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 March 31, 2023

 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. – 1099 Alakea Street, Suite 2200, 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)

Registrant	Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Hawaiian Electric Industries, Inc.	Common Stock, Without Par Value	HE	New 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 April 18, 2023
Hawaiian Electric Industries, Inc. (Without Par Value)	109,572,075	Shares
Hawaiian Electric Company, Inc. ($6-2/3 Par Value)	17,854,278	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 March 31, 2023

TABLE OF CONTENTS

 

Page No.
ii	Glossary of Terms
iv	Cautionary Note Regarding Forward-Looking Statements
	PART I. FINANCIAL INFORMATION
1	Item 1.	Financial Statements
		Hawaiian Electric Industries, Inc. and Subsidiaries
1		Condensed Consolidated Statements of Income (unaudited) - three months ended March 31, 2023 and 2022
2		Condensed Consolidated Statements of Comprehensive Income (unaudited) - three months ended March 31, 2023 and 2022
3		Condensed Consolidated Balance Sheets (unaudited) - March 31, 2023 and December 31, 2022
4		Condensed Consolidated Statements of Changes in Shareholders’ Equity (unaudited) - three months ended March 31, 2023 and 2022
5		Condensed Consolidated Statements of Cash Flows (unaudited) - three months ended March 31, 2023 and 2022
		Hawaiian Electric Company, Inc. and Subsidiaries
7		Condensed Consolidated Statements of Income (unaudited) - three months ended March 31, 2023 and 2022
7		Condensed Consolidated Statements of Comprehensive Income (unaudited) - three months ended March 31, 2023 and 2022
8		Condensed Consolidated Balance Sheets (unaudited) - March 31, 2023 and December 31, 2022
10		Condensed Consolidated Statements of Changes in Common Stock Equity (unaudited) - three months ended March 31, 2023 and 2022
11		Condensed Consolidated Statements of Cash Flows (unaudited) - three months ended March 31, 2023 and 2022
11		Notes to Condensed Consolidated Financial Statements (unaudited)
53	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations
53		HEI consolidated
58		Electric Utilities
72		Bank
78	Item 3.	Quantitative and Qualitative Disclosures About Market Risk
79	Item 4.	Controls and Procedures
	PART II.	OTHER INFORMATION
80	Item 1.	Legal Proceedings
80	Item 1A.	Risk Factors
80	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds
81	Item 6.	Exhibits
82	Signatures

i

Hawaiian Electric Industries, Inc. and Subsidiaries

Hawaiian Electric Company, Inc. and Subsidiaries

Form 10-Q—Quarter ended March 31, 2023

GLOSSARY OF TERMS

Terms	Definitions
ACL	Allowance for credit losses, which is the current credit loss standard, requires recording the allowance based on the expected loss model
AES Hawaii	AES Hawaii, Inc.
AOCI	Accumulated other comprehensive income/(loss)
ARA	Annual 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
CBRE	Community-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. and Pacific Current, LLC and its subsidiaries (listed under Pacific Current). The Old Oahu Tug Service, Inc. was dissolved in March 2022.
Consumer Advocate	Division of Consumer Advocacy, Department of Commerce and Consumer Affairs of the State of Hawaii
CSSM	Collective Shared Savings Mechanism
D&O	Decision and order from the PUC
DER	Distributed energy resources
DRIP	HEI Dividend Reinvestment and Stock Purchase Plan
ECRC	Energy cost recovery clause
EIP	2010 Equity and Incentive Plan, as amended and restated
EPA	Environmental Protection Agency — federal
EPRM	Exceptional Project Recovery Mechanism
EPS	Earnings per share
ESM	Earnings Sharing Mechanism
EVE	Economic value of equity
Exchange Act	Securities Exchange Act of 1934
FDIC	Federal Deposit Insurance Corporation
federal	U.S. Government
FHLB	Federal Home Loan Bank
FHLMC	Federal Home Loan Mortgage Corporation
FNMA	Federal National Mortgage Association
FRB	Federal Reserve Board
GAAP	Accounting principles generally accepted in the United States of America
GHG	Greenhouse gas
GNMA	Government National Mortgage Association
GSPA	Grid Services Purchase Agreement
Hamakua Energy	Hamakua Energy, LLC, an indirect subsidiary of Pacific Current
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.
HEI	Hawaiian Electric Industries, Inc., direct parent company of Hawaiian Electric Company, Inc., ASB Hawaii, Inc. and Pacific Current, LLC. The Old Oahu Tug Service, Inc. was dissolved in March 2022.
HEIRSP	Hawaiian Electric Industries Retirement Savings Plan
HELOC	Home equity line of credit
HPOWER	City and County of Honolulu with respect to a power purchase agreement for a refuse-fired plant
IIJA	Infrastructure Investment and Jobs Act
IPP	Independent power producer
IRLCs	Interest rate lock commitments
Kalaeloa	Kalaeloa Partners, L.P.
kWh	Kilowatthour/s (as applicable)
LMI	Low-to-moderate income
LTIP	Long-term incentive plan
Mahipapa	Mahipapa, LLC, a subsidiary of Pacific Current
Maui Electric	Maui Electric Company, Limited, an electric utility subsidiary of Hawaiian Electric Company, Inc.
Mauo	Mauo, LLC, a subsidiary of Pacific Current
MPIR	Major Project Interim Recovery
MRP	Multi-year rate period
MSRs	Mortgage servicing rights
MW	Megawatt/s (as applicable)
NII	Net interest income
NPBC	Net periodic benefit costs
NPPC	Net 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, Alenuihaha Developments, LLC, Kaʻieʻie Waho Company, LLC, Kaʻaipuaʻa, LLC, Upena, LLC and Mahipapa, LLC
PBR	Performance-based regulation
PIMs	Performance incentive mechanisms
PPA	Power purchase agreement
PPAC	Purchased power adjustment clause
PUC	Public Utilities Commission of the State of Hawaii
PV	Photovoltaic
RAM	Revenue adjustment mechanism
RBA	Revenue balancing account
RFP	Request for proposals
ROACE	Return on average common equity
RORB	Return on rate base
RPS	Renewable portfolio standards
SBA	Small Business Administration
SEC	Securities and Exchange Commission
See	Means the referenced material is incorporated by reference
SOFR	Secured Overnight Financing Rate
TDR	Troubled debt restructuring
Utilities	Hawaiian 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’ ability 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 ongoing impact of the COVID-19 pandemic, including any recurrence of the COVID-19 pandemic due to new variants and the potential reinstatement of related government orders and restrictions, and the resulting impact on our employees, customers and suppliers;

•ability to adequately address risks and capitalize on opportunities related to our environmental, social and governance 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 their 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, resilience and reliability objectives and renewable portfolio standards (RPS) and other climate-related 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, collateral underlying ASB loans 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 potential higher 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 and mortality improvements;

•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;

•increasing competition in the banking industry from traditional financial institutions as well as from non-traditional providers of financial services, including financial service subsidiaries of commercial and manufacturing companies (e.g., increased price competition for loans and deposits, or an outflow of deposits to alternative investments or platforms, which may have an adverse impact on ASB’s net interest margin and portfolio growth);

•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 or resilience proposals, among others, and related costs; reliance by the Utilities on outside parties such as the state, independent power producers (IPPs) and developers; supply-chain challenges; and

iv

uncertainties surrounding technologies, solar power, wind power, biofuels, environmental assessments required to meet RPS and other climate-related goals; the impacts of implementation of the renewable energy and resilience 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 required to be 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;

•high and/or volatile fuel prices, which increases working capital requirements and customer bills, or delivery of adequate fuel by suppliers (including as a result of the Russia-Ukraine war), which could affect the reliability of utility operations, 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), annual revenue adjustment (ARA) 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 kilowatt-hour sales;

•the ability of the Utilities to recover increasing costs and earn a reasonable return on capital investments not covered by the ARA, while providing the customer dividend required by performance-based regulation (PBR);

•the impact from the PUC’s implementation of PBR 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 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;

•unfavorable changes in economic conditions, such as sustained inflation, higher interest rates or recession, may negatively impact the ability of the Company’s customers to pay their utility bills or loan payments, reduce loan production, and increase operating costs of the Utilities or Bank that cannot be passed on to, or recovered, from customers;

•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 and related cost 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 subsidiaries (including at ASB branches and electric utility plants), its third-party service providers, contractors and customers with whom they have shared data (IPPs, distributed energy resources (DER) aggregators and customers enrolled under DER programs) 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 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 pricing or “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 levels, 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 supply chain issues; 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 March 31
(in thousands, except per share amounts)	2023		2022
Revenues
Electric utility	$	830,361	$	708,792
Bank	93,857		75,115
Other	4,019		1,161
Total revenues	928,237		785,068
Expenses
Electric utility	754,486		635,197
Bank	70,337		45,085
Other	9,896		5,510
Total expenses	834,719		685,792
Operating income (loss)
Electric utility	75,875		73,595
Bank	23,520		30,030
Other	(5,877)		(4,349)
Total operating income	93,518		99,276
Retirement defined benefits credit—other than service costs	1,152		1,243
Interest expense, net—other than on deposit liabilities and other bank borrowings	(28,798)		(24,349)
Allowance for borrowed funds used during construction	1,131		778
Allowance for equity funds used during construction	3,301		2,409
Gain on sales of equity-method investment	—		8,123
Income before income taxes	70,304		87,480
Income taxes	15,110		17,840
Net income	55,194		69,640
Preferred stock dividends of subsidiaries	473		473
Net income for common stock	$	54,721	$	69,167
Basic earnings per common share	$	0.50	$	0.63
Diluted earnings per common share	$	0.50	$	0.63
Weighted-average number of common shares outstanding	109,514		109,361
Net effect of potentially dilutive shares (share-based compensation programs)	311		273
Weighted-average shares assuming dilution	109,825		109,634

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2022 Form 10-K.

1

Hawaiian Electric Industries, Inc. and Subsidiaries

Condensed Consolidated Statements of Comprehensive Income (unaudited)

	Three months ended March 31
(in thousands)	2023		2022
Net income for common stock	$	54,721	$	69,167
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 $6,079 and $(44,079), respectively	16,605		(120,407)
Amortization of unrealized holding losses on held-to-maturity securities, net of taxes of $1,346 and nil, respectively	3,677		—
Derivatives qualifying as cash flow hedges:
Unrealized interest rate hedging gains arising during the period, net of taxes of $65 and $1,046, respectively	186		3,017
Reclassification adjustment to net income, net of taxes of $(17) and $19, respectively	(48)		55
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost, net of taxes of $(122) and $1,562, respectively	(357)		4,501
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $147 and $(1,500), respectively	425		(4,325)
Other comprehensive income (loss), net of taxes	20,488		(117,159)
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	$	75,209	$	(47,992)

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2022 Form 10-K.

2

Hawaiian Electric Industries, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets (unaudited) 

(dollars in thousands)	March 31, 2023		December 31, 2022
Assets
Cash and cash equivalents	$	315,334	$	199,877
Restricted cash	4,216		5,050
Accounts receivable and unbilled revenues, net	435,158		511,903
Available-for-sale investment securities, at fair value	1,419,755		1,429,667
Held-to-maturity investment securities, at amortized cost	1,238,185		1,251,747
Stock in Federal Home Loan Bank, at cost	10,000		26,560
Loans held for investment, net	5,988,058		5,906,690
Loans held for sale, at lower of cost or fair value	660		824
Property, plant and equipment, net of accumulated depreciation of $3,241,748 and $3,192,545 at March 31, 2023 and December 31, 2022, respectively	5,778,571		5,687,003
Operating lease right-of-use assets	110,920		115,684
Regulatory assets	247,902		242,513
Other	812,836		824,536
Goodwill	82,190		82,190
Total assets	$	16,443,785	$	16,284,244
Liabilities and shareholders’ equity
Liabilities
Accounts payable	$	237,822	$	251,460
Interest and dividends payable	41,382		21,333
Deposit liabilities	8,230,601		8,169,696
Short-term borrowings—other than bank	148,802		172,568
Other bank borrowings	680,690		695,120
Long-term debt, net—other than bank	2,480,948		2,384,980
Deferred income taxes	273,081		262,462
Operating lease liabilities	121,323		126,604
Finance lease liabilities	88,024		48,709
Regulatory liabilities	1,069,551		1,055,650
Defined benefit pension and other postretirement benefit plans liability	71,394		71,813
Other	727,919		787,057
Total liabilities	14,171,537		14,047,452
Preferred stock of subsidiaries - not subject to mandatory redemption	34,293		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: 109,572,075 shares and 109,470,795 shares at March 31, 2023 and December 31, 2022, respectively	1,692,390		1,692,697
Retained earnings	861,105		845,830
Accumulated other comprehensive loss, net of tax benefits	(315,540)		(336,028)
Total shareholders’ equity	2,237,955		2,202,499
Total liabilities and shareholders’ equity	$	16,443,785	$	16,284,244

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2022 Form 10-K.

