounting principle and deemed it to be immaterial to the historical financial statements of the Company and Hawaiian Electric and, therefore, did not account for the change retrospectively and recorded the cumulative effects from the change in accounting principle in earnings for non-Utility businesses in the first quarter of 2021. Amounts related to the Utilities were reflected as adjustments to regulatory assets as appropriate, consistent with the expected regulatory treatment as described in the following paragraph.
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
51

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
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 2021 and 2020, 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 $4.9 million and $5.5 million, respectively, and cash contributions were $4.8 million and $6.0 million, respectively. For the first nine months of 2021 and 2020, the Utilities’ expenses and cash contributions for its defined contribution plan under the HEIRSP were $2.3 million and $2.1 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, 2021, approximately 2.9 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 0.8 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, 2021, there were 244,843 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)2021202020212020
HEI consolidated
Share-based compensation expense 1
$1.3 $1.4 $6.7 $5.4 
Income tax benefit0.1 0.2 1.0 0.9 
Hawaiian Electric consolidated
Share-based compensation expense 1
0.1 — 2.1 1.2 
Income tax benefit— — 0.4 0.3 
1    For the three and nine months ended September 30, 2021 and 2020, the Company has not capitalized any share-based compensation.
Stock awards. HEI granted HEI common stock to nonemployee directors under the 2011 Director Plan as follows:
Three months ended September 30Nine months ended September 30
(dollars in millions)2021202020212020
Shares granted— — 29,320 36,100 
Fair value$— $— $1.2 $1.3 
Income tax benefit— — 0.3 0.3 
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.
52

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
 2021202020212020
Shares(1)Shares(1)Shares(1)Shares(1)
Outstanding, beginning of period229,775 $38.02 204,357 $40.65 193,939  $40.89 207,641 $35.36 
Granted1,432 45.09 — — 133,924 34.49 78,595 47.99 
Vested(343)37.83 — — (79,623)38.51 (77,719)34.19 
Forfeited(1,074)38.52 — — (18,450)39.92 (4,160)35.81 
Outstanding, end of period229,790 $38.06 204,357  $40.65 229,790  $38.06 204,357 $40.65 
Total weighted-average grant-date fair value of shares granted (in millions)$0.1 $— $4.6 $3.8 
(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, 2021 and 2020, total restricted stock units and related dividends that vested had a fair value of $3.0 million and $4.2 million, respectively, and the related tax benefits were $0.6 million and $0.7 million, respectively.
As of September 30, 2021, there was $6.4 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 2.2 years.
Long-term incentive plan payable in stock.  The 2019-2021, 2020-2022 and 2021-2023 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 EPS growth, return on average common equity (ROACE), renewable portfolio standards, Hawaiian Electric’s net income growth, ASB’s efficiency ratio and strategic initiatives 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
 2021202020212020
Shares(1)Shares(1)Shares(1)Shares(1)
Outstanding, beginning of period91,159 $42.87 90,616 $42.08 89,222 $42.10 96,402 $39.62 
Granted 281 41.12 — — 46,024 41.12 24,630 48.62 
Vested (issued or unissued and cancelled)— — — — (32,355)38.20 (29,409)39.51 
Forfeited(466)42.49 — — (11,917)43.07 (1,007)41.72 
Outstanding, end of period90,974 $42.86 90,616 $42.08 90,974 $42.86 90,616  $42.08 
Total weighted-average grant-date fair value of shares granted (in millions)$— $— $1.9 $1.2 
(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 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. A dividend assumption is not required for the Monte Carlo simulation because the grant payout includes dividend equivalents and projected returns include the value of reinvested dividends.
53

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:
20212020
Risk-free interest rate0.19 %1.39 %
Expected life in years33
Expected volatility29.9 %13.1 %
Range of expected volatility for Peer Group
25.6% to 102.9%
13.6% to 95.4%
Grant date fair value (per share)$41.12$48.62
For the nine months ended September 30, 2021 and 2020, total vested LTIP awards linked to TSR and related dividends had a fair value of $0.8 million and $2.6 million, respectively, and the related tax benefits were $0.2 million and $0.4 million, respectively.
As of September 30, 2021, there was $1.8 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 1.4 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
2021202020212020
 Shares(1)Shares (1)Shares(1)Shares(1)
Outstanding, beginning of period316,005 $38.38 297,523  $40.37 220,715 $41.03 403,768  $35.15 
Granted 1,125 41.12 — — 184,102 34.37 98,522 48.10 
Vested — — —  — (43,155)34.12 (135,804) 33.48 
Increase above target (cancelled)(22,354)37.81 (21,807) 34.11 (21,077)38.18 (86,739) 34.12 
Forfeited(1,865)36.77 — — (47,674)38.74 (4,031)39.67 
Outstanding, end of period292,911 $38.45 275,716  $40.86 292,911 $38.45 275,716  $40.86 
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)
$— $— $6.3 $4.7 
(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, 2021 and 2020, total vested LTIP awards linked to other performance conditions and related dividends had a fair value of $1.7 million and $7.6 million, respectively, and the related tax benefits were $0.4 million and $1.2 million, respectively.
As of September 30, 2021, there was $5.7 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 1.6 years.

Note 10 · Income taxes
The Company’s and the Utilities’ effective tax rates (combined federal and state income tax rates) were 20% and 19%, respectively, for the nine months ended September 30, 2021. 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, the non-taxability of the bank-owned life insurance income and federal research and development tax credit claims. The Company’s and the Utilities’ effective tax rates were 17% and 19%, respectively, for the nine months ended September 30, 2020.
In August 2020, the Internal Revenue Service notified the Company that its 2017 and 2018 income tax returns would 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.

54

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
Note 11 · Cash flows
Nine months ended September 3020212020
(in millions)  
Supplemental disclosures of cash flow information  
HEI consolidated
Interest paid to non-affiliates, net of amounts capitalized$61 $64 
Income taxes paid (including refundable credits)34 23 
Hawaiian Electric consolidated
Interest paid to non-affiliates43 39 
Income taxes paid (including refundable credits)20 29 
Supplemental disclosures of noncash activities  
HEI consolidated
Property, plant and equipment
   Estimated fair value of noncash contributions in aid of construction (investing)5 9 
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)30 32 
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)44 22 
Common stock issued (gross) for director and executive/management compensation (financing)1
7 16 
Obligations to fund low income housing investments (investing)9 10 
Loans transferred from held for investment to held for sale (investing)62 — 
Hawaiian Electric consolidated
Electric utility property, plant and equipment
   Estimated fair value of noncash contributions in aid of construction (investing)5 9 
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)27 28 
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)44 16 
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 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.
55

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
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.
Collateral dependent loans. Collateral dependent loans have been adjusted to fair value. When a loan is identified as collateral dependent, the Company measures the impairment using the current fair value of the collateral, less selling costs. Depending on the characteristics of a loan, the fair value of collateral is generally estimated by obtaining external appraisals, but in some cases, the value of the collateral may be estimated as having little or no 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. If it is determined that the value of the collateral dependent loan is less than its recorded investment, the Company recognizes this impairment and adjusts the carrying value of the loan to fair value through the allowance for credit losses.
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. ASB includes MSRs within Level 3 of the valuation hierarchy.
Time deposits. 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.
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
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)
prices in active exchange markets. The fair values of ASB’s best efforts and 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.
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, 2021     
Financial assets     
HEI consolidated
Available-for-sale investment securities
$2,580,830 $— $2,565,403 $15,427 $2,580,830 
Held-to-maturity investment securities
491,871 — 484,654 — 484,654 
Loans, net5,100,178 — 54,537 5,167,221 5,221,758 
Mortgage servicing rights10,272 — — 13,712 13,712 
Derivative assets53,789 121 494 — 615 
Financial liabilities    
HEI consolidated
Deposit liabilities444,897 — 445,401 — 445,401 
Short-term borrowings—other than bank92,246 — 92,246 — 92,246 
Other bank borrowings129,305 — 129,304 — 129,304 
Long-term debt, net—other than bank2,244,795 — 2,588,972 — 2,588,972 
  Derivative liabilities27,250 12 3,456 — 3,468 
Hawaiian Electric consolidated
Short-term borrowings— — — — — 
Long-term debt, net 1,676,223 — 1,987,933 — 1,987,933 
December 31, 2020     
Financial assets     
HEI consolidated
Available-for-sale investment securities
$1,970,417 $— $1,943,232 $27,185 $1,970,417 
Held-to-maturity investment securities
226,947 — 229,963 — 229,963 
Loans, net5,260,917 — 28,354 5,410,976 5,439,330 
Mortgage servicing rights10,020 — — 10,705 10,705 
Derivative assets120,980 — 4,536 — 4,536 
Financial liabilities    
HEI consolidated
Deposit liabilities548,830 — 552,800 — 552,800 
Short-term borrowings—other than bank129,379 — 129,379 — 129,379 
Other bank borrowings89,670 — 89,669 — 89,669 
Long-term debt, net—other than bank2,119,129 — 2,487,790 — 2,487,790 
Derivative liabilities137,500 500 4,530 — 5,030 
Hawaiian Electric consolidated
Short-term borrowings49,979 — 49,979 — 49,979 
Long-term debt, net 1,561,302 — 1,890,490 — 1,890,490 
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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, 2021December 31, 2020
 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
$— $2,441,683 $— $— $1,849,559 $— 
U.S. Treasury and federal agency obligations— 92,075 — — 62,322 — 
Corporate bonds— 31,645 — — 31,351 — 
Mortgage revenue bonds— — 15,427 — — 27,185 
 $— $2,565,403 $15,427 $— $1,943,232 $27,185 
Derivative assets     
Interest rate lock commitments (bank segment)1
$— $308 $— $— $4,536 $— 
Forward commitments (bank segment)1
121 — — — — — 
Interest rate swap (Other segment)2
— 186 — — — — 
 $121 $494 $— $— $4,536 $— 
Derivative liabilities
Forward commitments (bank segment)1
$12 $— $— $500 $— $— 
Interest rate swap (Other segment)2
— 3,456 — — 4,530 — 
$12 $3,456 $— $500 $4,530 $— 
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 assets and 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 bonds2021202020212020
(in thousands)
Beginning balance$15,427 $28,827 $27,185 $28,597 
Principal payments received— (1,642)(11,758)(1,642)
Purchases— — — 230 
Unrealized gain (loss) included in other comprehensive income— — — — 
Ending balance$15,427 $27,185 $15,427 $27,185 
Mortgage revenue bonds are 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, 2021, the weighted average discount rate was 2.06%, 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, 2021
Loans$125 $— $— $125 
December 31, 2020
Loans387 — — 387 
Mortgage servicing rights3,001 — — 3,001 
For the nine months ended September 30, 2021 and 2020, there were no adjustments to fair value for ASB’s loans held for sale.
The following table presents quantitative information about Level 3 fair value measurements for financial instruments measured at fair value on a nonrecurring basis:
Significant unobservable
 input value (1)
($ in thousands)Fair value Valuation techniqueSignificant unobservable inputRangeWeighted
Average
September 30, 2021
Residential$125 Fair value of property or collateralAppraised value less selling costN/A (2)N/A (2)
December 31, 2020
Commercial loan$387 Fair value of collateralAppraised value less selling costN/A (2)N/A (2)
Mortgage servicing rights3,001 Discounted cash flowPrepayment speed
15% - 22%
22 %
Discount rate9.3 %
(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 2020 Form 10-K and should be read in conjunction with such discussion and the 2020 annual consolidated financial statements of HEI and Hawaiian Electric and notes thereto included in HEI’s and Hawaiian Electric’s 2020 Form 10-K, as well as the quarterly (as of and for the nine months ended September 30, 2021) condensed consolidated financial statements and notes thereto included in this Form 10-Q.
HEI consolidated
Recent developments—COVID-19.
The economic recovery in Hawaii experienced a setback early in the third quarter as daily COVID-19 case counts rose and set a pandemic high of 900 cases (7-day average) in early September. As a result of the rising cases, a number of preventative policies were enacted by state, county and private entities. These measures included limiting group sizes for indoor and outdoor activities, mandatory vaccinations or adherence to regular testing protocols, and proof of vaccination or negative COVID-19 test for entry into certain indoor venues under the state’s Safe Access program. Additionally, the governor of the State of Hawaii made an announcement in late August, recommending that tourists postpone their visit to Hawaii.
Hawaii vaccinations have steadily increased with over 70% of the state’s population now fully vaccinated as of October 18, 2021. Due to increasing vaccination rates and the mitigation measures cited above, the 7-day average case count has steadily decreased, reaching 120 cases (7-day average) on October 18, 2021. On October 19, 2021, the governor of the State of Hawaii made an announcement encouraging fully vaccinated residents and non-residents to resume non-essential travel starting November 1, 2021.
While the case count trend has improved recently, tourism numbers have declined from the high levels experienced during the summer, due in part to the dampening effect of rising COVID-19 case counts across the U.S., but also due to seasonality where tourism numbers generally decline in the fall season.
Although the Hawaii economy experienced a temporary set back with the rise of the Delta variant, the Company expects that the Hawaii economy will continue to improve as tourism numbers increase for the balance of the year. In the third quarter of 2021, kWh sales remained below pre-pandemic levels, but were 4.4% higher than the same period in 2020 due to increased economic activity following the loosening of restrictions and an increase in tourism. While the level of kWh sales does not affect Utility revenues due to decoupling, it may increase or decrease the price per kWh paid by customers. See “Decoupling” in Note 3 of the Condensed Consolidated Financial Statements for a discussion of decoupling.
At the Bank, due to an improvement in the credit outlook in the third quarter of 2021, as reflected in upgrades in the commercial and commercial real estate loan portfolios and overall lower net charge offs, ASB recorded a $2 million negative provision for credit losses in the third quarter of 2021.
The Company remains focused on the continued safety and well-being of customers, employees, their families and the community. The Company’s mandatory work-from-home policy remains in effect through January 10, 2022 for certain employees and this policy has not impaired the Company’s ability to maintain effective internal controls over financial reporting. For personnel that cannot perform their work remotely, the Company has maintained safety protocols and policies to keep employees safe, while at the same time ensuring the reliability and resilience of its operations.
For further discussion of the impact of the COVID-19 pandemic on our subsidiaries see “Recent Developments—COVID-19” in the Electric Utility and Bank sections below. There has been no material impact on the “Other” segment and Pacific Current as a result of the COVID-19 pandemic as the primary businesses of Pacific Current are supported by PPAs that provide for contractual cash flows with credit-worthy counterparties.
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” sections of this MD&A.
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 isolated in the middle of the Pacific Ocean, the Company’s long-term health, and ability to deliver sustainable value for all stakeholders—including shareholders—is inextricably linked to the well-being of its employees, communities, economy, and environment. That is why the Company sees its mission of being a catalyst for a better Hawaii as advancing the Company’s long-term financial performance and
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sustainability. The Company has focused on ensuring ESG considerations are appropriately integrated into its governance structures, strategies and risk management. This includes:
•Integration of Board oversight of important ESG matters into its existing governance structures and processes. This includes full Board review of ESG-related strategies, Audit & Risk Committee oversight of ESG risks, Compensation Committee responsibility for ESG-related compensation matters and Nominating & Corporate Governance Committee responsibility for human capital management and for ensuring an appropriate board governance framework is in place with respect to ESG.
•Robust ESG expertise among board members, including directors with direct experience in renewable energy, climate change policy and strategy, environmental management and sustainable investing.
•Expanded ESG goals as part of HEI and Utility executive incentive compensation.
•ESG considerations explicitly woven into strategic planning efforts and enterprise risk management processes.
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. The report encompassed ESG policies, principles and results reported during 2019 across the Company’s two primary operating subsidiaries, Hawaiian Electric and ASB, and was aligned with Sustainability Accounting Standards Board (SASB) guidance—using the electric utilities standard for Hawaiian Electric, and the commercial banks, commercial finance, and mortgage finance standards for ASB. On April 22, 2021, the Company issued its second ESG report. This report continues to include SASB disclosures for Hawaiian Electric and ASB and incorporates disclosures regarding risks and opportunities related to climate change, as well as associated risk management and governance processes, based on recommendations from the Task Force on Climate-related Financial Disclosures. It also outlines key impacts for the Company under two climate scenarios, including a scenario targeted to limit global temperature rise to 2 degrees Celsius or lower. The Company’s ESG reports can be found at www.hei.com/esg.
RESULTS OF OPERATIONS

Three months ended September 30%
(in thousands)20212020changePrimary reason(s)*
Revenues$756,904 $641,427 18 Primarily increase for the electric utility segment
Operating income97,316 99,561 (2)Primarily decrease for electric utility segment due to higher operating expenses, partly offset by increase for bank segment
Net income for common stock63,415 65,032 (2)Primarily lower net income for electric utility segment, partly offset by higher net income at bank segment.

Nine months ended September 30%
(in thousands)20212020changePrimary reason(s)*
Revenues$2,080,107 $1,927,558 8 Primarily increase for the electric utility segment
Operating income297,203 230,819 29 Primarily increase for the electric utility and bank segments
Net income for common stock191,645 147,339 30 Primarily higher net income at the electric utility and bank segments. See below for effective tax rate explanation.
*     Also, see segment discussions which follow.

The Company’s effective tax rates for the third quarters of 2021 and 2020 were each 18%. The Company’s effective tax rates for the first nine months of 2021 and 2020 were 20% and 17%, respectively. The effective tax rates were higher for the nine months ended September 30, 2021 compared to the same period in 2020 due primarily to an increase in income before taxes in 2021, which reduces the rate impact of certain tax items, lower amortization in 2021 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 a decrease in excess tax benefits related to vesting of share-based awards in 2021. These increases were partially offset by higher nontaxable bank owned life insurance and federal research and development tax credit claims in 2021.
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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), Department of Health of the State of Hawaii , 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).
The CARES Act was passed by Congress and signed into law on March 27, 2020. The economic relief package totals more than $2 trillion and provides direct economic support to businesses and individuals. On December 27, 2020, the President signed into law the $900 billion economic stimulus package that provides, among others, direct payments to qualifying individuals, extended unemployment benefits, and additional small business aid. On March 11, 2021, the President signed into law the $1.9 trillion coronavirus relief package. The plan sent direct payments of up to $1,400 to most Americans. The bill extended a $300 per week unemployment insurance boost that ended September 6 and expanded the child tax credit for a year. It will also put nearly $20 billion into COVID-19 vaccinations, $25 billion into rental and utility assistance, and $350 billion into state, local and tribal relief. Hawaii has received a significant amount of funds through these various federal assistance programs that will help attenuate the impact to Hawaii’s economy.
The City and County of Honolulu had been operating under a tiered framework for reducing the spread of COVID-19 on Oahu. On September 20, 2021, the mayor of the County of Honolulu announced moving away from the tiered system and into a more flexible and responsive approach to Honolulu’s COVID-19 related restrictions called the Safe Oahu Response Plan (SORP). Under the SORP, the response plan will be guided by consideration of metrics that have previously guided the City’s response to the pandemic, including reported COVID-19 cases per day (which informs projected hospitalizations), COVID-19 case positivity rate, percentage of fully vaccinated people, healthcare system capacity (including hospitalizations, ICU beds, ventilators, staffing, etc.), all with consideration of the economic impact of restrictions imposed. However, the loosening and tightening of restrictions, which will be more flexible than provided for under the tiered framework, will be made in consultation with healthcare professionals, including the State of Hawaii Department of Health and consideration of current CDC guidelines.
See “Recent Developments—COVID-19” in the “Electric utility” and “Bank” sections below 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 73.8% reduction in total visitor arrivals in 2020 compared with 2019. Starting October 15, 2020, the state launched its Safe Travels Program that allows travelers to avoid the mandatory 14-day quarantine if they test negative for COVID-19 within 72 hours of departure. Effective July 8, 2021, domestic visitors can now bypass the mandatory quarantine or COVID-19 test by providing proof of vaccination. Since the launch of the Safe Travels Program, the average daily passenger arrivals have steadily improved, but still remain below pre-pandemic levels. For the third quarter of 2021, average daily passenger counts were 1,268.5% higher than the comparable period in the prior year, but still 19.2% below 2019. A new 2021 year-to-date high of 35,555 daily visitor arrivals was achieved on August 1, 2021. On August 24th, due to increasing case numbers resulting from the Delta variant of COVID-19 and hospitals approaching maximum capacity, Governor Ige requested that tourists postpone their to travel to Hawaii and also implemented certain restrictions. As a result of seasonality and the measures taken above, the average daily passenger count in September 2021 trended lower to 19,871, compared to 27,972 in September 2019. The recovery in total passenger counts from the low levels in 2020 thus far has been driven by domestic travelers, with international travelers remaining at low levels due to higher restrictions for international travelers, depending on country of origin. In September 2021, domestic passenger counts were down 3.1% compared to 2019 pre-COVID-19 levels, while international passenger counts were down 94.6% compared to 2019 pre-COVID-19 levels.
Hawaii’s seasonally adjusted unemployment rate in September 2021 was 6.6%, which was substantially lower compared to the September 2020 rate of 14.8%. The national unemployment rate in September 2021 was 4.8% compared to 7.8% in September 2020. Hawaii’s unemployment rate is expected to continue to improve now that the job search requirement has been reinstated in order for claimants to receive unemployment benefits, restrictions on travel have been reduced significantly and increased vaccination rates should enable further reductions in business restrictions.
Hawaii real estate activity through September 2021, as indicated by Oahu’s home resale market, drove an increase in the median sales price of 8.7% for condominiums and 20.2% for single-family homes compared to the same period in 2020, with the median single-family home price reaching a record $1,050,000 in August and remained the same in September. The number of closed sales was up 63.3% for condominiums and up 24.2% for single-family residential homes for the first nine months of 2021 compared to the same period in 2020.
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 gradually increased during the 4th quarter of last year and the trend has continued during the first nine months of this year.
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At its September 22, 2021 meeting, the Federal Open Market Committee (FOMC) decided to maintain the federal funds rate target range of 0%-0.25%. The FOMC plans to 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 most recent forecast by UHERO, which was issued on September 24, 2021, forecasts full year 2021 real GDP growth of 3.5%, increase in total visitor arrivals of 142.9%, decrease in real personal income of -1.1%, and an unemployment rate of 8.3%. This forecast reflects improvement of Hawaii’s economy compared to the prior forecast as the U.S. visitor market outperforms expectations with visitor arrivals reaching an all-time high in July and accommodation occupancy rates reaching 80%. However, the economy experienced a downturn due to the Delta variant of COVID-19 causing record virus numbers and implementation of preventative policies that resulted in visitor arrivals falling sharply. The international market continues to be much slower to return and is anticipated to return in 2022 at half its pre-pandemic levels. A full economic recovery is still forecasted to be several years out.
Although the Company expects economic conditions to improve going forward, if economic conditions worsen from current levels or remain depressed for an extended period of time, it could have a material unfavorable impact on the Company’s net revenues or income from continuing operations in 2021.
“Other” segment.
 Three months ended September 30Nine months ended September 30
(in thousands)2021202020212020Primary reason(s)
Revenues$1,197 $215 $3,266 $237 Increase in other sales at Pacific Current subsidiaries.
Operating loss(2,933)(4,457)(14,946)(12,854)
The third quarters of 2021 and 2020 include $1.3 million and $0.2 million, respectively, of operating income from Pacific Current1. Third quarter 2021 corporate expense was $0.4 million lower than the same period of 2020, primarily due to a decrease in administrative and general expenses. The first nine months of 2021 and 2020 include $2.6 million and $2.0 million, respectively, of operating income from Pacific Current1. Corporate expenses for the first nine months of 2021 was $2.7 million higher than the same period in 2020, primarily due to higher incentive compensation, higher charitable contribution expense related to an obligation to make matching contributions under a settlement agreement with the former President and Chief Executive Officer of the Bank and higher charitable donations, due to timing of contributions.
Net loss (6,192)(7,183)(23,061)(20,885)
The net loss for the third quarter of 2021 was lower than the net loss for the third quarter of 2020 and net loss for the first nine months of 2021 was higher than the net loss for the first nine months of 2020 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 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 subsidiaries, Mauo, LLC (Mauo), which owns solar-plus-storage projects totaling 8.6 MW on five University of Hawaii campuses, ‘Alenuihāhā Developments, LLC, which owns a collection of renewable energy assets, Ka‘ie‘ie Waho Company, LLC, which owns a 6 MW solar photovoltaic system that provides renewable energy to Kauai Island Utility Cooperative, and Ka‘aipua‘a, LLC, which is constructing a wastewater treatment and energy recovery facility on Hawaii island; as well as eliminations of intercompany transactions.