3

Hawaiian Electric Industries, Inc. and Subsidiaries

Condensed Consolidated Statements of Changes in Shareholders’ Equity (unaudited) 

	Common stock			Retained		Accumulated other comprehensive
(in thousands)	Shares	Amount		Earnings		income (loss)		Total
Balance, December 31, 2022	109,471	$	1,692,697	$	845,830	$	(336,028)	$	2,202,499
Net income for common stock	—	—		54,721		—		54,721
Other comprehensive income, net of taxes	—	—		—		20,488		20,488
Share-based expenses and other, net	101	(307)		—		—		(307)
Common stock dividends (36¢ per share)	—	—		(39,446)		—		(39,446)
Balance, March 31, 2023	109,572	$	1,692,390	$	861,105	$	(315,540)	$	2,237,955
Balance, December 31, 2021	109,312	$	1,685,496	$	757,921	$	(52,533)	$	2,390,884
Net income for common stock	—	—		69,167		—		69,167
Other comprehensive loss, net of tax benefits	—	—		—		(117,159)		(117,159)
Share-based expenses and other, net	119	(949)		—		—		(949)
Common stock dividends (35¢ per share)	—	—		(38,301)		—		(38,301)
Balance, March 31, 2022	109,431	$	1,684,547	$	788,787	$	(169,692)	$	2,303,642

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2022 Form 10-K.

4

Hawaiian Electric Industries, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows (unaudited)

	Three months ended March 31
(in thousands)	2023		2022
Cash flows from operating activities
Net income	$	55,194	$	69,640
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation of property, plant and equipment	66,508		62,990
Other amortization	10,362		9,425
Provision for credit losses	1,175		(3,263)
Loans originated, held for sale	(5,450)		(73,931)
Proceeds from sale of loans, held for sale	5,662		75,629
Gain on sales of investment securities, net and equity-method investment	—		(8,123)
Gain on sale of loans, net	(130)		(1,077)
Deferred income taxes	(1,076)		(5,255)
Share-based compensation expense	2,031		2,117
Allowance for equity funds used during construction	(3,301)		(2,409)
Other	(988)		(2,552)
Changes in assets and liabilities
Decrease in accounts receivable and unbilled revenues, net	82,423		4,454
Decrease (increase) in fuel oil stock	33,429		(35,333)
Decrease (increase) in regulatory assets	(8,898)		(5,089)
Increase in regulatory liabilities	11,551		5,520
Increase in accounts, interest and dividends payable	24,748		71,490
Change in prepaid and accrued income taxes, tax credits and utility revenue taxes	(47,305)		(14,928)
Decrease in defined benefit pension and other postretirement benefit plans liability	(1,950)		(1,309)
Change in other assets and liabilities	(43,033)		(55,411)
Net cash provided by operating activities	180,952		92,585
Cash flows from investing activities
Available-for-sale investment securities purchased	—		(291,168)
Principal repayments on available-for-sale investment securities	32,484		104,654
Proceeds from repayments or maturities of held-to-maturity investment securities	17,938		4,547
Purchase of stock from Federal Home Loan Bank	(35,960)		—
Redemption of stock from Federal Home Loan Bank	52,520		—
Net decrease (increase) in loans held for investment	(68,871)		28,076
Purchase of loans held for investment	(13,012)		—
Capital expenditures	(124,297)		(79,163)
Contributions to low income housing investments	(418)		—
Other	2,148		5,340
Net cash used in investing activities	(137,468)		(227,714)

(continued)

5

Hawaiian Electric Industries, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows (unaudited) (continued)

	Three months ended March 31
(in thousands)	2023		2022
Cash flows from financing activities
Net increase in deposit liabilities	60,905		117,060
Net increase (decrease) in short-term borrowings with original maturities of three months or less	(88,666)		17,493
Net increase (decrease) in other bank borrowings with original maturities of three months or less	(564,430)		49,080
Proceeds from issuance of short-term debt	65,000		—
Proceeds from issuance of other bank borrowings	550,000		—
Proceeds from issuance of long-term debt	150,000		7,312
Repayment of long-term debt	(53,878)		(13,446)
Withheld shares for employee taxes on vested share-based compensation	(2,338)		(3,065)
Common stock dividends	(39,446)		(38,301)
Preferred stock dividends of subsidiaries	(473)		(473)
Other	(5,535)		(4,377)
Net cash provided by financing activities	71,139		131,283
Net increase (decrease) in cash, cash equivalents and restricted cash	114,623		(3,846)
Cash, cash equivalents and restricted cash, beginning of period	204,927		311,462
Cash, cash equivalents and restricted cash, end of period	319,550		307,616
Less: Restricted cash	(4,216)		(5,912)
Cash and cash equivalents, end of period	$	315,334	$	301,704

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2022 Form 10-K.

6

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidated Statements of Income (unaudited)

	Three months ended March 31
(in thousands)	2023		2022
Revenues	$	830,361	$	708,792
Expenses
Fuel oil	334,097		221,286
Purchased power	152,761		163,533
Other operation and maintenance	128,316		125,257
Depreciation	60,927		58,471
Taxes, other than income taxes	78,385		66,650
Total expenses	754,486		635,197
Operating income	75,875		73,595
Allowance for equity funds used during construction	3,301		2,409
Retirement defined benefits credit—other than service costs	1,047		990
Interest expense and other charges, net	(20,246)		(18,326)
Allowance for borrowed funds used during construction	1,131		778
Income before income taxes	61,108		59,446
Income taxes	13,600		12,538
Net income	47,508		46,908
Preferred stock dividends of subsidiaries	229		229
Net income attributable to Hawaiian Electric	47,279		46,679
Preferred stock dividends of Hawaiian Electric	270		270
Net income for common stock	$	47,009	$	46,409

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2022 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 March 31
(in thousands)	2023		2022
Net income for common stock	$	47,009	$	46,409
Other comprehensive income (loss), net of taxes:
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost, net of taxes of $(163) and $1,518, respectively	(470)		4,376
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $147 and $(1,500), respectively	425		(4,325)
Other comprehensive income (loss), net of taxes	(45)		51
Comprehensive income attributable to Hawaiian Electric Company, Inc.	$	46,964	$	46,460

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2022 Form 10-K.

7

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets (unaudited)

(dollars in thousands, except par value)	March 31, 2023		December 31, 2022
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	52,060	$	52,060
Plant and equipment	8,042,892		7,979,510
Right-of-use assets - finance lease	88,297		48,371
Less accumulated depreciation	(3,133,811)		(3,086,499)
Construction in progress	315,862		275,353
Utility property, plant and equipment, net	5,365,300		5,268,795
Nonutility property, plant and equipment, less accumulated depreciation of $64 and $63 as of March 31, 2023 and December 31, 2022, respectively	6,945		6,945
Total property, plant and equipment, net	5,372,245		5,275,740
Current assets
Cash and cash equivalents	116,022		39,242
Customer accounts receivable, net	235,305		288,338
Accrued unbilled revenues, net	160,532		183,280
Other accounts receivable, net	11,427		13,567
Fuel oil stock, at average cost	157,583		191,530
Materials and supplies, at average cost	84,093		79,568
Prepayments and other	43,909		33,482
Regulatory assets	64,973		52,273
Total current assets	873,844		881,280
Other long-term assets
Operating lease right-of-use assets	84,930		89,318
Regulatory assets	182,929		190,240
Other	160,515		160,889
Total other long-term assets	428,374		440,447
Total assets	$	6,674,463	$	6,597,467

(continued)

8

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets (unaudited) (continued)

(dollars in thousands, except par value)	March 31, 2023		December 31, 2022
Capitalization and liabilities
Capitalization
Common stock ($6 2/3 par value, authorized 50,000,000 shares; outstanding 17,854,278 shares at March 31, 2023 and December 31, 2022)	$	119,048	$	119,048
Premium on capital stock	810,955		810,955
Retained earnings	1,426,065		1,411,306
Accumulated other comprehensive income, net of taxes-retirement benefit plans	2,816		2,861
Common stock equity	2,358,884		2,344,170
Cumulative preferred stock — not subject to mandatory redemption	34,293		34,293
Long-term debt, net	1,734,347		1,584,854
Total capitalization	4,127,524		3,963,317
Commitments and contingencies (Note 3)
Current liabilities
Current portion of operating lease liabilities	18,414		19,095
Current portion of long-term debt, net	99,973		99,962
Short-term borrowings from non-affiliates	—		87,967
Accounts payable	191,769		202,492
Interest and preferred dividends payable	29,367		17,176
Taxes accrued, including revenue taxes	246,914		289,902
Regulatory liabilities	25,234		31,475
Other	86,580		85,596
Total current liabilities	698,251		833,665
Deferred credits and other liabilities
Operating lease liabilities	74,633		78,715
Finance lease liabilities	84,341		46,048
Deferred income taxes	384,953		384,430
Regulatory liabilities	1,044,317		1,024,175
Unamortized tax credits	93,445		95,300
Defined benefit pension and other postretirement benefit plans liability	49,388		49,748
Other	117,611		122,069
Total deferred credits and other liabilities	1,848,688		1,800,485
Total capitalization and liabilities	$	6,674,463	$	6,597,467

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2022 Form 10-K.

9

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidated Statements of Changes in Common Stock Equity (unaudited)

 

	Common stock			Premium on capital		Retained		Accumulated other comprehensive
(in thousands)	Shares	Amount		stock		earnings		income (loss)		Total
Balance, December 31, 2022	17,854	$	119,048	$	810,955	$	1,411,306	$	2,861	$	2,344,170
Net income for common stock	—	—		—		47,009		—		47,009
Other comprehensive loss, net of taxes	—	—		—		—		(45)		(45)
Common stock dividends	—	—		—		(32,250)		—		(32,250)
Balance, March 31, 2023	17,854	$	119,048	$	810,955	$	1,426,065	$	2,816	$	2,358,884
Balance, December 31, 2021	17,753	$	118,376	$	798,526	$	1,348,277	$	(3,280)	$	2,261,899
Net income for common stock	—	—		—		46,409		—		46,409
Other comprehensive income, net of taxes	—	—		—		—		51		51
Common stock dividends	—	—		—		(31,475)		—		(31,475)
Balance, March 31, 2022	17,753	$	118,376	$	798,526	$	1,363,211	$	(3,229)	$	2,276,884

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2022 Form 10-K.

10

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows (unaudited)

	Three months ended March 31
(in thousands)	2023		2022
Cash flows from operating activities
Net income	$	47,508	$	46,908
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation of property, plant and equipment	60,927		58,471
Other amortization	6,530		6,355
Deferred income taxes	(3,659)		(6,021)
State refundable credit	(2,874)		(2,759)
Bad debt expense	1,539		1,619
Allowance for equity funds used during construction	(3,301)		(2,409)
Other	350		(2)
Changes in assets and liabilities
Decrease in accounts receivable	60,939		16,236
Decrease (increase) in accrued unbilled revenues	22,659		(10,825)
Decrease (increase) in fuel oil stock	33,947		(35,294)
Increase in materials and supplies	(4,525)		(829)
Increase in regulatory assets	(8,898)		(5,089)
Increase in regulatory liabilities	11,551		5,520
Increase in accounts payable	6,588		29,624
Change in prepaid and accrued income taxes, tax credits and revenue taxes	(45,392)		(16,080)
Decrease in defined benefit pension and other postretirement benefit plans liability	(1,837)		(1,206)
Change in other assets and liabilities	(12,697)		(7,444)
Net cash provided by operating activities	169,355		76,775
Cash flows from investing activities
Capital expenditures	(122,139)		(76,358)
Other	1,545		1,494
Net cash used in investing activities	(120,594)		(74,864)
Cash flows from financing activities
Common stock dividends	(32,250)		(31,475)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(499)		(499)
Proceeds from issuance of long-term debt	150,000		—
Net increase (decrease) in short-term borrowings from non-affiliates and affiliates with original maturities of three months or less	(87,967)		6,000
Payments of obligations under finance leases	(575)		—
Other	(690)		—
Net cash provided by financing activities	28,019		(25,974)
Net increase (decrease) in cash, cash equivalents and restricted cash	76,780		(24,063)
Cash, cash equivalents and restricted cash, beginning of period	39,242		55,258
Cash, cash equivalents and restricted cash, end of period	116,022		31,195
Less: Restricted cash	—		(2,140)
Cash and cash equivalents, end of period	$	116,022	$	29,055

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2022 Form 10-K.

11

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, 2022.

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 March 31, 2023 and December 31, 2022 and the results of their operations and cash flows for the three months ended March 31, 2023 and 2022. All such adjustments are of a normal recurring nature, unless otherwise disclosed below or in other referenced material. Results of operations for interim periods are not necessarily indicative of results for the full year.

Recent accounting pronouncements.

Credit Losses. In March 2022, Financial Accounting Standards Board issued Accounting Standards Update (ASU) No. 2022-02, “Financial Instruments-Credit Losses (Topic 326): Troubled Debt Restructurings and Vintage Disclosures,” which eliminates the accounting guidance for Troubled Debt Restructurings (TDRs) by creditors in Subtopic 310-40, Receivables-Troubled Debt Restructurings by Creditors, while enhancing disclosure requirements for certain loan refinancings and restructurings by creditors when a borrower is experiencing financial difficulty. Specifically, rather than applying the recognition and measurement guidance for TDRs, an entity must apply the loan refinancing and restructuring guidance in paragraphs 310-20-35-9 through 35-11 to determine whether a modification results in a new loan or a continuation of an existing loan. The amendments in this update also require that an entity disclose current-period gross write-offs by year of origination for financing receivables and net investments in leases within the scope of Subtopic 326-20, “Financial Instruments-Credit Losses-Measured at Amortized Cost.” Gross write-off information must be included in the vintage disclosures required for public business entities in accordance with paragraph 325-20-50-6, which requires that an entity disclose the amortized cost basis of financing receivables by credit-quality indicator and class of financing receivable by year of origination. The amendments in this update are effective for fiscal years beginning after December 15, 2022, including interim periods within those fiscal years. ASB updated the accounting for certain loan refinancings and restructurings, and included the required disclosures in the Notes herein in accordance with ASU No. 2022-02.

12

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Note 2 · Segment financial information

(in thousands)	Electric utility		Bank		Other		Total
Three months ended March 31, 2023
Revenues	$	830,361	$	93,857	$	4,019	$	928,237
Income (loss) before income taxes	$	61,108	$	23,707	$	(14,511)	$	70,304
Income taxes (benefit)	13,600		5,145		(3,635)		15,110
Net income (loss)	47,508		18,562		(10,876)		55,194
Preferred stock dividends of subsidiaries	499		—		(26)		473
Net income (loss) for common stock	$	47,009	$	18,562	$	(10,850)	$	54,721
Total assets (at March 31, 2023)	$	6,674,463	$	9,610,070	$	159,252	$	16,443,785
Three months ended March 31, 2022
Revenues from external customers and other sources	$	708,788	$	75,115	$	1,165	$	785,068
Intersegment revenues (eliminations)	4		—		(4)		—
Revenues	$	708,792	$	75,115	$	1,161	$	785,068
Income (loss) before income taxes	$	59,446	$	30,215	$	(2,181)	$	87,480
Income taxes (benefit)	12,538		6,345		(1,043)		17,840
Net income (loss)	46,908		23,870		(1,138)		69,640
Preferred stock dividends of subsidiaries	499		—		(26)		473
Net income (loss) for common stock	$	46,409	$	23,870	$	(1,112)	$	69,167
Total assets (at December 31, 2022)	$	6,597,467	$	9,545,970	$	140,807	$	16,284,244

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.

13

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Note 3 · Electric utility segment

Unconsolidated variable interest entities.

Power purchase agreements.  As of March 31, 2023, the Utilities had four power purchase agreements (PPAs) for firm capacity 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) and Hamakua Energy by reason of the provisions of the PPA that the Utilities have with the two IPPs. However, management has concluded that the Utilities are not the primary beneficiary of Kalaeloa and Hamakua Energy because the Utilities do not have the power to direct the activities that most significantly impact the two 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 and Hamakua Energy in its condensed consolidated financial statements. However, 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 legal, regulatory and environmental 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. The Utilities record loss contingencies when the outcome of such proceedings is probable and when the amount of the loss is reasonably estimable. The Utilities also evaluate, on a continuous basis, whether developments in such proceedings could cause these assessments or estimates to change. Assessment regarding future events is required when evaluating whether a loss is probable or reasonably possible, and as to whether such loss or a range of such loss is estimable. Management is often unable to estimate a reasonably possible loss, or a range of loss, particularly in cases in which: (i) the damages sought are indeterminate or the basis for the damages claimed is not clear; (ii) proceedings are in early stages; (iii) discovery is not complete; (iv) the matters involve novel or unsettled legal theories; (v) significant facts are in dispute; (vi) a large number of parties are represented (including circumstances in which it is uncertain how liability, if any, would be shared among multiple defendants); (vii) a lower court or administrative agency’s decision or ruling has been appealed; and/or (vii) a wide range of potential outcomes exist. In such cases, there may be considerable uncertainty regarding the timing or ultimate resolution, including any possible loss, fine, penalty, or business impact.

Power purchase agreements.  Purchases from all IPPs were as follows:

	Three months ended March 31
(in millions)	2023		2022
Kalaeloa	$	67	$	60
AES Hawaii 1	—		27
HPOWER	18		19
Hamakua Energy	20		16
Puna Geothermal Venture	8		10
Wind IPPs	24		18
Solar IPPs	14		13
Other IPPs 2	2		1
Total IPPs	$	153	$	164

1 The term of the PPA with AES Hawaii expired on September 1, 2022 and the AES Hawaii coal plant ceased operations.

14

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

2 Includes 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. 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. The Amended and Restated PPA was approved by the PUC on November 23, 2022. The new pricing provisions in the Amended and Restated PPA took effect on January 1, 2023.

Stage 1 Renewable PPAs. In February 2018, the Utilities issued their Stage 1 renewable request for proposals and have procured eight renewable PPAs with a total of 274.5 MW capacity. The total annual payments to be made by the Utilities under the eight renewable PPAs are estimated at $64.5 million. The Utilities have received PUC approvals to recover the total projected annual payments under the eight renewable PPAs through the purchased power adjustment clause (PPAC) to the extent such costs are not included in base rates. As of March 31, 2023, the Utilities have accounted for the battery portion of two PPAs that were placed in service during 2022 and first quarter of 2023 as finance leases and recorded lease liabilities with corresponding right-of-use assets of $88 million. On April 21, 2023, the AES Waikoloa Solar project with a capacity of 30 MW, including 120 MWh of batteries, was placed into commercial operation on Hawaii Island, and the battery portion of the PPA will be recorded as a finance lease during the second quarter of 2023. The timing of the Utilities’ recognition of the expense conforms to ratemaking treatment for the Utilities’ recovery of the cost of electricity and is included in purchased power for the interest and amortization of financing leases related to PPAs. Any material differences between expense recognition and timing of payments is deferred as a regulatory asset or liability in order to match what is being recovered for ratemaking purposes.

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. On May 23, 2022, the PUC issued a decision and order denying the amended and restated PPA, based on, among other things, findings that: (1) the project will result in significant greenhouse gas (GHG) emissions, (2) Hu Honua’s proposed carbon commitment to sequester more GHG emissions than produced by the project are speculative and unsupported, (3) the amended and restated PPA is likely to result in high costs to customers through its relatively high cost of electricity and through potential displacement of other, lower cost, renewable resources, and (4) based on the foregoing, approving the amended and restated PPA is not prudent or in the public interest. On June 2, 2022, Hawaii Electric Light and Hu Honua filed their separate motions for reconsideration, which were denied by the PUC on June 24, 2022. On June 29, 2022, Hu Honua filed its notice of appeal to the Hawaii Supreme Court of the PUC’s May 23, 2022 decision and order denying the amended and restated PPA, and the PUC’s June 24, 2022 order denying Hawaii Electric Light and Hu Honua’s motions for reconsideration. Opening briefs were filed with the Supreme Court on October 5, 2022. Answering briefs were filed on December 5, 2022, and reply briefs were filed on December 28, 2022. The Supreme Court heard oral arguments on January 31, 2023. On March 13, 2023, the Hawaii Supreme Court affirmed the PUC’s decision denying the amended and restated PPA between Hu Honua and Hawaii Electric Light and entered its judgment on appeal on April 12, 2023.

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 a 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

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November 2020, respectively. The PUC required a minimum of $246 million ERP/EAM project-related benefit to be delivered to customers over the system’s 12-year service life.

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 other operation and maintenance (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 March 31, 2023, the Utilities’ regulatory liability was $11.0 million ($3.7 million for Hawaiian Electric, $2.9 million for Hawaii Electric Light and $4.4 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.

At the PUC’s direction, the Utilities have been filing Annual Enterprise System Benefits (AESB) report on the achieved benefits savings. The most recent AESB report was filed on February 14, 2023 for the period January 1 through December 31, 2022.

Waena Switchyard/Synchronous Condenser Project. In October 2020, to support efforts to increase renewable energy generation and reduce fossil fuel consumption by deactivating current generating units, Maui Electric filed a PUC application to construct a switchyard, which includes the extension of two 69 kV transmission lines and the relocation of another 69 kV transmission line; and the conversion of two generating units to synchronous condensers at Kahului Power Plant in central Maui. In November 2021, the PUC approved Maui Electric’s request to commit funds estimated at $38.8 million for the project, and to recover capital expenditures for the project under Exceptional Project Recovery Mechanism (EPRM) not to exceed $38.8 million, which shall be further reduced to reflect the total project cost exclusive of overhead costs not directly attributable to the project. The Waena Switchyard project is expected to be placed in service in the third quarter of 2023, while the conversion of the two generating units will be performed after the retirement of Kahului Power Plant Units 3 and 4.

In approving the project, the PUC recognized that the project will facilitate the ability to accommodate increased renewable energy, as contemplated under the EPRM guidelines. As of March 31, 2023, $17.1 million has been incurred for the project.

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 and left the property in 1987. The federal Environmental Protection Agency (EPA) has since identified environmental impacts in the subsurface soil at the Site. In cooperation with the Department of Health of State of Hawaii 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 $2.6 million as of March 31, 2023, representing the probable and reasonably estimable undiscounted cost for remediation of the Site and the adjacent parcel based on presently available information; however, final costs of remediation will depend on the cleanup approach implemented.