FINANCIAL CONDITION
Liquidity and capital resources.  As of September 30, 2021, there was no balance on HEI’s revolving credit facility or Hawaiian Electric’s revolving credit facility and the available committed capacity under the facilities was $175 million and $200 million, respectively. On April 19, 2021, Hawaiian Electric’s $75 million 364-day revolving credit agreement terminated
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and was not renewed. At the end of the quarter, HEI and Hawaiian Electric had approximately $92 million and nil of commercial paper outstanding, respectively. As of September 30, 2021, ASB’s unused FHLB borrowing capacity was approximately $2.0 billion and ASB had unpledged investment securities of $2.5 billion that were available to be used as collateral for additional borrowing capacity.
The Company expects that its liquidity will continue to be moderately impacted at the Utilities due to COVID-19. For the Utilities, the elevated level of unemployment in the state and the moratorium on customer disconnections (which ended on May 31, 2021) have resulted in higher accounts receivable balances and bad debt expense and may result in higher write-offs in the future. As of September 30, 2021, approximately $39 million of the Utilities’ accounts receivables were 30 days past due. Of the over 30 days past due amounts, approximately 64% were on payment plans. In addition, 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 section below). At this time, the delay in customer cash collections has not significantly affected the Company’s liquidity. The Company is prepared to address, if needed, the potential financing requirement related to the delayed timing of customer collections. At ASB, liquidity remains at satisfactory levels largely due to U.S. economic stimulus programs implemented as a result of COVID-19 that led to a substantial increase in customer deposits. ASB’s cash and cash equivalents was $190 million as of September 30, 2021, compared to $293 million as of December 31, 2020. ASB remains well above the “well capitalized” level under the FDIC Improvement Act prompt correction action capital category, and while the economic outlook has improved and is expected to continue to improve, there are still COVID-19 related business restrictions that remain in place that could create ongoing uncertainty regarding COVID-19’s impact on loan performance and the allowance for credit losses (see “Recent Developments — COVID-19” in the Bank section below).
On May 14, 2021, HEI and Hawaiian Electric each entered into a separate agreement with a syndicate of nine financial institutions (the HEI Facility and Hawaiian Electric Facility, respectively, and together, the Facilities), to amend and restate their respective previously existing unsecured revolving credit agreements. The HEI Facility was increased to $175 million from $150 million and its term was extended to May 14, 2026. The $200 million Hawaiian Electric Facility has an initial term that expires May 13, 2022, but its term will extend to May 14, 2026 upon approval by the PUC during the initial term, which approval is currently being requested.
On September 29, 2021, HEI executed a $125 million private placement utilizing a delayed draw feature, which allows HEI to draw $75 million and $50 million at any time on or before December 29, 2021 and November 15, 2022, respectively. Proceeds from the notes, when drawn, will ultimately be used to invest in the Utilities’ equity, refinance a portion of HEI’s $150 million long-term notes maturing in November 2022, and used for other general corporate purposes. The ability to draw at any time prior to the December 29, 2021 and November 15, 2022 dates will provide additional liquidity in the interim period. The notes bear interest at a weighted average rate of 3.10% and a weighted average maturity of 15.7 years. See “HEI Private Placement” in Note 5 of the Condensed Consolidated Financial Statements.
As of September 30, 2021 and December 31, 2020, the total amount of available borrowing capacity (net of commercial paper outstanding) under the Company’s committed lines of credit was approximately $283 million and $360 million, respectively.
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 an 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.
The consolidated capital structure of HEI (excluding deposit liabilities and other bank borrowings) was as follows:
(dollars in millions)September 30, 2021December 31, 2020
Short-term borrowings—other than bank$92 2 %$129 3 %
Long-term debt, net—other than bank2,245 47 2,119 46 
Preferred stock of subsidiaries34 1 34 1 
Common stock equity2,384 50 2,338 50 
 $4,755 100 %$4,620 100 %
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HEI’s commercial paper borrowings and line of credit facility were as follows:
 Average balanceBalance
(in millions) Nine months ended September 30, 2021September 30, 2021December 31, 2020
Commercial paper$53 $92 $65 
Line of credit draws— — — 
Undrawn capacity under HEI’s line of credit facility 175 150 
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 short-term commercial paper borrowings during the first nine months of 2021 was $102 million.
On March 17, 2021, S&P revised HEI’s outlook to stable from positive and affirmed the “BBB-” issuer credit rating and “A-3” short-term and commercial paper ratings. On April 20, 2021, Moody’s upgraded HEI’s short-term rating for commercial paper to “P-2” from “P-3” and revised the outlook to stable from positive. On June 25, 2021, Fitch affirmed HEI’s “BBB” long-term issuer default rating, “F3” short-term issuer default rating and stable outlook.
There were no new issuances of common stock through the HEI Dividend Reinvestment and Stock Purchase Plan (DRIP), HEIRSP or the ASB 401(k) Plan in the nine months ended September 30, 2021 and 2020 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 2021, net cash provided by operating activities of HEI consolidated was $267 million. Net cash used by investing activities for the same period was $985 million, primarily due to capital expenditures, ASB’s purchases of available-for-sale and held-to maturity investment securities, partly offset by ASB’s receipt of investment security repayments and maturities, proceeds from the sale of investment securities, net decrease in loans and sale of residential loans. Net cash provided by financing activities during this period was $596 million as a result of several factors, including net increases in ASB’s deposit liabilities and other bank borrowings, the issuances of long-term debt and net increases in short-term borrowings, partly offset by repayment of short-term and long-term debt and payment of common stock dividends. During the first nine months of 2021, Hawaiian Electric and ASB (through ASB Hawaii) paid cash dividends to HEI of $84 million and $40 million, respectively.
Dividends.  The payout ratios for the first nine months of 2021 and full year 2020 were 58% and 73%, respectively. On February 9, 2021, the HEI Board of Directors approved a 1 cent increase in the quarterly dividend from $0.33 per share to $0.34 per share, starting with the dividend in the first quarter of 2021. 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, current and expected future economic conditions, including impacts from the COVID-19 pandemic, and capital investment alternatives.
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.
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 42 to 44, 58 to 59, and 72 to 74 of HEI’s MD&A included in Part II, Item 7 of HEI’s 2020 Form 10-K.
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.
In the third quarter of 2021, the State of Hawaii experienced a rapid rise in COVID-19 case counts primarily due to the Delta variant. As a result, additional preventative restrictions, such as limits to gathering sizes, were put in place to slow the spread of COVID-19. In September, the City and County of Honolulu launched the Safe Access program, which requires proof of the COVID-19 vaccine or a negative test, taken within the last 48 hours, to be shown in order to enter certain establishments, such as restaurants and bars. The governor of the State of Hawaii also made an announcement to encourage tourists to postpone their trips to later in the year. As a result of these measures and the requirement for employees of certain governmental agencies and private businesses to be vaccinated or regularly tested, case counts have trended down from the high in early September.
In the third quarter of 2021, the demand for electricity has increased from 2020 levels, however, sales remain below the kWh sales levels achieved for the same period in 2019. In the third quarter of 2021, kWh sales were up 4.4% compared with the same quarter in 2020, however, they were 9.2% below the same quarter in 2019. The Utilities expect kWh sales to continue to improve in the remainder of the year as COVID-19 vaccination levels increase, allowing government restrictions to be lifted.
While the Utilities’ electric energy revenues have not been 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 (2.5% for Hawaiian Electric, 3.75% for Hawaii Electric Light and 3.0% for Maui Electric). As of September 30, 2021, the RBA balance was approximately $29.7 million, compared to $7.6 million as of December 31, 2020. The billed accounts receivable balance, net of allowance for doubtful accounts, of $174 million, as of September 30, 2021, is 17.9% higher than the billed accounts receivable balance as of December 31, 2020, and the past due accounts receivable balance has increased by $6.9 million or 14% since December 31, 2020 with a corresponding increase in the number of accounts past due by approximately 5% for the same period. The increase in accounts receivables was primarily driven by higher fuel prices, as well as lower cash receipts associated with the auto-enrollment of customers in payment plans, starting in July 2021 through mid-September 2021, under which the past due balances are recovered over a 12-month period. While the moratorium on customer disconnections ended on May 31, 2021, the Utilities initially focused its efforts on working with customers to enroll in payment plans and seek other bill assistance for customers through funding from non-profit organizations, as well as state and county relief programs. Starting in September 2021, the Utilities have begun the disconnection process for those customers that have not enrolled in payment plans or that have not adhered to their payment plans beginning with the largest and oldest amounts in arrears. At this time, the delay in customer cash collections has not significantly affected the Utilities’ liquidity. The Utilities are prepared to address, if needed, 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. 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.
In the second quarter of 2020, the PUC approved the deferral of certain COVID-19 related costs, 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, 2021, these costs, which have been deferred and recorded as a regulatory asset, totaled approximately $28.7 million (see also discussion under Item 1A. “Risk Factors” and “Regulatory assets for COVID-19 related costs” in Note 3 of the Condensed Consolidated Financial Statements). The Utilities have approval to defer COVID-19 related costs through December 31, 2021. The Utilities will be seeking recovery
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of the deferred costs in a separate proceeding. Looking forward, while the distribution and administration of the COVID-19 vaccine has allowed for fewer restrictions and a partial reopening of the Hawaii economy, a worsening of COVID-19 case counts or a prolonged period of current COVID-19 restrictions 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. Additionally, while the state’s aggressive response to the pandemic has managed to control 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 future rate increases. See “Item 1A. Risk Factors” in Part II for additional discussion of risks.
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
20212020(decrease)(dollars in millions, except per barrel amounts)
$679 $563 $117 
Revenues. Net increase largely due to:
$83 
net of higher fuel oil prices and lower kWh generated1
39 
higher purchased power energy prices and higher kWh purchased2
2 lower ERP system implementation benefits to be passed on to the customers in future rates
1 
higher PPAC revenue2
(8)decrease related solely to a change in the timing for revenue recognition within the year, which eliminates seasonality in recognizing target revenues and results in recognizing revenues evenly throughout the year with target revenues recognized on an annual basis remaining unchanged
181 105 76 
Fuel oil expense1. Net increase largely due to higher fuel oil prices and lower fuel efficiency due to planned maintenance outages of certain generating units, partially offset by lower kWh generated
186 149 37 
Purchased power expense1, 2. Increase largely due to higher purchased power energy prices and higher kWh purchased
116 111 5 
Operation and maintenance expenses. Net increase largely due to:
3 more generating facility overhauls and maintenance work performed
1 higher outside service costs for Emergency Management System
1 ERP system costs amortization, which started for Hawaiian Electric in November 2020
1 higher medical premium costs due to a one-time credit in 2020
(1)lower labor expense
121 109 13 
Other expenses. Increase due to higher revenue taxes, coupled with higher depreciation expense in 2021 for plant investments in 2020
75 89 (15)
Operating income. Decrease due to change in timing for revenue recognition within the year, higher operation and maintenance expenses, coupled with higher depreciation expense
61 74 (13)
Income before income taxes. Decrease due to change in timing for revenue recognition within the year, higher operation and maintenance expense, higher interest expense related to new long term debt issued in January 2021, coupled with higher depreciation expense, partially offset by lower pension non-service costs
50 60 (10)
Net income for common stock. Decrease due to change in timing for revenue within the year, coupled with higher operating expense. See below for effective tax rate explanation
2,191 2,099 92 
Kilowatthour sales (millions)3
$86.77 $49.71 $37.06 Average fuel oil cost per barrel
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Nine months ended September 30Increase 
20212020(decrease)(dollars in millions, except per barrel amounts)
$1,846 $1,694 $152 
Revenues. Net increase largely due to:
$64 
higher purchased power energy prices and higher kWh purchased2
61 
net of higher fuel oil prices and lower kWh generated1
12 higher revenues from 2020 RAM adjustments
8 lower ERP system implementation benefits to be passed on to the customers in future rates
6 
higher PPAC revenue2
1 increase related solely to a change in the timing for revenue recognition within the year, which eliminates seasonality in recognizing target revenues and results in recognizing revenues evenly throughout the year with target revenues recognized on an annual basis remaining unchanged
447 391 57 
Fuel oil expense1. Net increase largely due to higher fuel oil prices and lower fuel efficiency due to planned maintenance outages of certain generating units, partially offset by lower kWh generated
491 426 65 
Purchased power expense1 ,2. Increase largely due to higher purchased power energy prices, higher kWh purchased and higher capacity and non-fuel O&M charges
349 349 — 
Operation and maintenance expenses.
4 more generating facility overhauls and maintenance work performed
3 ERP system costs amortization, which started for Hawaiian Electric in November 2020
1 expense due to decommissioning of combined heat and power unit on Lanai
(4)lower labor due to lower staffing and reduction in overtime
(4)lower pension service cost due to reset of pension cost included in rates as part of Hawaiian Electric final rate case decision
347 329 19 
Other expenses. Increase due to higher revenue taxes, coupled with higher depreciation expense in 2021 for plant investment in 2020
212 200 12 
Operating income. Increase due to higher RAM revenues, offset in part by higher depreciation expense
170 157 13 
Income before income taxes. Increase higher RAM revenues and lower pension non-service costs, partially offset by higher interest expense related to new long term debt issued in May 2020 and January 2021 and higher depreciation expense
136 126 9 
Net income for common stock. Increase due to higher RAM revenues and lower pension non-service costs, partially offset by higher operating expense.
6,126 5,979 147 
Kilowatthour sales (millions)3
$74.93 $64.70 $10.23 Average fuel oil cost per barrel
470,013 466,943 3,070 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 in 2021 were higher when compared to the same periods last year largely due to recovery from the initial impacts of the COVID-19 pandemic. An increase in visitor arrivals due to changes in the Safe Travels requirements allowing travelers to bypass the 10-day quarantine by taking a COVID-19 test or showing proof of vaccination for domestic travelers, led to a recovery in the tourism industry. However, in late August visitor arrivals fell when Governor Ige asked visitors not to visit Hawaii and implemented restrictions to combat rising COVID-19 case counts and hospitalizations due to a surge in the Delta variant. As restrictions ease, vaccination levels increase and more visitors arrive, sales are expected to slowly rebound but remain lower than pre-pandemic levels.