Additionally, on November 24, 2021, the current landowners of the Site, Misaki’s, Inc., filed a lawsuit against Hawaiian Electric (as alleged successor in interest to Molokai Electric, the prior owner of the Site) in the Circuit Court of the Second Circuit of the State of Hawaii (removed to the U.S. District Court for the District of Hawaii). The complaint, which was subsequently amended to include Maui Electric, alleges that Hawaiian Electric is responsible for remediation of the Site based on the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (CERCLA), and the Hawaii Environmental Response Law under Hawaii Revised Statutes Chapter 128D, as well as being liable on contractual claims related to a short leaseback period during the transition of ownership from Molokai Electric. The amended complaint was dismissed and a new complaint may be filed subject to the parties attempt to enter into settlement negotiations, but the Utilities

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intend to vigorously defend the action if necessary. At this time, the Utilities are unable to determine the ultimate outcome of the lawsuit or the amount of any possible loss. As of March 31, 2023, the reserve balance recorded by the Utilities to address the lawsuit was not material.

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 under CERCLA 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 March 31, 2023, the reserve account balance recorded by Hawaiian Electric to address the PCB contamination was $9.9 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. Decoupling delinks the utility’s revenues from the utility’s sales, removing the disincentive to promote energy efficiency and accept more renewable energy. Decoupling continues under the PBR Framework.

Performance-based regulation framework. On December 23, 2020, the PUC issued a decision and order (PBR D&O) establishing the PBR Framework to govern the Utilities. The PBR Framework incorporates an annual revenue adjustment (ARA) and a suite of new regulatory mechanisms in addition to previously established regulatory mechanisms. Under the PBR Framework, the decoupling mechanism (i.e., the Revenue Balancing Account (RBA)) established by the previous regulatory framework will continue. The existing cost recovery mechanisms will continue as currently implemented (e.g., the Energy Cost Recovery Clause, PPAC, Demand Side Management surcharge, Renewable Energy Infrastructure Program, Demand Response Adjustment Clause, Pension and Other Post-Employment Benefits (OPEB) tracking mechanisms). In addition to annual revenues provided by the ARA, the Utilities may seek relief for extraordinary projects or programs through the Exceptional Project Recovery Mechanism (EPRM) (formerly known as the Major Project Interim Recovery adjustment mechanism) and earn financial rewards for exemplary performance as provided through a portfolio of Performance Incentive Mechanisms (PIMs) and Shared Savings Mechanisms (SSMs). The PBR Framework incorporates a variety of additional performance mechanisms, including Scorecards, Reported Metrics, and an expedited Pilot Process. The PBR Framework also contains a number of safeguards, including a symmetric Earnings Sharing Mechanism (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 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 PBR Framework became fully effective on June 1, 2021.

On June 17, 2022, the PUC issued a decision and order (June 2022 D&O) establishing additional PIMs under the PBR Framework for the Utilities. The June 2022 D&O approved two new PIMs, a new SSM, and extended the timeframe for an existing PIM. Of the new PIMs, only one is penalty-only. Specifically, the PUC approved (1) a new (penalty-only) generation-caused interruption reliability PIM, (2) a new (penalty/reward) interconnection requirements study (IRS) PIM, (3) a new (reward-only) Collective Shared Savings Mechanism (CSSM), and (4) a modification and extension of the existing interim (reward-only) Grid Services PIM. On November 23, 2022, the PUC approved the Utilities’ proposed tariffs to implement the aforementioned PIMs with an effective date of January 1, 2023.

In addition, the June 2022 D&O instructed the Utilities to prepare and submit: a detailed fossil fuel retirement report (FF Retirement Report) outlining necessary steps to safely and reliably retire certain existing fossil fuel power plants during the first multi-year rate period (MRP); and a functional integration plan (FIP) for distributed energy resources (DER) to increase transparency into the Utilities’ plans and progress for utilizing cost-effective grid services from DERs and ensure that the necessary functionalities and requisite technologies are in place to do so. The PUC also instructed the PBR Working Group to continue its ongoing collaborative efforts to consider other potential new incentive mechanisms and to address other issues raised during the proceeding. On March 30, 2023, the PUC held a PBR Working Group coordination meeting to initiate subgroups on the priority topics of a long-term DER Grid Services PIM, modification to/evaluation of existing PIMs, and a comprehensive PBR Framework review to be addressed in the near term.

In accordance with the June 2022 D&O, the Utilities filed their FIP and FF Retirement Report with the PUC on September 30, 2022 and April 17, 2023, respectively.

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Revenue adjustment mechanism. Prior to the implementation of the PBR Framework, the revenue adjustment mechanism (RAM) was a major component of the previously established regulatory framework. The RAM was 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). Under the PBR Framework, the ARA mechanism replaced the RAM, and became effective on June 1, 2021. RAM revenue adjustments approved by the PUC in 2020 will continue to be included in the RBA provision’s target revenue and RBA rate adjustment unless modified with PUC approval.

Annual revenue adjustment mechanism. The PBR Framework established a five-year MRP 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% of adjusted revenue requirements compounded annually and a flow through of the “pre-PBR” savings commitment from the management audit recommendations developed in a prior docket at a rate of $6.6 million per year from 2021 to 2025. The implementation of the ARA occurred on June 1, 2021.

Earnings sharing mechanism. The PBR Framework established 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.

Exceptional project recovery mechanism. Prior to the implementation of the PBR Framework, the PUC established the Major Project Interim Recovery (MPIR) adjustment mechanism and MPIR Guidelines. The MPIR mechanism provides the opportunity to recover revenues for net costs of approved eligible projects placed in service between general rate cases. In establishing the PBR Framework, the MPIR Guidelines were terminated and replaced with the EPRM Guidelines. Although the MPIR Guidelines were terminated and replaced by the EPRM Guidelines, the MPIR mechanism will continue within the PBR Framework to provide recovery of project costs previously approved for recovery under the MPIR. The established EPRM Guidelines 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. Deferred and O&M expense projects are also eligible for EPRM recovery under the EPRM Guidelines. EPRM recoverable costs will be limited to the lesser of actual incurred project costs or PUC‑approved amounts, net of savings.

As of March 31, 2023, the Utilities annualized MPIR and EPRM revenue amounts totaled $26.2 million, including revenue taxes, for the Schofield Generating Station ($16.5 million), West Loch PV project ($3.5 million), Grid Modernization Strategy (GMS) Phase 1 project ($6.1 million for all three utilities) and Waiawa UFLS project ($0.1 million) that included the 2022 return on project amount (based on approved amounts) in rate base, depreciation and incremental O&M expenses. The PUC approved the Utilities’ recovery of the annualized 2022 MPIR amounts for the Schofield Generating Station, West Loch PV, and GMS Phase 1 projects effective June 1, 2022 through the RBA rate adjustment. Recovery of the incremental change to the West Loch PV project and Waiawa UFLS project were approved on December 7, 2022 and December 5, 2022, respectively.

As of March 31, 2023, the PUC approved two EPRM applications for projects totaling $41 million to the extent that the project costs are not included in rates. Currently, the Utilities are seeking EPRM recovery for six projects with total project costs up to $480 million, subject to PUC approval.

Pilot process. As part of the PBR Framework, the PUC approved a Pilot Process to foster innovation by establishing an expedited implementation process for pilots that tests new technologies, programs, business models, and other arrangements. Under the Pilot Process, the Utilities submit specific pilot proposals (Pilot Notices) that are within the scope of the approved Workplan to the PUC for their expedited review. The PUC will strive to issue an order addressing a proposed pilot within 45 days of the filing date of a Pilot Notice. If the PUC does not take affirmative action on a Pilot Notice by the end of the 45-day period, the Pilot Notice shall be considered approved as submitted. The PUC may modify the pilot as originally proposed, and the Utilities shall have 15 days to notify the PUC whether the Utilities accept the modification, propose further modification, or withdraw the Pilot Notice. The PUC may also, where necessary, suspend the Pilot Notice for further investigation.

The approved Pilot Process includes a cost recovery process that generally allows the Utilities to defer and recover total annual expenditures of approved pilot projects net of revenues, subject to an annual cap of $10 million, over 12 months beginning June 1 of the year following pilot implementation through the RBA rate adjustment, although the PUC may determine on a case-by-case basis that a particular project’s deferred costs should be amortized over a period greater than 12 months.

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On February 28, 2023, the Utilities filed their annual Pilot Update report covering pilot projects that were active during 2022, including reporting on pilot projects that were initiated prior to the commencement of the Pilot Process. The Pilot Update reported on approximately $0.4 million of 2022 recorded pilot project costs including revenue taxes for the Utilities. The 2022 recorded pilot project costs were included in the Utilities’ proposed adjustments to target revenue in the 2023 spring revenue report filed on March 28, 2023.

On February 2, 2023, the Utilities filed a Pilot Notice to commence an EV Telematics Pilot project in April 2023. On March 22, 2023, the PUC issued an order approving the Utilities’ EV Telematics Pilot project. The order also temporarily suspends the filing of Pilot Notices, pending a stakeholder meeting to be held in the second quarter of 2023, to discuss the Pilot Process and potential improvements.

Performance incentive mechanisms. The PUC has established the following PIMs and SSMs: (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, (4) new PIMs established in the PBR D&O and (5) new PIMs and a SSM established in the June 2022 D&O.

•Service Quality performance incentives (ongoing). Service Quality performance incentives are measured on a calendar-year basis. The PIM tariff requires the performance targets, deadbands and the amount of maximum financial incentives used to determine the PIM financial incentive levels for each of the PIMs to remain constant in interim periods, unless otherwise amended by order of the PUC.

•Service Reliability Performance measured by Transmission and Distribution-caused 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). For the 2022 evaluation period, the Utilities incurred $(0.1) million in penalties.

•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 eight 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).

•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. The first portion 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 2025.

•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. On July 9, 2020, the Utilities filed two Grid Services Purchase Agreements (GSPA) 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 one PPA that qualified for a PIM incentive and on February 16, 2021, the Utilities filed one additional PPA that qualified for a declining PIM incentive. The PUC approved two PPAs in September 2021 and November 2021 and two GSPAs on December 31, 2020. Based on the two approved PPAs, the Utilities recognized $0.1 million in rewards in 2021. In December 2022 and March 2023, these two PPAs were terminated or declared null and void.

•The PUC previously established the following two PIMs in its PBR D&O, which were approved in an order issued on March 23, 2021 and became effective on June 1, 2021. In its June 2022 D&O, the PUC modified and extended the Grid Services PIM.

•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 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 PIM that provides financial rewards on a $/kW basis for the acquisition of eligible grid services. The eligibility period for this PIM initially commenced on January 1, 2021 and was scheduled to end on

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December 31, 2022. However, the June 2022 D&O extended the eligibility period for this PIM through December 31, 2023. The June 2022 D&O also increased the incentive rate for the acquisition of load reduction grid services. During the PIM performance period, newly acquired committed capacity in the Oahu Scheduled Dispatch Program (SDP), the Oahu Fast DR program (up to the 7 MW cap), and the Maui SDP program shall qualify for the incentive. The Utilities can earn a maximum reward of $1.5 million from 2021 through 2023. In 2022, the Utilities earned $0.04 million in rewards.

•The PUC also previously established the following three 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 DER 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. In 2022, the Utilities earned $3.0 million in rewards.

•Low-to-Moderate Income (LMI) Energy Efficiency PIM that provides financial rewards 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. The Utilities earned $0.5 million in rewards for the program period ending 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.

•The PUC established the following new PIMs and SSM in its June 2022 D&O, which became effective on January 1, 2023.

•Generation-caused System Average Interruption Duration and Frequency Indexes PIMs to incentivize achievement of generation-based reliability targets, measured by Generation 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 3 basis points applied to the common equity share of each respective utility’s approved rate base (or maximum penalties of approximately $1 million - for both indices in total for the three utilities).

•An IRS PIM to incentivize the timely completion of the IRS process for large-scale renewable energy projects (rewards and penalties) measured by the number of months between final model checkout and delivery of IRS results to the developer. Target performance is ten months with an asymmetrical deadband of two-months for penalties and no deadband for rewards. The maximum penalty and reward will depend on the specifics of the upcoming procurement.

•A CSSM to incentivize cost control over the Utilities’ fuel, purchased power, and EPRM/MPIR costs (collectively, non-ARA costs). This is a reward only incentive where the Utilities retain 20% share of savings when non-ARA costs in a performance year are lower than target year non-ARA costs, which are adjusted for changes in fuel prices, inflation, and system generation from a base year (calendar year 2021). The CSSM does not have a potential penalty and does not have a cap for maximum reward.