The Utilities’ effective tax rate for each of the third quarters of 2021 and 2020 was 17% and 19%, respectively. The Utilities’ effective tax rates for the first nine months of 2021 and 2020 were each 19%. The effective tax rate was lower for the third quarter of 2021 compared to the same period in 2020 due primarily to federal research and development tax credit claims in 2021, partially offset by lower amortization in 2021 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.
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Hawaiian Electric’s consolidated ROACE was 8.3% and 8.4% for the twelve months ended September 30, 2021 and September 30, 2020, respectively.
The net book value (cost less accumulated depreciation) of utility property, plant and equipment (PPE) as of September 30, 2021 amounted to $4.8 billion, of which approximately 26% related to generation PPE, 66% related to transmission and distribution PPE, and 8% related to other PPE. Approximately 9% 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.
Performance-based regulations. On December 23, 2020, the PUC issued a D&O (PBR D&O) approving a new performance-based regulation framework (PBR Framework). See “Regulatory proceedings” under “Commitments and contingencies” in Note 3 of the Condensed Consolidated Financial Statements.
Transition to a decarbonized and sustainable energy future.  The Utilities are fully committed to leading and enabling pathways to a decarbonized and sustainable energy future for Hawaii. The Utilities believe that a holistic approach to decarbonization is needed, and that such a strategy requires achieving the Utilities’ renewable energy commitments, facilitating and promoting beneficial electrification, and deploying carbon removal and offsets among other levers to reduce statewide emissions. Hawaii’s renewable portfolio standard law requires electric utilities to meet an RPS of 30%, 40%, 70% and 100% by December 31, 2020, 2030, 2040 and 2045, respectively. Hawaii law has also established a target of sequestering more atmospheric carbon and greenhouse gases than emitted within the State by 2045.
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 2020 was 34.5%, which exceeded the statutory 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 2020, a 1% shortfall in meeting the 2030 RPS requirement of 40% would translate into a penalty of approximately $1.6 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 the Utilities to limited commodity fossil fuel price exposure under a fuel cost risk-sharing mechanism. 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 $3.7 million.
The Utilities are fully aligned with, and supportive of, state policy to achieve a decarbonized future and have made significant progress in reducing emissions through renewable energy and electrification. 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 throughout its operations 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 are environmental and social costs 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 decarbonized 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
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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. Certain mechanisms were replaced or modified under the new PBR framework. See “Regulatory proceedings” under “Commitments and contingencies” and “Decoupling” in Note 3 of the Condensed Consolidated Financial Statements.
Integrated Grid Planning. Achieving high levels of 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 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 Advisory 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 August 2021, the Utilities submitted their Revised Inputs and Assumptions to the PUC for review and approval. Once approved by the PUC, the next phase of the process which includes the development of long-range integrated grid plans and the acquisition of new resources, will begin.
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.
On June 9, 2021, the PUC issued an order providing guidance to the third Grid Service RFP filed on February 23, 2021. The proposed Grid Service RFP focused only on Oahu and is seeking 60MW of grid services with focus on capacity reduction similarly in response to the potential reserve shortfall from the AES coal plant retirement scheduled on September 1, 2022. The Utilities filed a final draft and received PUC approval to proceed on August 3, 2021. The Utilities subsequently issued an approved Grid Services RFP and the bids were due on October 13, 2021.
On June 8, 2021, the PUC approved the new program, Emergency Demand Response Program (EDRP), a battery storage incentive program to dispatch electricity between 6 p.m. to 8 p.m. daily from participating residential and commercial customers, to address the potential reserve shortfalls following the AES coal plant retirement. The PUC approved EDRP for 50MW on Oahu with an incentive budget not to exceed $34 million, which will be recovered via a surcharge cost recovery mechanism over a 10-year amortization. The Utilities’ implementation plan was approved by the PUC on June 30, 2021, and the Utilities subsequently filed the updated EDRP tariffs on July 1, 2021. As of September 30, 2021, the Utilities have received and approved the applications worth up to 0.77 MW.
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 distributed energy resources and renewable energy integration. Under the Grid Modernization Strategy, the Utilities expect 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 are implementing Phase 1 of their Grid Modernization Strategy, 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, 2021, approximately $30 million has been incurred to date under Phase 1. The Utilities have deployed over 30,000 advanced meters since the beginning of 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. 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 supplement and update to the Grid Mod Phase 2 field devices application was filed on March 31, 2021. The estimated cost for the implementation over five years of the ADMS and field devices, which includes capital, deferred and O&M costs, is $105 million. A PUC order was issued on April 27, 2021, unsuspending and resuming consideration of the Phase 2 Application. The Utilities filed the reply statement of position on October 15, 2021, completing the discovery phase of the docket, with a PUC decision on the Phase 2 Application as the expected next and final step in the proceeding.
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
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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.
The second phase, which commenced on April 9, 2020, allows up to 235 MW across all Hawaiian Electric service territories in two tranches for small (under 250 kW) and large system sizes to encourage a variety of system sizes. 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. Proposed final drafts of the LMI RFPs, Molokai and Lanai RFPs tariff, and contracts were filed on September 8, 2020. Proposed final drafts of the remaining RFPs on Oahu, Maui and Hawaii Island were filed on December 1, 2020.
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. See “Developments in renewable energy efforts–Requests for renewable proposals, expressions of interest, and information” for additional information.
The Utilities have been working on interconnection improvements and proposed several ways to potentially improve the time and cost of interconnection during the development of the CBRE Phase 2 tariff and RFPs. Additionally, the Utilities increased their focus and attention on this area and worked with the parties, including the CBRE Independent Observer, to make the interconnection process more transparent, predictable and standardized, including interconnection costs, timelines and requirements in order to reduce costs and accelerate schedules. In addition, the Utilities researched interconnection solutions in other jurisdictions, and worked with the parties to identify additional improvements. The Utilities solicited from the parties a list of recommended improvements, and consolidated and adopted nearly all the near-term and continuous improvement recommendations from the parties. The Utilities filed these recommendations and associated updates to the previously filed RFPs, tariff, and contracts on March 30, 2021.
On July 27, 2021 the PUC issued an order approving the RFPs for Oahu, Maui, Hawaii Island, and Lanai, as well as the LMI RFPs with certain modifications and ordered the Utilities to hold a community meeting for Molokai. On August 6, 2021, the Utilities filed a motion for clarification regarding the PUC’s July 27, 2021 order. On August 11, the Utilities held a community meeting regarding the Molokai RFP. On August 25, 2021, the Utilities filed their final versions of the Oahu, Maui, Hawaii Island, Lanai and LMI RFPs. On August 31, 2021, the Utilities filed the final draft of the Molokai RFP. On September 1, 2021, community members on Oahu submitted a letter to the PUC asking the PUC to pause CBRE to allow for more community input into the program. On September 3, 2021, the PUC issued a clarifying order in response to the Utilities’ motion for clarification and ordering a pause on CBRE for at least 45 days to allow for further time for community engagement and to allow for further revisions to the RFP documents requested by the PUC. The order issued on September 3, 2021 included language seeming to require the inclusion of projects under 250 kW for the island of Molokai. On September 13, 2021, the Utilities filed another motion for clarification regarding this requirement. On October 13, 2021, the PUC held a community meeting regarding CBRE for the island of Oahu. The PUC has indicated that it is also in the process of scheduling community meetings for Maui and Hawaii island. The PUC has not yet issued next steps pending the scheduling of these meetings.
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 opened a proceeding to investigate establishment of a microgrid services tariff, pursuant to Act 200 of 2018. There are currently five intervenors in the docket, although initially there were eight. In August 2019, the PUC issued an order, focusing for the remainder of the docket, to facilitate the ability of microgrids to disconnect from the grid and provide backup power to customers and critical energy uses during contingency events.
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Two Working Groups were formed: (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 Services Tariff and updated language for various distributed energy resources Rules on March 30, 2020. Parties to the docket filed comments on and proposed revisions to the Draft Tariff on April 27, 2020.
On November 30, 2020, the PUC held a technical conference to present its proposed redlines to Utilities’ Draft Microgrid Services Tariff and related documents. On February 1, 2021, the Working Group filed its Draft Microgrid Tariff. Members of the Working Group separately filed their positions on areas of disagreements and later commented on other parties’ positions on areas of disagreements on February 10, 2021 and February 17, 2021, respectively.
On May 17, 2021, the PUC issued an order, directing the Utilities to submit the Microgrid Services Tariff and appendices consistent with the revisions provided by the PUC. Furthermore, the PUC stated it intends to issue a separate order to govern the next phase of the Microgrid Tariff proceeding. On May 27, 2021, the Utilities filed the Microgrid Service Tariff.
On September 21, 2021, the PUC provided guidance for Phase 2 of the Microgrid Tariff proceeding, and instructed Parties to recommend priority topics, along with supporting rationale to better inform the topics that will be discussed during this phase of the proceeding by October 21, 2021.
Regulated returns. As part of the PBR Framework’s annual review cycle, the Utilities 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. The D&O in the PBR proceeding modified the earnings sharing mechanism to a symmetric arrangement. Effective with annual earnings for 2021, the earnings sharing will be triggered for achieved rate-making ROACE outside of a 300 basis points dead band above and below the current authorized rate-making ROACE of 9.5% for each of the Utilities. Earnings sharing credits or recoveries will be included in the biannual report (formally known as annual decoupling filing) to be filed with the PUC in the spring of the following year. Results for 2020, 2019 and 2018 did not trigger the earnings sharing mechanism for the Utilities.
Actual and PUC-allowed returns, as of September 30, 2021, were as follows:
%Rate-making Return on rate base (RORB)*ROACE**Rate-making ROACE***
Twelve months ended 
September 30, 2021
Hawaiian ElectricHawaii Electric LightMaui ElectricHawaiian ElectricHawaii Electric LightMaui ElectricHawaiian ElectricHawaii Electric LightMaui Electric
Utility returns7.40 6.34 6.24 8.77 7.40 7.14 9.65 7.85 7.75 
PUC-allowed returns7.37 7.52 7.43 9.50 9.50 9.50 9.50 9.50 9.50 
Difference0.03 (1.18)(1.19)(0.73)(2.10)(2.36)0.15 (1.65)(1.75)
*      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 factors contributing to the difference between PUC-allowed ROACEs and the ROACEs actually achieved include the 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 return on capital additions since the last rate case in excess of indexed escalations.
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Most recent rate proceedings.  As of September 30, 2021, 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 4.110.507.97$2,477 57.15Yes
Final Decision and Order10/22/200.00.09.507.37NA57.15
Hawaii Electric Light        
2019 2
Request 12/14/18$13.4 3.410.508.30$537 56.91Yes
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’s proposed RBA provision tariff and ECRC tariff submitted on November 6, 2020 were approved by the PUC on December 11, 2020. The proposed RBA provision tariff and ECRC tariff took effect on January 1, 2021.
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 became effective on January 1, 2021.
See also “Most recent rate proceedings” in Note 3 of the Condensed Consolidated Financial Statements.
On December 23, 2020, the PBR D&O was issued, establishing a new PBR Framework. The PBR Framework implemented a five-year multi-year rate period (MRP), during which there will be no general rate case applications. In the fourth year of the MRP, the PUC will comprehensively review the PBR Framework to determine if any modifications or revisions are appropriate.