For the 2022 evaluation period, the Utilities earned $3.4 million ($2.5 million for Hawaiian Electric, $0.4 million for Hawaii Electric Light and $0.5 million for Maui Electric) in rewards net of penalties. The net rewards related to 2022 were reflected in the 2023 PIMs annual report and 2023 spring revenue report filings.

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 spring revenue report on March 28, 2023, which is subject to PUC approval.

The net incremental amounts between the 2022 fall and 2023 spring revenue reports are shown in the following table. The amounts are to be collected (refunded) from June, 1, 2023 through May 31, 2024 under the RBA rate tariffs, which were included in the 2023 spring revenue report filing.

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(in millions)	Hawaiian Electric		Hawaii Electric Light		Maui Electric		Total
Incremental Performance Incentive Mechanisms (net)	(0.4)		0.1		0.1		(0.2)
Incremental EPRM/MPIR Revenue Adjustment	2.5		1.4		1.0		4.9
Other	0.4		0.1		—		$	0.5
Net incremental amount to be collected under the RBA rate tariffs	$	2.5	$	1.5	$	1.1	$	5.1

Note: Columns may not foot due to rounding.

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. As the moratorium on customer disconnections ended on May 31, 2021, the Utilities have resumed charging late payment fees in July 2021. Pursuant to PUC orders, the deferral of COVID-19 related costs by the Utilities ended on December 31, 2020. On October 1, 2021, the PUC approved the Utilities’ request to extend the deferral period to December 31, 2021. In December 2021, to keep customers connected and provide some relief to customers experiencing financial difficulty during the pandemic, the Utilities committed to issuing $2 million in bill credits to qualified customers. The Utilities will not seek recovery for the issued bill credits, resulting in a reduction to the cumulative deferred costs. On June 9, 2022, the Utilities filed an application with the PUC, requesting recovery of a portion of the COVID-19 related deferral costs, net of cost savings realized, not to exceed the amount of $27.8 million over three years, from June 2023 through May 2026. Annual requests will be limited to actual costs incurred. On January 25, 2023, the PUC issued an order to modify the procedural schedule to allow more time for more discovery and consideration of the application. As of March 31, 2023, the Utilities have recorded $9.6 million in regulatory assets for deferral of COVID-19 related costs. The updated amounts have been reflected in the Utilities’ First Supplemental Report to the PUC filed on April 28, 2023.

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. On March 1, 2022, Hawaiian Electric acquired the Army’s existing distribution system for a purchase price of $14.5 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. The acquisition of additional assets contemplated in the contract, with an estimated value of $4 million, is planned for 2024.

Hawaiian Electric took ownership and all responsibilities for operation and maintenance of the system on March 1, 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 replace 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. 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.

Condensed consolidating financial information. Condensed consolidating financial information for Hawaiian Electric and its subsidiaries are presented for the three month periods ended March 31, 2023 and 2022, and as of March 31, 2023 and December 31, 2022.

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.

21

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Revenues	$	601,530	115,288	113,673	—	(130)	$	830,361
Expenses
Fuel oil	253,827		27,760	52,510	—	—	334,097
Purchased power	110,279		34,086	8,396	—	—	152,761
Other operation and maintenance	83,233		21,350	23,733	—	—	128,316
Depreciation	41,038		10,635	9,254	—	—	60,927
Taxes, other than income taxes	56,953		10,737	10,695	—	—	78,385
Total expenses	545,330		104,568	104,588	—	—	754,486
Operating income	56,200		10,720	9,085	—	(130)	75,875
Allowance for equity funds used during construction	2,640		284	377	—	—	3,301
Equity in earnings of subsidiaries	11,541		—	—	—	(11,541)	—
Retirement defined benefits credit (expense)—other than service costs	904		169	(26)	—	—	1,047
Interest expense and other charges, net	(14,557)		(2,831)	(2,988)	—	130	(20,246)
Allowance for borrowed funds used during construction	918		91	122	—	—	1,131
Income before income taxes	57,646		8,433	6,570	—	(11,541)	61,108
Income taxes	10,367		1,909	1,324	—	—	13,600
Net income	47,279		6,524	5,246	—	(11,541)	47,508
Preferred stock dividends of subsidiaries	—		134	95	—	—	229
Net income attributable to Hawaiian Electric	47,279		6,390	5,151	—	(11,541)	47,279
Preferred stock dividends of Hawaiian Electric	270		—	—	—	—	270
Net income for common stock	$	47,009	6,390	5,151	—	(11,541)	$	47,009

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Comprehensive Income

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net income for common stock	$	47,009	6,390	5,151	—	(11,541)	$	47,009
Other comprehensive loss, net of taxes:
Retirement benefit plans:
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes	(470)		(56)	(63)	—	119	(470)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	425		50	57	—	(107)	425
Other comprehensive loss, net of taxes	(45)		(6)	(6)	—	12	(45)
Comprehensive income attributable to common shareholder	$	46,964	6,384	5,145	—	(11,529)	$	46,964

22

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Revenues	$	500,242	108,528	100,028	—	(6)	$	708,792
Expenses
Fuel oil	154,425		25,251	41,610	—	—	221,286
Purchased power	124,183		30,712	8,638	—	—	163,533
Other operation and maintenance	83,656		20,214	21,387	—	—	125,257
Depreciation	39,484		10,351	8,636	—	—	58,471
Taxes, other than income taxes	47,274		10,032	9,344	—	—	66,650
Total expenses	449,022		96,560	89,615	—	—	635,197
Operating income	51,220		11,968	10,413	—	(6)	73,595
Allowance for equity funds used during construction	1,990		193	226	—	—	2,409
Equity in earnings of subsidiaries	13,661		—	—	—	(13,661)	—
Retirement defined benefits credit (expense)—other than service costs	855		167	(32)	—	—	990
Interest expense and other charges, net	(13,093)		(2,609)	(2,630)	—	6	(18,326)
Allowance for borrowed funds used during construction	651		60	67	—	—	778
Income before income taxes	55,284		9,779	8,044	—	(13,661)	59,446
Income taxes	8,605		2,268	1,665	—	—	12,538
Net income	46,679		7,511	6,379	—	(13,661)	46,908
Preferred stock dividends of subsidiaries	—		134	95	—	—	229
Net income attributable to Hawaiian Electric	46,679		7,377	6,284	—	(13,661)	46,679
Preferred stock dividends of Hawaiian Electric	270		—	—	—	—	270
Net income for common stock	$	46,409	7,377	6,284	—	(13,661)	$	46,409

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Comprehensive Income

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net income for common stock	$	46,409	7,377	6,284	—	(13,661)	$	46,409
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	4,376		670	603	—	(1,273)	4,376
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	(4,325)		(670)	(603)	—	1,273	(4,325)
Other comprehensive income, net of taxes	51		—	—	—	—	51
Comprehensive income attributable to common shareholder	$	46,460	7,377	6,284	—	(13,661)	$	46,460

23

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Balance Sheet

March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsi- diaries	Consoli- dating adjustments	Hawaiian Electric Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	42,860	5,606	3,594	—	—	$	52,060
Plant and equipment	5,302,293		1,431,852	1,308,747	—	—	8,042,892
Right-of-use assets - finance lease	88,297		—	—	—	—	88,297
Less accumulated depreciation	(1,889,007)		(651,463)	(593,341)	—	—	(3,133,811)
Construction in progress	248,788		28,136	38,938	—	—	315,862
Utility property, plant and equipment, net	3,793,231		814,131	757,938	—	—	5,365,300
Nonutility property, plant and equipment, less accumulated depreciation	5,298		115	1,532	—	—	6,945
Total property, plant and equipment, net	3,798,529		814,246	759,470	—	—	5,372,245
Investment in wholly owned subsidiaries, at equity	705,212		—	—	—	(705,212)	—
Current assets
Cash and cash equivalents	49,393		28,006	38,546	77	—	116,022
Customer accounts receivable, net	172,426		34,224	28,655	—	—	235,305
Accrued unbilled revenues, net	118,035		21,831	20,666	—	—	160,532
Other accounts receivable, net	22,376		3,883	4,677	—	(19,509)	11,427
Fuel oil stock, at average cost	116,295		16,678	24,610	—	—	157,583
Materials and supplies, at average cost	50,744		10,578	22,771	—	—	84,093
Prepayments and other	33,369		5,025	5,515	—	—	43,909
Regulatory assets	58,943		2,575	3,455	—	—	64,973
Total current assets	621,581		122,800	148,895	77	(19,509)	873,844
Other long-term assets
Operating lease right-of-use assets	40,724		32,599	11,607	—	—	84,930
Regulatory assets	151,684		19,041	12,204	—	—	182,929
Other	113,888		32,786	30,402	—	(16,561)	160,515
Total other long-term assets	306,296		84,426	54,213	—	(16,561)	428,374
Total assets	$	5,431,618	1,021,472	962,578	77	(741,282)	$	6,674,463
Capitalization and liabilities
Capitalization
Common stock equity	$	2,358,884	346,629	358,506	77	(705,212)	$	2,358,884
Cumulative preferred stock—not subject to mandatory redemption	22,293		7,000	5,000	—	—	34,293
Long-term debt, net	1,226,587		249,346	258,414	—	—	1,734,347
Total capitalization	3,607,764		602,975	621,920	77	(705,212)	4,127,524
Current liabilities
Current portion of operating lease liabilities	8,955		6,780	2,679	—	—	18,414
Current portion of long-term debt	49,987		19,994	29,992	—	—	99,973
Accounts payable	146,125		20,957	24,687	—	—	191,769
Interest and preferred dividends payable	20,788		3,839	4,740	—	—	29,367
Taxes accrued, including revenue taxes	178,418		34,570	33,926	—	—	246,914
Regulatory liabilities	9,505		7,918	7,811	—	—	25,234
Other	61,360		21,072	23,657	—	(19,509)	86,580
Total current liabilities	475,138		115,130	127,492	—	(19,509)	698,251
Deferred credits and other liabilities
Operating lease liabilities	39,387		26,087	9,159	—	—	74,633
Finance lease liabilities	84,341		—	—	—	—	84,341
Deferred income taxes	271,588		50,657	62,708	—	—	384,953
Regulatory liabilities	745,894		195,238	103,185	—	—	1,044,317
Unamortized tax credits	68,123		12,903	12,419	—	—	93,445
Defined benefit pension and other postretirement benefit plans liability	65,917		—	—	—	(16,529)	49,388
Other	73,466		18,482	25,695	—	(32)	117,611
Total deferred credits and other liabilities	1,348,716		303,367	213,166	—	(16,561)	1,848,688
Total capitalization and liabilities	$	5,431,618	1,021,472	962,578	77	(741,282)	$	6,674,463