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:
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. Hawaiian Electric reconductored the 46kV circuit and in December 2020, the project reached commercial operation.
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. These appeals are still ongoing.
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. In June 2021, the Supreme Court denied LOL’s appeal.
•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. On March 31, 2021, the PUC suspended the docket pending the completion of a supplemental environmental review under the Hawaii Environmental Policy Act (HEPA). On April 12, 2021, Hawaii Electric Light filed a motion for reconsideration and clarification in the
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proceeding. On June 4, 2021, the PUC lifted the docket suspension for the limited purpose of soliciting the Department of Land and Natural Resources (DLNR) and the County of Hawaii’s (County) position on the environment review. In June and July 2021, the DLNR and the County responded to the PUC indicating their respective agencies do not have discretionary approval over the project and are not in a position to conduct an environmental review under HEPA. On October 8, 2021, PGV sent a letter to the Office of Planning and Sustainable Development of the State of Hawaii (OPSD), requesting OPSD determine and designate an approving agency/accepting authority to process any environmental review under HEPA that may be required in connection with the repowering of PGV’s geothermal facility. On October 14, 2021, Hawaii Electric Light sent a letter to OPSD noting that Hawaii Electric Light is not opposed to PGV’s request to OPSD, but continues to assert that the PUC Order is incorrect in determining that the ARPPA is a “project” subject to HEPA and characterizing Hawaii Electric Light as the “applicant” for any anticipated HEPA review. Hawaii Electric Light further noted that it would be requesting the PUC to concurrently lift the suspension of the ARPPA approval docket in order to move the docket forward concurrently with the OPSD Request and any subsequent HEPA review.
Tariffed renewable resources.
•As of September 30, 2021, there were approximately 539 MW, 116 MW and 130 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, 2021, an estimated 32% 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, 2021, there were 43 MW, 3 MW and 4 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 three-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 and has been extended for one year through December 2022. 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 2023. On June 30, 2021, the Utilities issued an RFP for all fuels, including biodiesel, for supply commencing January 1, 2023.
•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 2022, 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 Hawaii Island, and 60 MW of renewable generation on Maui. As of September 30, 2021, summarized information for a total of 8 PPAs 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 Electric4139.5139.5/5587/31/22, 9/7/22, 9/30/22 & 8/31/2320 & 25$30.9 
Hawaii Electric Light26060/24011/3/22 & 12/2/222514.1 
Maui Electric27575/3004/28/23 & 10/27/232517.6 
Total8274.5274.5/1,098$62.6 
The Utilities have received PUC approvals to recover the total projected annual payment of $62.6 million for the eight PPAs through the PPAC to the extent such costs are not included in base rates.
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•In continuation of their February 2018 request for proposal process, the Utilities issued their Stage 2 Renewable RFPs for Oahu, Maui and Hawaii Island and Grid Services RFP on August 22, 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 were selected. On Maui, 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, three renewable plus storage projects have voluntarily withdrawn from the process for various reasons, including change in circumstances for the developer and a misunderstanding of contract requirements. As of September 30, 2021, the Utilities have filed 10 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. On October 25, 2021, one solar-plus-storage project on Hawaii Island was withdrawn by the developer.
A summary of the 9 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 Electric5232232/1,0555/17/23, 7/1/23, 10/30/23, 12/29/23 & 12/31/2320 & 25$62.0 
Hawaiian Electric1*N/A185/56512/30/222024.0 
Maui Electric3100100/4004/30/23 & 12/31/232528.2 
Total9332517/2,020$114.2 
* See further discussion under “Review of Interconnection Process and Kapolei Energy Storage Power Purchase Agreement” below.
As of September 30, 2021, the PUC approved six solar-plus-storage PPAs for a total of 297 MW, and one 185 MW standalone storage PPA. The total projected annual payment of $103 million for these PPAs will be recovered through the PPAC to the extent such costs are not included in base rates.
A summary of the GSPAs that were approved by PUC in December 2020 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 are pending PUC approval is as follows:
UtilitiesNumber of contractsBESS Size (MW/MWh)Guaranteed commercial operation dates
Hawaii Electric Light112/1212/30/22
Maui Electric140/1604/28/23
Total252/172
•On November 27, 2019, the Utilities issued RFPs for renewable generation paired with energy storage on the islands of Lanai and Molokai. The Utilities were seeking PV paired with storage or small wind (specified as 100 kW turbines or smaller) on Molokai and PV paired with storage on Lanai. The RFP on Lanai was postponed on January 14, 2020 to allow the Utility to re-evaluate the scope of the RFP in response to announced plans to remove two large resorts from the grid. Proposals for the Molokai RFP were received on February 14, 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 and subsequently postponed 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 May 21, 2021, the PUC approved the proposed combined Lanai RFP. 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. On August 25 and 31, 2021, the Utilities filed proposed final
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drafts of the CBRE RFPs, which included three dedicated Low-to-Moderate-Income RFPs on Oahu, Maui and Hawaii, three Tranche 1 RFPs on Oahu, Maui and Hawaii, a Molokai CBRE RFP, and a combined Lanai Variable and CBRE RFP. Since this filing, the PUC has paused the CBRE RFP development to hear additional community feedback on the various islands.
•The PUC issued a letter to the Utilities requesting development with a Stage 3 RFP on Hawaii Island on January 21, 2021. Per the PUC’s subsequent April 20, 2020 letter, the Hawaii Island Grid Needs Assessment was filed on July 15, 2021 and the draft RFP, including model contracts for PV+BESS, wind+BESS, standalone storage, firm renewable generation, and distributed energy resources aggregators, was filed on October 15, 2021. The requirements in the Stage 3 RFP are guided by the results of the Grid Needs Assessment.
Review of Interconnection Process and Kapolei Energy Storage Power Purchase Agreement.
•In February 2021, the PUC initiated a docket for the purposes of reviewing the status and interconnection progress of various utility-related renewable projects (i.e. Stage 1 and Stage 2 RFP PPAs and CBRE) and the Utilities’ transition plans for the expiration of the AES power purchase agreement, the retirement of the Kahului Power Plant, and other fossil fuel power plant transition plans, as needed. The Utilities filed initial status updates on the project timelines, steps needed for each of the renewable projects to achieve commercial operation and steps the Utilities are taking to address projected extensions of guaranteed commercial operation dates (GCOD) for renewable projects under development, which are due to a variety of factors, including those outside of the control of the Utilities. The PUC subsequently held status conferences on the Utilities’ updates. In April 2021, the PUC issued an Order directing the Utilities to establish regulatory liabilities for the difference between the on-peak avoided cost and the unit price included in the applications for approval of the renewable project PPAs, effective with the GCOD included in the applications (the earliest GCOD included in the applications is July 2021) or from the date of the Order for CBRE Phase 1 projects. The amount of regulatory liabilities to be recorded in future periods are not determinable at this time and would be affected by a number of factors, including the length of the GCOD extension period, the monthly on-peak avoided cost, as well as the factors described above. The Utilities filed a Motion for Reconsideration of the entire Order, or in the alternative to clarify that at most the PUC is directing the Utilities to track the information and not record the information at this time. The Utilities further requested a Stay of the Order pending resolution of the Motion. The Utilities maintain that extensions of GCODs are allowed under the PUC-approved contracts and that the Order has the unintended consequence of imposing penalties against the Utilities without due process. In May 2021, the PUC issued an order clarifying its Order and directed the Utilities to track costs to consumers caused by the perceived delay of renewable projects, and that the PUC does not intend to, at this time, impose any penalties on the Utilities. The full text of the Order, Motion for Reconsideration and request for a Stay of the Order, and clarification Order can be found on the PUC website at dms.puc.hawaii.gov/dms (Docket No. 2021-0024).
•Also in April 2021, the PUC approved the Kapolei Energy Storage (KES) PPA (one of the PPAs as a result of the Stage 2 Renewable RFP process) (KES Decision and Order), subject to nine conditions, including the Utilities forgoing the second portion of the PIM rewards amounting up to $1.7 million for the Stage 1 RFP PPAs, removing grid constraints for the Utilities’ CBRE Phase 2 projects and for existing and new distributed energy programs, financial retirement of Hawaiian Electric generating units by specified dates and adjusting target revenues at the retirement dates for such retirements, and a requirement to charge the batteries in the project using significant levels of renewable energy generation. The financial retirement of the generating units described in the KES Decision and Order is contrary to the intent of Hawaii Revised Statutes §269-6(d), which encourages the recovery of stranded costs for the retirement of fossil fuel generation, and contrary to the regulatory compact under which in return for agreeing to commit capital necessary to allow utilities to meet their obligation to serve, utilities are assured recovery of their investment and a fair opportunity to earn a reasonable return on the capital prudently committed to the business. Hawaiian Electric filed a Motion for Reconsideration and Stay of the Decision and Order due to potentially significant financial and operational impacts. In May 2021, the PUC granted, in part, Hawaiian Electric’s Motion for Reconsideration and Stay. In this Order, the PUC addressed a number of Hawaiian Electric’s concerns, including removing the condition of the Utilities foregoing the PIM award from Stage 1 RFP projects, agreeing to address grid constraint concerns in respective DER and CBRE dockets and not in the KES docket, removing the minimum thresholds of charging energy coming from renewable energy generation and corresponding deadlines associated with these thresholds and modifying the condition on financial retirement of generating units. The PUC indicated the net book value of generating assets would be addressed at the time of retirement. The full text of the KES Decision and Order and the Motion for Reconsideration and Stay with respect thereto, and the Order granting, in part, Hawaiian Electric’s Motion for Reconsideration can be found on the PUC website at dms.puc.hawaii.gov/dms (Docket No. 2020-0136).
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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 Hawaii 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. On June 30, 2021, the Utilities issued two RFPs for all fuels for supply commencing January 1, 2023. 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 LSFO 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 Hawaii at the established pricing, and purchases in excess of that volume (tier-2) either from PAR Hawaii 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 early 2022 for a 50-year term after a one-year transition period. Under the contract, Hawaiian Electric will make initial capital upgrades over the first six years of the contract and replacement 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. As of September 30, 2021, there was no outstanding balance on Hawaiian Electric’s revolving credit facility and no commercial paper borrowings by the Utilities.
On January 14, 2021, the Utilities received $115 million of proceeds using a delayed draw feature under a private placement executed on October 29, 2020. The proceeds were used to finance capital expenditures and reimburse funds used for the payment of capital expenditures.
The Utilities believe that their ability to generate cash, both internally from operations and externally from issuances of equity and debt securities, as well as bank borrowings, is adequate to maintain sufficient liquidity to fund their contractual obligations and commercial commitments, their forecasted capital expenditures and investments, their expected retirement benefit plan contributions and other cash requirements. However, the COVID-19 pandemic is an evolving situation, and the Utilities cannot predict the extent or duration of the outbreak, the future effects that it will have on the global, national or local economy, including the impacts on the Utilities’ ability, as well as the cost, to access additional capital, or the future impacts on the Utilities’ financial position, results of operations, and cash flows.
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Hawaiian Electric’s consolidated capital structure was as follows:
(dollars in millions)September 30, 2021December 31, 2020
Short-term borrowings$— — %$50 1 %
Long-term debt, net1,676 43 1,561 41 
Preferred stock34 1 34 1 
Common stock equity2,194 56 2,142 57 
$3,904 100 %$3,787 100 %

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, 2021September 30, 2021December 31, 2020
Short-term borrowings1
   
Commercial paper$8 $— $— 
Borrowings from HEI— — — 
Line of credit draws— — — 
Undrawn capacity under line of credit facility/facilities— 200 275 
 
1   The maximum amount of external short-term borrowings by Hawaiian Electric during the first nine months of 2021 was approximately $50 million. As of September 30, 2021, Hawaii Electric Light and Maui Electric had short-term borrowings from Hawaiian Electric of $0.7 million and nil, respectively. In addition to the short-term borrowings above, on January 15, 2021, Hawaiian Electric paid off and terminated the $50 million term loan facility dated as of May 19, 2020.
Credit agreement. Hawaiian Electric has a $200 million line of credit facility with no amount outstanding at September 30, 2021. On June 25, 2021, Hawaiian Electric requested PUC approval of its third amended and restated revolving unsecured syndicated credit facility agreement, including approving extending its term to May 14, 2026 from May 13, 2022. See Note 5 of the Condensed Consolidated Financial Statements.
Credit ratings. On March 17, 2021, S&P upgraded Hawaiian Electric’s issuer credit rating to “BBB” from “BBB-”, upgraded the short-term and commercial paper ratings to “A-2” from “A-3” and revised the outlook to stable from positive. The rating upgrade was primarily based on Hawaiian Electric’s strong financial measures, strength of the cumulative value of the regulatory protections, and S&P’s assessment of its stand-alone credit profile as sufficient to rate Hawaiian Electric higher than HEI.
On April 20, 2021, Moody’s upgraded Hawaiian Electric’s senior unsecured rating and issuer rating to “Baa1” from “Baa2” and revised the outlook to stable from positive. The rating upgrade reflects Hawaiian Electric's considerable progress in adding renewable resources to its energy supply mix and the improving regulatory relationship with the PUC. On June 25, 2021, Fitch affirmed Hawaiian Electric’s “BBB+” long-term issuer default rating, “F2” short-term issuer default rating and stable outlook.
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, 2021, Hawaiian Electric had $6.3 million of undrawn funds remaining with the trustee. Hawaii Electric Light and Maui Electric had no undrawn funds as of September 30, 2021.
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 February 9, 2021, the PUC approved the Utilities’ request to issue SPRBs (up to $100 million, $35 million and $45 million for Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively) through 2022, with the proceeds to be
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used to finance the Utilities’ multi-project capital improvement programs. The PUC also approved the use of the expedited approval procedure to request the issuance and sale of the remaining/unused amount of SPRBs authorized by the 2019 Legislative Authorization (i.e., total not to exceed up to $400 million for Hawaiian Electric, up to $150 million for Hawaii Electric Light, and up to $150 million for Maui Electric) during the period January 1, 2023 through June 30, 2024.
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.
As of September 30, 2021, 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 issued on January 14, 202160 30 25 
Remaining authorized amounts $135 $85 $45 
On September 30, 2021, the Utilities requested PUC approval through the expedited approval process to issue taxable debt (Hawaiian Electric up to $30 million, Hawaii Electric Light up to $30 million and Maui Electric up to $35 million) prior to December 31, 2022.
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, 2021, Hawaiian Electric, Hawaii Electric Light, and Maui Electric have $275.8 million, $102.5 million, and $87.8, 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, 2019 and 2020154.2 7.5 22.2 
Remaining authorized amounts $275.8 $102.5 $87.8 

Cash flows. The following table reflects the changes in cash flows for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020:
Nine months ended September 30
(in thousands)20212020Change
Net cash provided by operating activities$198,256 $244,955 $(46,699)
Net cash used in investing activities(197,589)(260,187)62,598 
Net cash provided by (used in) financing activities(21,213)23,596 (44,809)