24

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Balance Sheet

December 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsi-diaries	Consoli- dating adjustments	Hawaiian Electric Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	42,860	5,606	3,594	—	—	$	52,060
Plant and equipment	5,260,685		1,425,442	1,293,383	—	—	7,979,510
Finance lease right-of-use assets	48,371		—	—	—	—	48,371
Less accumulated depreciation	(1,855,150)		(644,457)	(586,892)	—	—	(3,086,499)
Construction in progress	215,560		23,989	35,804	—	—	275,353
Utility property, plant and equipment, net	3,712,326		810,580	745,889	—	—	5,268,795
Nonutility property, plant and equipment, less accumulated depreciation	5,298		115	1,532	—	—	6,945
Total property, plant and equipment, net	3,717,624		810,695	747,421	—	—	5,275,740
Investment in wholly owned subsidiaries, at equity	701,833		—	—	—	(701,833)	—
Current assets
Cash and cash equivalents	27,579		5,092	6,494	77	—	39,242
Advances to affiliates	—		4,500	21,700	—	(26,200)	—
Customer accounts receivable, net	216,802		39,339	32,197	—	—	288,338
Accrued unbilled revenues, net	136,508		23,839	22,933	—	—	183,280
Other accounts receivable, net	23,746		5,519	6,686	—	(22,384)	13,567
Fuel oil stock, at average cost	153,342		16,964	21,224	—	—	191,530
Materials and supplies, at average cost	48,130		9,783	21,655	—	—	79,568
Prepayments and other	24,040		6,346	4,137	—	(1,041)	33,482
Regulatory assets	46,504		2,435	3,334	—	—	52,273
Total current assets	676,651		113,817	140,360	77	(49,625)	881,280
Other long-term assets
Operating lease right-of-use assets	42,752		34,283	12,283	—	—	89,318
Regulatory assets	154,040		21,816	14,384	—	—	190,240
Other	115,028		32,654	29,495	—	(16,288)	160,889
Total other long-term assets	311,820		88,753	56,162	—	(16,288)	440,447
Total assets	$	5,407,928	1,013,265	943,943	77	(767,746)	$	6,597,467
Capitalization and liabilities
Capitalization
Common stock equity	$	2,344,170	344,720	357,036	77	(701,833)	$	2,344,170
Cumulative preferred stock—not subject to mandatory redemption	22,293		7,000	5,000	—	—	34,293
Long-term debt, net	1,126,915		224,439	233,500	—	—	1,584,854
Total capitalization	3,493,378		576,159	595,536	77	(701,833)	3,963,317
Current liabilities
Current portion of operating lease liabilities	9,775		6,690	2,630	—	—	19,095
Current portion of long-term debt	49,981		19,992	29,989	—	—	99,962
Short-term borrowings-affiliate	26,200		—	—	—	(26,200)	—
Accounts payable	143,253		32,113	27,126	—	—	202,492
Interest and preferred dividends payable	12,398		2,576	2,282	—	(80)	17,176
Taxes accrued, including revenue taxes	207,798		42,436	40,709	—	(1,041)	289,902
Regulatory liabilities	13,145		8,553	9,777	—	—	31,475
Other	64,659		20,856	22,385	—	(22,304)	85,596
Total current liabilities	615,176		133,216	134,898	—	(49,625)	833,665
Deferred credits and other liabilities
Operating lease liabilities	41,049		27,817	9,849	—	—	78,715
Finance lease liabilities	46,048		—	—	—	—	46,048
Deferred income taxes	271,234		50,615	62,581	—	—	384,430
Regulatory liabilities	729,683		194,222	100,270	—	—	1,024,175
Unamortized tax credits	69,614		13,150	12,536	—	—	95,300
Defined benefit pension and other postretirement benefit plans liability	65,907		129	—	—	(16,288)	49,748
Other	75,839		17,957	28,273		—	122,069
Total deferred credits and other liabilities	1,299,374		303,890	213,509	—	(16,288)	1,800,485
Total capitalization and liabilities	$	5,407,928	1,013,265	943,943	77	(767,746)	$	6,597,467

25

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Changes in Common Stock Equity

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Balance, December 31, 2022	$	2,344,170	344,720	357,036	77	(701,833)	$	2,344,170
Net income for common stock	47,009		6,390	5,151	—	(11,541)	47,009
Other comprehensive loss, net of taxes	(45)		(6)	(6)	—	12	(45)
Common stock dividends	(32,250)		(4,475)	(3,675)	—	8,150	(32,250)
Balance, March 31, 2023	$	2,358,884	346,629	358,506	77	(705,212)	$	2,358,884

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Changes in Common Stock Equity

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Balance, December 31, 2021	$	2,261,899	332,900	343,260	77	(676,237)	$	2,261,899
Net income for common stock	46,409		7,377	6,284	—	(13,661)	46,409
Other comprehensive income, net of taxes	51		—	—	—	—	51
Common stock dividends	(31,475)		(4,100)	(3,800)	—	7,900	(31,475)
Balance, March 31, 2022	$	2,276,884	336,177	345,744	77	(681,998)	$	2,276,884

26

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Cash Flows

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net cash provided by operating activities	$	143,356	18,733	15,416	—	(8,150)	$	169,355
Cash flows from investing activities
Capital expenditures	(74,916)		(20,747)	(26,476)	—	—	(122,139)
Advances to affiliates	—		4,500	21,700	—	(26,200)	—
Other	1,094		153	298	—	—	1,545
Net cash used in investing activities	(73,822)		(16,094)	(4,478)	—	(26,200)	(120,594)
Cash flows from financing activities
Common stock dividends	(32,250)		(4,475)	(3,675)	—	8,150	(32,250)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(270)		(134)	(95)	—	—	(499)
Proceeds from issuance of long-term debt	100,000		25,000	25,000	—	—	150,000
Net decrease in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less	(114,167)		—	—	—	26,200	(87,967)
Payments of obligations under finance leases	(575)		—	—	—	—	(575)
Other	(458)		(116)	(116)	—	—	(690)
Net cash provided by (used in) financing activities	(47,720)		20,275	21,114	—	34,350	28,019
Net increase in cash and cash equivalents	21,814		22,914	32,052	—	—	76,780
Cash and cash equivalents, beginning of period	27,579		5,092	6,494	77	—	39,242
Cash and cash equivalents, end of period	$	49,393	28,006	38,546	77	—	$	116,022

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Cash Flows

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net cash provided by operating activities	$	55,669	15,778	13,228	—	(7,900)	$	76,775
Cash flows from investing activities
Capital expenditures	(44,084)		(15,133)	(17,141)	—	—	(76,358)
Advances to affiliates	(4,000)		—	(12,800)	—	16,800	—
Other	961		280	253	—	—	1,494
Net cash used in investing activities	(47,123)		(14,853)	(29,688)	—	16,800	(74,864)
Cash flows from financing activities
Common stock dividends	(31,475)		(4,100)	(3,800)	—	7,900	(31,475)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(270)		(134)	(95)	—	—	(499)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less	18,800		4,000	—	—	(16,800)	6,000
Net cash used in financing activities	(12,945)		(234)	(3,895)	—	(8,900)	(25,974)
Net increase (decrease) in cash and cash equivalents	(4,399)		691	(20,355)	—	—	(24,063)
Cash, cash equivalents and restricted cash, beginning of period	26,433		5,326	23,422	77	—	55,258
Cash, cash equivalents and restricted cash, end of period	22,034		6,017	3,067	77	—	31,195
Less: Restricted cash	(2,140)		—	—	—	—	(2,140)
Cash and cash equivalents, end of period	$	19,894	6,017	3,067	77	—	$	29,055

27

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Note 4 ·Bank segment

Selected financial information

American Savings Bank, F.S.B.

Statements of Income and Comprehensive Income Data

	Three months ended March 31
(in thousands)	2023		2022
Interest and dividend income
Interest and fees on loans	$	64,842	$	46,005
Interest and dividends on investment securities	14,637		13,984
Total interest and dividend income	79,479		59,989
Interest expense
Interest on deposit liabilities	6,837		947
Interest on other borrowings	7,721		5
Total interest expense	14,558		952
Net interest income	64,921		59,037
Provision for credit losses	1,175		(3,263)
Net interest income after provision for credit losses	63,746		62,300
Noninterest income
Fees from other financial services	4,679		5,587
Fee income on deposit liabilities	4,599		4,691
Fee income on other financial products	2,744		2,718
Bank-owned life insurance	1,425		681
Mortgage banking income	130		1,077
Gain on sale of real estate	—		1,002
Other income, net	801		372
Total noninterest income	14,378		16,128
Noninterest expense
Compensation and employee benefits	30,204		27,215
Occupancy	5,588		5,952
Data processing	5,012		4,151
Services	2,595		2,439
Equipment	2,646		2,329
Office supplies, printing and postage	1,165		1,060
Marketing	1,016		1,018
Other expense	6,191		4,049
Total noninterest expense	54,417		48,213
Income before income taxes	23,707		30,215
Income taxes	5,145		6,345
Net income	18,562		23,870
Other comprehensive income (loss), net of taxes	18,430		(122,441)
Comprehensive income (loss)	$	36,992	$	(98,571)

28

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Reconciliation to amounts per HEI Condensed Consolidated Statements of Income*:

	Three months ended March 31
(in thousands)	2023		2022
Interest and dividend income	$	79,479	$	59,989
Noninterest income	14,378		16,128
Less: Gain on sale of real estate	—		1,002
*Revenues-Bank	93,857		75,115
Total interest expense	14,558		952
Provision for credit losses	1,175		(3,263)
Noninterest expense	54,417		48,213
Less: Gain on sale of real estate	—		1,002
Less: Retirement defined benefits credit—other than service costs	(187)		(185)
*Expenses-Bank	70,337		45,085
*Operating income-Bank	23,520		30,030
Add back: Retirement defined benefits credit—other than service costs	(187)		(185)
Income before income taxes	$	23,707	$	30,215

29

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

American Savings Bank, F.S.B.

Balance Sheets Data

(in thousands)	March 31, 2023				December 31, 2022
Assets
Cash and due from banks			$	138,742			$	153,042
Interest-bearing deposits			44,315				3,107
Cash and cash equivalents			183,057				156,149
Investment securities
Available-for-sale, at fair value			1,419,755				1,429,667
Held-to-maturity, at amortized cost (fair value of $1,158,090 and $1,150,971, respectively)			1,238,185				1,251,747
Stock in Federal Home Loan Bank, at cost			10,000				26,560
Loans held for investment			6,059,354				5,978,906
Allowance for credit losses			(71,296)				(72,216)
Net loans			5,988,058				5,906,690
Loans held for sale, at lower of cost or fair value			660				824
Other			688,165				692,143
Goodwill			82,190				82,190
Total assets			$	9,610,070			$	9,545,970
Liabilities and shareholder’s equity
Deposit liabilities—noninterest-bearing			$	2,769,789			$	2,811,077
Deposit liabilities—interest-bearing			5,460,812				5,358,619
Other borrowings			680,690				695,120
Other			206,317				212,269
Total liabilities			9,117,608				9,077,085
Common stock			1				1
Additional paid-in capital			356,391				355,806
Retained earnings			454,255				449,693
Accumulated other comprehensive loss, net of tax benefits
Net unrealized losses on securities	$	(308,622)			$	(328,904)
Retirement benefit plans	(9,563)		(318,185)		(7,711)		(336,615)
Total shareholder’s equity			492,462				468,885
Total liabilities and shareholder’s equity			$	9,610,070			$	9,545,970
Other assets
Bank-owned life insurance			$	183,936			$	182,986
Premises and equipment, net			192,789				195,324
Accrued interest receivable			26,547				25,077
Mortgage-servicing rights			8,745				9,047
Low-income housing investments			110,748				106,978
Real estate held for sale			100				—
Deferred tax asset			109,885				116,441
Real estate acquired in settlement of loans, net			614				115
Other			54,801				56,175
			$	688,165			$	692,143
Other liabilities
Accrued expenses			$	95,066			$	97,295
Federal and state income taxes payable			2,614				863
Cashier’s checks			34,616				36,401
Advance payments by borrowers			5,466				9,637
Other			68,555				68,073
			$	206,317			$	212,269

30

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Bank-owned life insurance is life insurance purchased by ASB on the lives of certain key employees, with ASB as the beneficiary. The insurance is used to fund employee benefits through tax-free income from increases in the cash value of the policies and insurance proceeds paid to ASB upon an insured’s death.

Other borrowings consisted of FHLB advances, borrowings from the Federal Reserve Bank and securities sold under agreements to repurchase.