Net cash provided by operating activities. The decrease in net cash provided by operating activities was driven by lower cash receipts from customers due to the impact of the pandemic, and higher cash paid for fuel stock due to higher fuel oil prices and volume purchased, partially offset by lower cash paid for accounts payable due to timing.
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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 decrease in net cash provided by financing activities was primarily driven by lower net cash from long-term and short-term debts.
Forecast capital expenditures. For the three-year period 2021 through 2023, the Utilities forecast up to $1.2 billion of net capital expenditures, which could change over time based upon external factors such as the timing and scope of environmental regulations and/or 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 2021 to 2023 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.
In the first half of 2021, economic conditions in Hawaii continued to improve following the rollout of stimulus programs and the loosening of business restrictions, both of which boosted economic activity. However, in the third quarter of 2021, COVID-19 case counts across the nation, and in Hawaii, rapidly increased. As a result of the rapid increase and the resulting stress placed on the healthcare system in Hawaii, additional restrictions were implemented, such as the Safe Access program on Oahu.
Interest rates across the curve remain at relatively low levels and the steepness of the yield curve flattened in the third quarter of 2021, which continues to negatively impact net interest margin as new loan origination rates remain below existing portfolio yields. In third quarter of 2021, the bank’s net interest margin was 2.90% compared to 2.98% and 3.12% for the quarters ended June 30, 2021 and September 30, 2020, respectively.
On a year-to-date basis, the investment securities portfolio increased approximately 40% as deposit growth of 8%, which included funds from stimulus programs that were provided to individuals and businesses, continued to outpace loan growth. The growth in the investment securities portfolio and fees from the PPP program contributed to higher interest income, partially offsetting the effect of lower loan portfolio balances and earning asset yields on a year-to-date basis.
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 September 30, 2021, approximately $1 million of loans remained in their active deferral period. Approximately $11 million of loans were not able to resume their contractual payments and were considered delinquent as of September 30, 2021.
ASB recorded a $2 million negative provision for credit losses that reduced the allowance for credit losses, reflecting upgrades in the commercial and commercial real estate loan portfolios and overall lower net charge offs. For the nine months ended September 30, 2021, the bank recorded a negative provision for credit losses of $22 million. The provision for credit losses in future quarters will be dependent on future economic conditions and changes to borrower credit quality at that time.
In 2020, ASB 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 since reopened seven of the branches that were temporarily closed and permanently closed eight branches. Three of the reopened branches are now digital branches, which provides digital solutions such as full-service ATMs and access to expert bankers through videoconferencing tools while allowing ASB to have a more efficient physical footprint . 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 continues to evaluate its branch network to determine whether further changes may be appropriate given its customers’ use of other banking channels.
ASB’s senior management team continually addresses the impacts to the operations and business of the bank as a result of the pandemic and meets regularly 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 on March 27, 2020. The CARES Act provided 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 and the Economic Aid Act was signed into law on December 27, 2020, which amended some of the prior rules and guidelines of the CARES Act. The Economic Aid Act established a second round of PPP, reopening the PPP for first-time borrowers and allowing for a second draw for businesses that meet more restrictive eligibility criteria to target businesses hardest hit by the pandemic. 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 generally have 24 weeks from disbursement of the loan 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. Small businesses may receive partial forgiveness if they do not spend the entirety of their PPP loan on eligible expenses, or if less than 60% of the loan disbursement is spent on payroll costs. Employers had until December 31, 2020 to restore their workforce, or, for a PPP loan made after December 27, 2020, before the last day of the Covered Period. Lenders processed and approved the
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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. During the first round of PPP, the Bank secured more than $370 million in PPP loans for approximately 4,100 small businesses that supported over 40,000 jobs; ASB received processing fees totaling approximately $13 million and started recognizing these fees over the life of the loans. During the second round of PPP, ASB secured more than $175 million for approximately 2,200 small businesses that supported more than 20,000 jobs; ASB received processing fees of approximately $9 million. The remaining PPP loans outstanding as of September 30, 2021 was $137 million.
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.
Three months ended September 30Increase
(in millions)20212020(decrease)Primary reason(s)
Interest and dividend income$61 $60 $1 
Average loan portfolio yields 4 basis points lower—impacted by the continued low interest rate environment as adjustable rate loans have repriced lower during the past year and new loan production yields continue to originate below their portfolio yields. PPP loan fees as a result of portfolio repayments partially offset the impact of low interest rate environment.
Average loan portfolio balances decreased $251 million - commercial, home equity lines of credit and consumer loan portfolio balances decreased by $282 million, $186 million and $76 million, respectively. The decrease in the commercial loan portfolio was primarily due to the repayments of the PPP loan portfolio. The decrease in the home equity line of credit and consumer loan portfolios were due to ASB’s strategic decision to reduce production of these loans in the economic environment during the COVID-19 pandemic. Average commercial real estate loan portfolio balance increased $247 million due to demand for this loan type. Residential loan portfolio balance increased $40 million due to ASB’s decision to portfolio a larger portion of its residential loan production.
Average investment securities portfolio balance increased $1.4 billion—excess liquidity from strong deposit growth invested in agency securities.
Average investment securities yields 17 basis points lower—impacted by the continued low interest rate environment as new investment security purchase yields were lower than the investment security portfolio yields.
Noninterest income15 19 (4)
Lower mortgage banking income - lower residential loan sale volume due to ASB’s decision to portfolio a larger portion of the residential loan production and lower residential loan profit margin in 2021 compared to 2020.
Higher customer fee income - lower fee income in 2020 was primarily due to ASB’s decision to waive overdraft and other deposit account fees to accommodate the hardships customers were experiencing during the COVID-19 pandemic.
Revenues76 79 (3)
The decrease in revenues for the three months ended September 30, 2021 compared to the same period in 2020 was primarily due to lower noninterest income partly offset by higher interest income.
Interest expense1 2 (1)
Lower interest expense on deposits—lower term certificate balances due to runoff of government term certificates and lower deposit yields as a result of the continued low interest rate environment..
Average core deposit balances increased $1 billion; average term certificate balances decreased $130 million.
Average deposit yields decreased from 13 basis points to 6 basis points.
Lower interest expense on other borrowings—primarily due to lower repurchase agreement yields as a result of the continued low interest rate environment.
Provision for credit losses(2)14 (16)
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Three months ended September 30Increase
(in millions)20212020(decrease)Primary reason(s)
Negative provision for credit losses reflects credit upgrades in the commercial real estate and commercial loan portfolios.
Negative provision for credit losses also due to a shift in mix - lower personal unsecured loan portfolio balances which had higher credit loss rates replaced with residential and commercial real estate loan portfolios with lower credit loss rates.
Additional provision for credit losses for the retail loan portfolios based on the recent surge in COVID-19 infections and a delay in Hawaii’s economic recovery.
Delinquency rates have increased—from 0.31% at September 30, 2020 to 0.37% at September 30, 2021 due to higher residential 1-4 family loan delinquencies, partly offset by lower personal unsecured and home equity lines of credit loan delinquencies.
Net charge-off to average loans have decreased—from 0.32% at September 30, 2020 to 0.03% at September 30, 2021 due to lower personal unsecured loan portfolio net charge-offs.
Noninterest expense52 47 5 Higher compensation and benefits expenses—increase in performance-based compensation.
Expenses51 63 (12)
The decrease in expenses for the three months ended September 30, 2021 compared to the same period in 2020 was due to lower provision for credit losses and lower interest expense partly offset by higher noninterest expenses.
Operating income25 16 9 
The increase in operating income for the three months ended September 30, 2021 compared to the same period in 2020 was primarily due to higher interest income, lower provision for credit losses and lower interest expense, partly offset by lower noninterest income and higher noninterest expenses.
Net income19 12 7 
The increase in net income for the three months ended September 30, 2021 compared to the same period in 2020 was primarily due to higher operating income, partly offset by higher income tax expense.
 Nine months ended September 30Increase 
(in millions)20212020(decrease)Primary reason(s)
Interest and dividend income$182 $184 $(2)
Average loan portfolio yields 22 basis points lower—impacted by the continued low interest rate environment as adjustable rate loans have repriced lower during the past year and new loan production yields continue to originate below their portfolio yields. PPP loan fees as a result of portfolio repayments partially offset the impact of low interest rate environment.
Average loan portfolio balances decreased $68 million - home equity lines of credit and consumer loan average loan portfolio balances decreased $183 million and $86 million, respectively - ASB’s strategic decision to reduce production of these loans in the economic environment during the COVID-19 pandemic. Commercial loan portfolio average balance decreased $22 million primarily due to repayments in the commercial markets loan portfolio. Commercial real estate loan portfolio average balance increased $225 million due to demand for this loan type.
Average investment securities portfolio balance increased $1.3 billion—excess liquidity from strong deposit growth invested in agency securities.
Average investment securities yields 51 basis points lower—impacted by the continued low interest rate environment as new investment security purchase yields were lower than the investment security portfolio yields.
Noninterest income49 58 (9)
Lower gain on sale of investment securities - in 2020, ASB sold all of its Visa Class B restricted shares and $160 million of investment securities with no similar sales in 2021.
Lower mortgage banking income - lower residential loan sale volume due to ASB’s decision to portfolio a larger portion of the residential loan production and lower residential loan sale profit margin in 2021 compared to 2020.
Higher customer fee income - lower fee income in 2020 was primarily due to ASB’s decision to waive overdraft and other deposit account fees to accommodate the hardships customers were experiencing during the COVID-19 pandemic.
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 Nine months ended September 30Increase 
(in millions)20212020(decrease)Primary reason(s)
Less: gain on sale of investment securities, net(1)(9)8 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 after operating income as a separate line item and excluded from Revenues.
Revenues230 233 (3)
The decrease in revenues for the nine months ended September 30, 2021 compared to the same period in 2020 was primarily due to lower interest and noninterest income, partly offset by lower reclassification of gain on sale of investment securities.
Interest expense4 9 (5)
Lower interest expense on deposits—lower term certificate balances due to runoff of government term certificates and lower deposit yields as a result of the continued low interest rate environment.
Average core deposit balances increased $1.2 billion; average term certificate balances decreased $202 million.
Average deposit yields decreased from 18 basis points to 7 basis points.
Lower interest expense on other borrowings—primarily due to lower repurchase agreement yields as a result of the continued low interest rate environment.
Provision for credit losses(22)40 (62)
Negative provision for credit losses reflects improvement in economic outlook, strong credit results including lower net charge-offs and improved credit loss rates which included credit upgrades in the commercial real estate and commercial loan portfolios.
Negative provision for credit losses also due to lower personal unsecured loan portfolio balances which had higher credit loss rates and improving net charge-off trends in the portfolio.
2020 provision for credit losses included $23 million COVID-19 related reserves and loss reserves for $17 million for net charge-offs as well as other changes in loan portfolio composition and asset quality metrics.
Delinquency rates have increased—from 0.31% at September 30, 2020 to 0.37% at September 30, 2021 due to higher residential 1-4 family loan delinquencies, partly offset by lower personal unsecured and home equity line of credit loan delinquencies.
Net charge-off to average loans have decreased—from 0.41% at September 30, 2020 to 0.08% at September 30, 2021 due to lower personal unsecured loan portfolio net charge-offs.
Noninterest expense147 142 5 
Higher compensation and benefits expenses—increase in incentive compensation payout for commission based employees, higher performance-based compensation and payment of the separation and release agreement with the former President and Chief Executive Officer.
Current year noninterest expense benefited from a one-time credit adjustment for a change in accounting for the ASB retirement plan.
Lower other expenses - 2020 expenses included higher direct and incremental COVID-19 related costs1 to enhance cleaning and sanitation of ASB’s facilities as well as incremental compensation expense.
Expenses129 191 (62)
The decrease in expenses for the nine months ended September 30, 2021 compared to the same period in 2020 was due to lower provision for credit losses and lower interest expense, partly offset by higher noninterest expenses.
Operating income101 42 59 
The increase in operating income for the nine months ended September 30, 2021 compared to the same period in 2020 was primarily due to lower provision for credit losses and lower interest expense, partly offset by lower interest and noninterest income and higher noninterest expenses.
Gain on sale of investment securities, net1 9 (8)The decrease in gain on sale of investment securities - primarily due to the sale of ASB’s Visa Class B restricted shares in 2020 with no similar sales in 2021.
Net income79 42 37 
Net income for the nine months ended September 30, 2021 was higher than the same period in 2020 due to higher operating income, partly offset by lower gain on sale of investment securities and higher income tax expense.

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1 Higher operating expenses in 2020, 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.
                      
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
(%)2021202020212020
Return on average assets0.86 0.61 1.21 0.73 
Return on average equity10.26 6.75 14.31 7.95 
Net interest margin2.90 3.12 2.94 3.34 
Three months ended September 30
20212020
(dollars in thousands)Average
balance		Interest
income/
expense		Yield/
rate (%)		Average
balance		Interest
 income/
expense		Yield/
rate (%)
Assets:
Interest-earning deposits$77,991 $30 0.15 $252,738 $64 0.10 
FHLB stock10,002 76 3.01 9,891 83 3.31 
Investment securities
Taxable2,959,102 11,625 1.57 1,598,389 6,922 1.73 
Non-taxable63,823 336 2.10 27,917 193 2.70 
Total investment securities3,022,925 11,961 1.58 1,626,306 7,115 1.75 
Loans
Residential 1-4 family2,198,089 19,531 3.55 2,158,258 21,085 3.91 
Commercial real estate1,194,776 9,846 3.24 947,337 8,207 3.41 
Home equity line of credit866,755 6,791 3.11 1,052,607 8,201 3.10 
Residential land19,020 269 5.66 13,574 187 5.51 
Commercial773,548 8,988 4.62 1,055,190 8,119 3.06 
Consumer126,821 4,078 12.76 202,844 6,642 13.03 
Total loans 1,2
5,179,009 49,503 3.80 5,429,810 52,441 3.84 
Total interest-earning assets 3
8,289,927 61,570 2.96 7,318,745 59,703 3.25 
Allowance for credit losses(78,258)(81,055)
Noninterest-earning assets739,522 764,504 
Total assets$8,951,191 $8,002,194 
Liabilities and shareholder’s equity:
Savings$3,129,166 $204 0.03 $2,715,445 $424 0.06 
Interest-bearing checking1,240,159 61 0.02 1,130,053 92 0.03 
Money market202,073 31 0.06 165,330 86 0.21 
Time certificates466,343 880 0.75 596,601 1,685 1.12 
Total interest-bearing deposits5,037,741 1,176 0.09 4,607,429 2,287 0.20 
Advances from Federal Home Loan Bank54 — 0.30 30,283 27 0.36 
Securities sold under agreements to repurchase and federal funds purchased89,540 5 0.02 65,988 34 0.20 
Total interest-bearing liabilities5,127,335 1,181 0.09 4,703,700 2,348 0.20 
Noninterest bearing liabilities:
Deposits2,899,005 2,421,842 
Other173,842 156,687 
Shareholder’s equity751,009 719,965 
Total liabilities and shareholder’s equity$8,951,191 $8,002,194 
Net interest income$60,389 $57,355 
Net interest margin (%) 4
2.90 3.12 
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Nine months ended September 30
20212020
(dollars in thousands)Average
balance		Interest
income/
expense		Yield/
rate (%)		Average
balance
Interest
 income/
expense
Yield/
rate (%)
Assets:      
Interest-earning deposits$65,133 $61 0.12 $173,151 $216 0.16 
FHLB stock10,398 251 3.23 9,639 236 3.27 
Investment securities
Taxable2,688,906 30,761 1.53 1,444,895 21,919 2.02 
Non-taxable49,520 805 2.16 28,463 719 3.32 
Total investment securities2,738,426 31,566 1.54 1,473,358 22,638 2.05 
Loans   
Residential 1-4 family2,164,829 58,592 3.61 2,170,785 64,642 3.97 
Commercial real estate1,152,716 28,392 3.26 927,901 26,014 3.70 
Home equity line of credit898,304 21,118 3.14 1,080,914 25,894 3.20 
Residential land17,782 683 5.12 13,650 568 5.55 
Commercial892,181 28,179 4.21 914,431 22,535 3.28 
Consumer141,800 13,569 12.79 228,280 21,917 12.82 
Total loans 1,2
5,267,612 150,533 3.81 5,335,961 161,570 4.03 
Total interest-earning assets 3
8,081,569 182,411 3.01 6,992,109 184,660 3.52 
Allowance for credit losses(90,347)  (77,891)  
Noninterest-earning assets743,611   756,882   
Total assets$8,734,833   $7,671,100   
Liabilities and shareholder’s equity:      
Savings$3,029,335 $594 0.03 $2,554,376 $1,583 0.08 
Interest-bearing checking1,214,136 178 0.02 1,091,944 415 0.05 
Money market191,092 99 0.07 157,689 425 0.36 
Time certificates500,278 3,048 0.81 702,030 6,522 1.24 
Total interest-bearing deposits4,934,841 3,919 0.11 4,506,039 8,945 0.26 
Advances from Federal Home Loan Bank20,474 42 0.27 25,918 138 0.71 
Securities sold under agreements to repurchase and federal funds purchased83,453 13 0.02 83,148 311 0.50 
Total interest-bearing liabilities5,038,768 3,974 0.11 4,615,105 9,394 0.27 
Noninterest bearing liabilities:      
Deposits2,792,899   2,204,221   
Other166,285   148,547   
Shareholder’s equity736,881   703,227   
Total liabilities and shareholder’s equity$8,734,833   $7,671,100   
Net interest income $178,437   $175,266  
Net interest margin (%) 4
  2.94   3.34 
1   Includes loans held for sale, at lower of cost or fair value.
2   Includes recognition of net deferred loan fees of $3.9 million and $1.5 million for the three months ended September 30, 2021 and 2020, respectively, and $11.3 million and $2.1 million for the nine months ended September 30, 2021 and 2020, respectively,
together with interest accrued prior to suspension of interest accrual on nonaccrual loans. Includes nonaccrual loans.
3   For the three and nine months ended September 30, 2021 and 2020, 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.
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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 2020, the Federal Open Market Committee lowered its federal funds rate target range to 0% - 0.25% in response to the financial crisis caused by the COVID-19 pandemic, which resulted in a decrease in ASB’s net interest income and net interest margin. A prolonged low interest rate environment 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.
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. The HELOC portfolio makes up 17% 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. 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, 2021, approximately 33% of the portfolio balances were amortizing loans under the Fixed Rate Loan Option. A HELOC loan is typically in a subordinate lien position to a borrower’s first mortgage loan, however, approximately 58% of ASB’s HELOC loan portfolio is in a first lien position.
Attention had been given by regulators and rating agencies to the potential for increased exposure to credit losses associated with HELOCs 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.
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, 2021December 31, 2020
(dollars in thousands)Balance% of totalBalance% of total
U.S. Treasury and federal agency obligations$132,139 4 %$62,322 3 %
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies2,893,490 94 2,076,506 95 
Corporate bonds31,645 1 31,351 1 
Mortgage revenue bonds15,427 1 27,185 1 
Total investment securities$3,072,701 100 %$2,197,364 100 %
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 $590 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, 2021 ASB’s costing liabilities consisted of 98% deposits and 2% other borrowings compared to 99% deposits and 1% other borrowings as of December 31, 2020. The weighted average cost of deposits for the first nine months of 2021 and 2020 was 0.07% and 0.18%, respectively.
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Federal Home Loan Bank of Des Moines. As of September 30, 2021 and December 31, 2020, ASB had no advances outstanding at the FHLB of Des Moines. As of September 30, 2021, 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.
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, 2021, ASB had an unrealized loss, net of taxes, on available-for-sale investment securities (including securities pledged for repurchase agreements) in AOCI of $20.3 million compared to an unrealized gain, net of taxes, of $20.0 million as of December 31, 2020. 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 2021, ASB recorded a negative provision for credit losses of $22.0 million in the allowance for credit losses primarily due to improvement in the economic outlook, strong credit results including lower net charge-offs and credit upgrades in commercial real estate and commercial loan portfolios and due to lower personal unsecured loan portfolio balances which had higher credit loss rates. During the first nine months of 2020, ASB recorded a provision for credit losses of $35.2 million in the allowance for credit losses primarily due to increased loss reserves for the consumer loan portfolio, increased loss rates for the commercial and commercial real estate portfolios and reserves for forecasted deterioration due to the COVID-19 pandemic.
 Nine months ended September 30
Year ended
December 31, 2020
(in thousands)20212020
Allowance for credit losses, beginning of period$101,201 $53,355 $53,355 
Impact of adopting ASU No. 2016-13— 19,441 19,441 
Provision for credit losses(21,967)35,204 49,811 
Less: net charge-offs3,290 16,541 21,406 
Allowance for credit losses, end of period$75,944 $91,459 $101,201 
Ratio of net charge-offs during the period to average loans outstanding (annualized)0.08 %0.41 %0.40 %
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, 2021 and 2020, ASB recorded a recovery in the provision for credit losses for unfunded commitments of $0.4 million and a provision for credit losses for unfunded commitments of $4.3 million, respectively. As of September 30, 2021 and December 31, 2020, the reserve for unfunded loan commitments was $3.9 million and $4.3 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.”
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 had 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 was 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.
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As of September 30, 2021, the bank was in compliance with all of the minimum capital requirements under OCC regulations, and was categorized as “well capitalized” under the regulatory framework for prompt corrective action. Beginning in the second quarter of 2020, ASB adopted the community bank leverage ratio framework, which allowed it to report only on the community bank leverage ratio, but does not change minimum capital requirements under OCC regulations. At March 31, 2021, ASB’s leverage ratio was below the 8.5 percent requirement to qualify for abbreviated reporting under the community bank leverage framework for 2021 and started reporting its risk-based capital ratios in the third quarter of 2021.
FINANCIAL CONDITION
Liquidity and capital resources.
(dollars in millions)September 30, 2021December 31, 2020% change
Total assets$9,010 $8,397 7 
Investment securities3,073 2,197 40 
Loans held for investment, net5,046 5,233 (4)
Deposit liabilities7,977 7,387 8 
Other bank borrowings129 90 44 
As of September 30, 2021, ASB was one of Hawaii’s largest financial institutions based on assets of $9.0 billion and deposits of $8.0 billion.
As of September 30, 2021, ASB’s unused FHLB borrowing capacity was approximately $2.0 billion. As of September 30, 2021, ASB had commitments to borrowers for loans and unused lines and letters of credit of $2.1 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, 2021, net cash provided by ASB’s operating activities was $93 million. Net cash used during the same period by ASB’s investing activities was $780 million, primarily due to purchases of available-for-sale securities of $1.3 billion, purchases of held-to-maturity securities of $314 million, contributions to low income housing investments of $12 million, additions to premises and equipment of $9 million and a net increase in stock from the Federal Home Loan Bank of $1 million, partly offset by the receipt of investment security repayments and maturities of $499 million, proceeds from the sale of investment securities of $197 million, a net decrease in loans of $159 million, proceeds from the sale of residential loans of $17 million and proceeds from redemption of bank owned life insurance of $3 million. Net cash provided by financing activities during this period was $584 million, primarily due to increases in deposit liabilities of $590 million and a net increase in repurchase agreements of $40 million, partly offset by a net decrease in mortgage escrow deposits of $5 million and $40 million in common stock dividends to HEI (through ASB Hawaii).
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 and 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 investment security repayments and maturities 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).
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. As of September 30, 2021, ASB was well-capitalized (well-capitalized ratio requirements noted in parentheses) with a Tier-1 leverage ratio of 8.0% (5.0%), common equity Tier-1 ratio of 13.6% (6.5%), Tier-1 capital ratio of 13.6% (8.0%) and total capital ratio of 14.7% (10.0%). As of December 31, 2020, ASB was well-capitalized (well-capitalized ratio requirements noted in parentheses) with a Tier-1 leverage ratio of 8.4% (5.0%), respectively. 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).
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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 2020 Form 10-K (pages 74 to 76).
ASB’s interest-rate risk sensitivity measures as of September 30, 2021 and December 31, 2020 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, 2021December 31, 2020September 30, 2021December 31, 2020
+3005.6 %7.0 %15.1 %31.4 %
+2004.0 5.0 11.5 23.9 
+1002.3 2.7 6.9 14.0 
-100(2.3)(1.9)(14.4)(25.2)

ASB’s net interest income (NII) sensitivity profile was less asset sensitive as of September 30, 2021 as compared to December 31, 2020, primarily driven by the increase in market rates, growth in the fixed rate portion of the HELOC and residential mortgage portfolios, and core deposit funded investment securities purchases. The increase in market rates decreased prepayment expectations in the bank’s fixed-rate mortgage and mortgage-backed investment portfolios, driving decreased asset sensitivity. In addition, the fixed rate portion of the HELOC portfolio grew, contributing to decreased asset sensitivity. Lastly, the deployment of strong core deposit growth into new fixed-rate investment purchases further contributed to decreased sensitivity.
Economic value of equity (EVE) sensitivity decreased as of September 30, 2021 compared to December 31, 2020 as the duration of assets lengthened. The steepening of the yield curve led to slower prepayment expectations and lengthened 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 speed with which rates change, actual changes in ASB’s balance sheet and management’s responses to the changes in interest rates.
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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 2021 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 2021 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 2020 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
For information about Risk Factors, see pages 18 to 30 of HEI’s and Hawaiian Electric’s 2020 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.
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 2021 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, 202126,173$42.87—NA
August 1 to 31, 202118,443$43.91—NA
September 1 to 30, 2021154,393$42.87—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,” 20,134 of the 26,173 shares, 14,468 of the 18,443 shares and 133,402 of the 154,393 shares were purchased for the DRIP; 5,208 of the 26,173 shares, 3,076 of the 18,443 shares and 17,329 of the 154,393 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.

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Item 6. Exhibits
 
Letter Amendment effective October 15, 2021 to Master Trust Agreement (dated September 4, 2012) between HEI and ASB and Fidelity Management Trust Company
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  Chief Financial Officer and Treasurer
 (Principal Financial Officer of HEI)  (Principal Financial Officer of Hawaiian Electric)
   
   
Date: November 5, 2021 Date: November 5, 2021

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