Investment securities.  The major components of investment securities were as follows:

	Amortized cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value		Gross unrealized losses
									Less than 12 months					12 months or longer
(dollars in thousands)									Number of issues	Fair  value		Amount		Number of issues	Fair  value		Amount
March 31, 2023
Available-for-sale
U.S. Treasury and federal agency obligations	$	85,786	$	—	$	(6,042)	$	79,744	—	$	—	$	—	14	$	79,744	$	(6,042)
Mortgage-backed securities*	1,500,717		1		(216,783)		1,283,935		24	89,727		(7,367)		158	1,193,633		(209,416)
Corporate bonds	44,341		—		(3,031)		41,310		2	8,951		(50)		3	32,359		(2,981)
Mortgage revenue bonds	14,766		—		—		14,766		—	—		—		—	—		—
	$	1,645,610	$	1	$	(225,856)	$	1,419,755	26	$	98,678	$	(7,417)	175	$	1,305,736	$	(218,439)
Held-to-maturity
U.S. Treasury and federal agency obligations	$	59,900	$	—	$	(7,172)	$	52,728	—	$	—	$	—	3	$	52,728	$	(7,172)
Mortgage-backed securities*	1,178,285		8,875		(81,798)		1,105,362		6	64,288		(532)		41	427,520		(81,266)
	$	1,238,185	$	8,875	$	(88,970)	$	1,158,090	6	$	64,288	$	(532)	44	$	480,248	$	(88,438)
December 31, 2022
Available-for-sale
U.S. Treasury and federal agency obligations	$	88,344	$	—	$	(7,281)	$	81,063	12	$	41,201	$	(2,120)	4	$	39,862	$	(5,161)
Mortgage-backed securities*	1,530,582		—		(237,614)		1,292,968		113	455,836		(56,999)		70	837,132		(180,615)
Corporate bonds	44,377		—		(3,643)		40,734		4	29,644		(2,028)		1	11,090		(1,615)
Mortgage revenue bonds	14,902		—		—		14,902		—	—		—		—	—		—
	$	1,678,205	$	—	$	(248,538)	$	1,429,667	129	$	526,681	$	(61,147)	75	$	888,084	$	(187,391)
Held-to-maturity
U.S. Treasury and federal agency obligations	$	59,894	$	—	$	(8,478)	$	51,416	1	$	16,874	$	(3,222)	2	$	34,542	$	(5,256)
Mortgage-backed securities*	1,191,853		2,670		(94,968)		1,099,555		22	183,629		(10,593)		51	567,250		(84,375)
	$	1,251,747	$	2,670	$	(103,446)	$	1,150,971	23	$	200,503	$	(13,815)	53	$	601,792	$	(89,631)

* 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 March 31, 2023 and December 31, 2022, 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 rated 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 March 31, 2023 and December 31, 2022.

31

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

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.

The contractual maturities of investment securities were as follows:

March 31, 2023	Amortized  cost		Fair value
(in thousands)
Available-for-sale
Due in one year or less	$	2,579	$	2,531
Due after one year through five years	127,548		118,523
Due after five years through ten years	14,766		14,766
Due after ten years	—		—
	144,893		135,820
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	1,500,717		1,283,935
Total available-for-sale securities	$	1,645,610	$	1,419,755
Held-to-maturity
Due in one year or less	$	—	$	—
Due after one year through five years	—		—
Due after five years through ten years	59,900		52,728
Due after ten years	—		—
	59,900		52,728
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	1,178,285		1,105,362
Total held-to-maturity securities	$	1,238,185	$	1,158,090

There were no sales of available-for-sale securities for the quarters ended March 31, 2023 and 2022.

The components of loans were summarized as follows:

	March 31, 2023		December 31, 2022
(in thousands)
Real estate:
Residential 1-4 family	$	2,484,316	$	2,479,637
Commercial real estate	1,377,184		1,358,123
Home equity line of credit	1,022,800		1,002,905
Residential land	20,061		20,679
Commercial construction	94,267		88,489
Residential construction	15,749		20,788
Total real estate	5,014,377		4,970,621
Commercial	800,949		779,691
Consumer	272,401		254,709
Total loans	6,087,727		6,005,021
Less: Deferred fees and discounts	(28,373)		(26,115)
Allowance for credit losses	(71,296)		(72,216)
Total loans, net	$	5,988,058	$	5,906,690

ASB's policy is to require private mortgage insurance on all real estate loans when the loan-to-value ratio of the property exceeds 80% of the lower of the appraised value or purchase price at origination. For non-owner occupied residential property purchases, the loan-to-value ratio may not exceed 75% of the lower of the appraised value or purchase price at origination.

32

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Allowance for credit losses.  The allowance for credit losses (balances and changes) by portfolio segment were as follows:

(in thousands)	Residential 1-4 family		Commercial real estate		Home equity line of credit		Residential land		Commercial construction		Residential construction		Commercial loans		Consumer loans		Total
Three months ended March 31, 2023
Allowance for credit losses:
Beginning balance	$	6,270	$	21,898	$	6,125	$	717	$	1,195	$	46	$	12,426	$	23,539	$	72,216
Charge-offs	(809)		—		(63)		—		—		—		(227)		(2,323)		(3,422)
Recoveries	4		—		17		—		—		—		398		908		1,327
Provision	(853)		803		(26)		(97)		(460)		(18)		(661)		2,487		1,175
Ending balance	$	4,612	$	22,701	$	6,053	$	620	$	735	$	28	$	11,936	$	24,611	$	71,296
Three months ended March 31, 2022
Allowance for credit losses:
Beginning balance	$	6,545	$	24,696	$	5,657	$	646	$	2,186	$	18	$	15,798	$	15,584	$	71,130
Charge-offs	—		—		—		—		—		—		(76)		(1,482)		(1,558)
Recoveries	8		—		11		5		—		—		353		1,025		1,402
Provision	1,321		(4,520)		(18)		46		154		13		(1,761)		1,002		(3,763)
Ending balance	$	7,874	$	20,176	$	5,650	$	697	$	2,340	$	31	$	14,314	$	16,129	$	67,211

Allowance for loan commitments.  The allowance for loan commitments by portfolio segment were as follows:

(in thousands)	Home equity  line of credit		Commercial construction		Commercial loans		Total
Three months ended March 31, 2023
Allowance for loan commitments:
Beginning balance	$	400	$	2,600	$	1,400	$	4,400
Provision	—		—		—		—
Ending balance	$	400	$	2,600	$	1,400	$	4,400
Three months ended March 31, 2022
Allowance for loan commitments:
Beginning balance	$	400	$	3,700	$	800	$	4,900
Provision	—		(100)		600		500
Ending balance	$	400	$	3,600	$	1,400	$	5,400

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.

33

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 Year												Revolving Loans
(in thousands)	2023		2022		2021		2020		2019		Prior		Revolving		Converted to term loans		Total
March 31, 2023
Residential 1-4 family
Current	$	46,292	$	425,843	$	750,578	$	418,780	$	110,618	$	727,411	$	—	$	—	$	2,479,522
30-59 days past due	—		—		—		—		938		971		—		—		1,909
60-89 days past due	—		—		—		—		—		930		—		—		930
Greater than 89 days past due	—		—		—		267		—		1,688		—		—		1,955
	46,292		425,843		750,578		419,047		111,556		731,000		—		—		2,484,316
Current YTD period
Gross charge-offs	—		—		—		—		—		809		—		—		809
Home equity line of credit
Current	—		—		—		—		—		—		973,686		46,565		1,020,251
30-59 days past due	—		—		—		—		—		—		781		115		896
60-89 days past due	—		—		—		—		—		—		346		337		683
Greater than 89 days past due	—		—		—		—		—		—		573		397		970
	—		—		—		—		—		—		975,386		47,414		1,022,800
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		63		63
Residential land
Current	1,204		5,237		8,587		4,039		—		994		—		—		20,061
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	1,204		5,237		8,587		4,039		—		994		—		—		20,061
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Residential construction
Current	1,444		6,786		7,519		—		—		—		—		—		15,749
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	1,444		6,786		7,519		—		—		—		—		—		15,749
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Consumer
Current	36,794		189,133		18,047		4,233		4,301		341		9,589		4,904		267,342
30-59 days past due	203		1,628		235		54		170		11		78		120		2,499
60-89 days past due	—		899		116		59		129		4		16		117		1,340
Greater than 89 days past due	—		502		199		59		105		26		82		247		1,220
	36,997		192,162		18,597		4,405		4,705		382		9,765		5,388		272,401
Current YTD period
Gross charge-offs	189		1,523		319		57		135		21		15		64		2,323
Commercial real estate
Pass	41,312		392,018		174,655		276,754		52,121		339,660		8,235		—		1,284,755
Special Mention	—		—		11,250		3,425		30,179		21,307		—		—		66,161
Substandard	5,433		—		—		659		11,356		8,820		—		—		26,268
Doubtful	—		—		—		—		—		—		—		—		—
	46,745		392,018		185,905		280,838		93,656		369,787		8,235		—		1,377,184

34

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

	Term Loans by Origination Year												Revolving Loans
(in thousands)	2023		2022		2021		2020		2019		Prior		Revolving		Converted to term loans		Total
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Commercial construction
Pass	—		11,206		54,924		44		—		—		28,093		—		94,267
Special Mention	—		—		—		—		—		—		—		—		—
Substandard	—		—		—		—		—		—		—		—		—
Doubtful	—		—		—		—		—		—		—		—		—
	—		11,206		54,924		44		—		—		28,093		—		94,267
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Commercial
Pass	30,142		238,671		184,551		86,275		60,265		97,277		66,200		12,918		776,299
Special Mention	—		—		—		—		2,255		—		8,492		6		10,753
Substandard	—		3,234		1,507		398		1,320		5,195		899		1,344		13,897
Doubtful	—		—		—		—		—		—		—		—		—
	30,142		241,905		186,058		86,673		63,840		102,472		75,591		14,268		800,949
Current YTD period
Gross charge-offs	—		—		51		—		—		—		14		162		227
Total loans	$	162,824	$	1,275,157	$	1,212,168	$	795,046	$	273,757	$	1,204,635	$	1,097,070	$	67,070	$	6,087,727

35

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

	Term Loans by Origination Year												Revolving Loans
(in thousands)	2022		2021		2020		2019		2018		Prior		Revolving		Converted to term loans		Total
December 31, 2022
Residential 1-4 family
Current	$	432,707	$	755,056	$	423,455	$	113,096	$	51,860	$	698,354	$	—	$	—	$	2,474,528
30-59 days past due	—		—		—		—		448		1,098		—		—		1,546
60-89 days past due	—		—		268		—		—		90		—		—		358
Greater than 89 days past due	—		—		—		—		809		2,396		—		—		3,205
	432,707		755,056		423,723		113,096		53,117		701,938		—		—		2,479,637
Home equity line of credit
Current	—		—		—		—		—		—		959,131		40,814		999,945
30-59 days past due	—		—		—		—		—		—		1,103		209		1,312
60-89 days past due	—		—		—		—		—		—		209		226		435
Greater than 89 days past due	—		—		—		—		—		—		587		626		1,213
	—		—		—		—		—		—		961,030		41,875		1,002,905
Residential land
Current	5,245		9,010		5,222		203		522		477		—		—		20,679
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	5,245		9,010		5,222		203		522		477		—		—		20,679
Residential construction
Current	7,986		11,624		1,178		—		—		—		—		—		20,788
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	7,986		11,624		1,178		—		—		—		—		—		20,788
Consumer
Current	199,574		21,330		5,543		7,580		527		140		10,810		4,782		250,286
30-59 days past due	1,110		287		65		239		30		—		81		167		1,979
60-89 days past due	756		163		88		137		19		—		45		107		1,315
Greater than 89 days past due	621		105		37		176		28		—		20		142		1,129
	202,061		21,885		5,733		8,132		604		140		10,956		5,198		254,709
Commercial real estate
Pass	390,206		177,130		283,321		51,542		63,084		278,280		8,235		—		1,251,798
Special Mention	—		11,250		3,446		40,423		—		24,466		—		—		79,585
Substandard	—		—		665		11,357		—		14,718		—		—		26,740
Doubtful	—		—		—		—		—		—		—		—		—
	390,206		188,380		287,432		103,322		63,084		317,464		8,235		—		1,358,123
Commercial construction
Pass	15,094		47,478		44		—		—		—		25,873		—		88,489
Special Mention	—		—		—		—		—		—		—		—		—
Substandard	—		—		—		—		—		—		—		—		—
Doubtful	—		—		—		—		—		—		—		—		—
	15,094		47,478		44		—		—		—		25,873		—		88,489
Commercial
Pass	239,852		185,013		85,220		68,161		46,142		53,192		60,871		13,964		752,415
Special Mention	—		—		—		2,374		—		645		9,005		8		12,032
Substandard	3,322		2,305		401		1,304		1,346		3,849		1,664		1,053		15,244
Doubtful	—		—		—		—		—		—		—		—		—
	243,174		187,318		85,621		71,839		47,488		57,686		71,540		15,025		779,691
Total loans	$	1,296,473	$	1,220,751	$	808,953	$	296,592	$	164,815	$	1,077,705	$	1,077,634	$	62,098	$	6,005,021

36

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Revolving loans converted to term loans during the three months ended March 31, 2023 in the commercial, home equity line of credit and consumer portfolios were $1.2 million, $7.8 million and $1.1 million, respectively. Revolving loans converted to term loans during the three months ended March 31, 2022 in the commercial, home equity line of credit and consumer portfolios were $0.5 million, $4.4 million and $1.0 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		Current		Total financing receivables		Amortized cost> 90 days and accruing
March 31, 2023
Real estate:
Residential 1-4 family	$	1,909	$	930	$	1,955	$	4,794	$	2,479,522	$	2,484,316	$	—
Commercial real estate	—		—		—		—		1,377,184		1,377,184		—
Home equity line of credit	896		683		970		2,549		1,020,251		1,022,800		—
Residential land	—		—		—		—		20,061		20,061		—
Commercial construction	—		—		—		—		94,267		94,267		—
Residential construction	—		—		—		—		15,749		15,749		—
Commercial	263		71		427		761		800,188		800,949		—
Consumer	2,499		1,340		1,220		5,059		267,342		272,401		—
Total loans	$	5,567	$	3,024	$	4,572	$	13,163	$	6,074,564	$	6,087,727	$	—
December 31, 2022
Real estate:
Residential 1-4 family	$	1,546	$	358	$	3,205	$	5,109	$	2,474,528	$	2,479,637	$	—
Commercial real estate	508		217		—		725		1,357,398		1,358,123		—
Home equity line of credit	1,312		435		1,213		2,960		999,945		1,002,905		—
Residential land	—		—		—		—		20,679		20,679		—
Commercial construction	—		—		—		—		88,489		88,489		—
Residential construction	—		—		—		—		20,788		20,788		—
Commercial	614		18		77		709		778,982		779,691		—
Consumer	1,979		1,315		1,129		4,423		250,286		254,709		—
Total loans	$	5,959	$	2,343	$	5,624	$	13,926	$	5,991,095	$	6,005,021	$	—

The credit risk profile based on nonaccrual loans were as follows:

(in thousands)	March 31, 2023						December 31, 2022
	With a Related ACL		Without a Related ACL		Total		With a Related ACL		Without a Related ACL		Total
Real estate:
Residential 1-4 family	$	3,371	$	2,117	$	5,488	$	4,198	$	2,981	$	7,179
Commercial real estate	—		—		—		—		—		—
Home equity line of credit	4,014		1,237		5,251		3,654		1,442		5,096
Residential land	109		—		109		420		—		420
Commercial construction	—		—		—		—		—		—
Residential construction	—		—		—		—		—		—
Commercial	1,744		—		1,744		2,183		—		2,183
Consumer	1,895		—		1,895		1,588		—		1,588
Total	$	11,133	$	3,354	$	14,487	$	12,043	$	4,423	$	16,466

ASB did not recognize interest on nonaccrual loans for the three months ended March 31, 2023 and 2022.

37

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

Modifications Made to Borrowers Experiencing Financial Difficulty. The allowance for credit losses incorporates an estimate of lifetime expected credit losses and is recorded on each asset upon origination. The starting point for the estimate of the allowance for credit losses is historical loan information, which includes losses from modifications of receivables to borrowers experiencing financial difficulty. ASB uses a probability of default/loss given default model to determine the allowance for credit losses. An assessment of whether a borrower is experiencing financial difficulty is made at the time of the modification.

Because the effect of most modifications made to borrowers experiencing financial difficulty is already included in the allowance for credit losses, a change to the allowance for credit losses is generally not recorded upon modification.

Modifications may include interest rate reductions, interest only payments for an extended period of time, protracted terms such as amortization and maturity beyond the customary length of time found in the normal marketplace, and other actions intended to minimize economic loss and to provide alternatives to foreclosure or repossession of collateral.

During the first three months of 2023, no loans received a material modification based on borrower financial difficulty.

Troubled debt restructurings. Prior to January 1, 2023, a loan modification was 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. With the adoption of ASU No. 2022-02, accounting guidance for TDRs by creditors is eliminated. Loan refinancing and restructuring guidance is applied to determine whether a modification results in a new loan or a continuation of an existing loan. ASB will continue TDR disclosures for years prior to the adoption of ASU No. 2022-02.

The credit risk profile based on loans whose terms have been modified and accruing interest were as follows:

(in thousands)	December 31, 2022
Real estate:
Residential 1-4 family	$	8,821
Commercial real estate	9,477
Home equity line of credit	4,404
Residential land	782
Commercial construction	—
Residential construction	—
Commercial	6,596
Consumer	50
Total troubled debt restructured loans accruing interest	$	30,130

Loans modified as a TDR.  There were no loan modifications that occurred during the three months ended March 31, 2022.

There were no loans modified in TDRs that experienced a payment default of 90 days or more during the first three months of 2022.

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 December 31, 2022.

Collateral-dependent loans. A loan is considered collateral-dependent when the borrower is experiencing financial difficulty and repayment of the loan is expected to be provided substantially through the operation or sale of the collateral. Loans considered collateral-dependent were as follows:

	Amortized cost
(in thousands)	March 31, 2023		December 31, 2022		Collateral type
Real estate:
Residential 1-4 family	$	2,353	$	3,959	Residential real estate property
Home equity line of credit	1,237		1,425		Residential real estate property
Total	$	3,590	$	5,384

ASB had $3.4 million and $4.2 million of consumer mortgage loans collateralized by residential real estate property that were in the process of foreclosure at March 31, 2023 and December 31, 2022, respectively.

38

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

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 $5.7 million and $75.6 million for the three months ended March 31, 2023 and 2022, respectively, and recognized gains on such sales of $0.1 million and $1.1 million for the three months ended March 31, 2023 and 2022, respectively.

There were no repurchased mortgage loans for the three months ended March 31, 2023 and 2022.

Mortgage servicing fees, a component of other income, net, were $0.9 million for the three months ended March 31, 2023 and 2022.

Changes in the carrying value of MSRs were as follows:

(in thousands)	Gross carrying amount		Accumulated amortization		Valuation allowance		Net carrying amount
March 31, 2023	$	17,868	$	(9,123)	$	—	$	8,745
December 31, 2022	19,544		(10,497)		—		9,047

Changes related to MSRs were as follows:

	Three months ended March 31
(in thousands)	2023		2022
Mortgage servicing rights
Beginning balance	$	9,047	$	9,950
Amount capitalized	51		719
Amortization	(353)		(645)
Other-than-temporary impairment	—		—
Carrying amount before valuation allowance	8,745		10,024
Valuation allowance for mortgage servicing rights
Beginning balance	—		—
Provision	—		—
Other-than-temporary impairment	—		—
Ending balance	—		—
Net carrying value of mortgage servicing rights	$	8,745	$	10,024

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)	March 31, 2023			December 31, 2022
Unpaid principal balance	$	1,431,037		$	1,451,322
Weighted average note rate	3.39		%	3.38		%
Weighted average discount rate	10.00		%	10.00		%
Weighted average prepayment speed	6.39		%	6.56		%

39

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

The sensitivity analysis of fair value of MSRs to hypothetical adverse changes of 25 and 50 basis points in certain key assumptions was as follows:

(dollars in thousands)	March 31, 2023		December 31, 2022
Prepayment rate:
25 basis points adverse rate change	$	(109)	$	(92)
50 basis points adverse rate change	(243)		(214)
Discount rate:
25 basis points adverse rate change	(190)		(182)
50 basis points adverse rate change	(376)		(361)

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 March 31, 2023 and December 31, 2022, ASB had nil and $414.0 million of FHLB advances outstanding, respectively, and borrowings with the Federal Reserve Bank of $550.0 million and nil, respectively. As of March 31, 2023, ASB was in compliance with all FHLB Advances, Pledge and Security Agreement requirements and all requirements to borrow at the Federal Reserve Discount Window Primary Credit Facility under 12 CFR 201.4(a) guidelines.

Securities sold under agreements to repurchase are accounted for as financing transactions and the obligations to repurchase these securities are recorded as liabilities in the condensed consolidated balance sheets. ASB pledges investment securities as collateral for securities sold under agreements to repurchase. All such agreements are subject to master netting arrangements, which provide for a conditional right of set-off in case of default by either party; however, ASB presents securities sold under agreements to repurchase on a gross basis in the balance sheet. The following tables present information about the securities sold under agreements to repurchase, including the related collateral received from or pledged to counterparties:

(in millions)	Gross amount  of recognized  liabilities		Gross amount  offset in the  Balance Sheets		Net amount of liabilities presented in the Balance Sheets
Repurchase agreements
March 31, 2023	$	131	$	—	$	131
December 31, 2022	281		—		281

	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
March 31, 2023	$	131	$	172	$	—
December 31, 2022	281		327		—

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.

40

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued (Unaudited)

ASB enters into forward commitments to hedge the interest rate risk for rate locked mortgage applications in process and closed mortgage loans held for sale. These commitments are primarily forward sales of to-be-announced mortgage backed securities. Generally, when mortgage loans are closed, the forward commitment is liquidated and replaced with a mandatory delivery forward sale of the mortgage to a secondary market investor. 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:

	March 31, 2023				December 31, 2022
(in thousands)	Notional amount		Fair value		Notional amount		Fair value
Interest rate lock commitments	$	2,467	$	26	$	1,720	$	9
Forward commitments	2,250		5		1,500		18

ASB’s derivative financial instruments, their fair values and balance sheet location were as follows:

Derivative Financial Instruments Not Designated as Hedging Instruments 1	March 31, 2023				December 31, 2022
(in thousands)	Asset derivatives		Liability derivatives		Asset derivatives		Liability derivatives
Interest rate lock commitments	$	26	$	—	$	9	$	—
Forward commitments	9		4		18		—
	$	35	$	4	$	27	$	—

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 Income	Three months ended March 31
(in thousands)		2023		2022
Interest rate lock commitments	Mortgage banking income	$	17	$	(655)
Forward commitments	Mortgage banking income	(13)		178
		$	4	$	(477)

Low-Income Housing Tax Credit (LIHTC). ASB’s unfunded commitments to fund its LIHTC investment partnerships were $77.1 million and $70.1 million at March 31, 2023 and December 31, 2022, respectively. These unfunded commitments were unconditional and legally binding and are recorded in other liabilities with a corresponding increase in other assets. As of March 31, 2023, ASB did not have any impairment losses resulting from forfeiture or ineligibility of tax credits or other circumstances related to its LIHTC investment partnerships.

Note 5 · Credit agreements and changes in debt

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 Credit Facilities) to amend and restate their respective previously existing revolving unsecured credit agreements. The $175 million HEI Facility and the $200 million Hawaiian Electric Facility both terminate on May 14, 2026. On February 18, 2022, the PUC approved Hawaiian Electric’s request to extend the term of the $200 million Hawaiian Electric Facility to May 14, 2026. In addition to extending the term, Hawaiian Electric also received 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 March 31, 2023 and December 31, 2022, no amounts were outstanding under the Credit Facilities.

41

The Credit Facilities will be maintained to support each company’s respective short-term commercial paper program, but may be drawn on to meet each company’s respective working capital needs and general corporate purposes.

Changes in debt.

HEI private placement. On March 16, 2023, HEI entered into a note purchase agreement (HEI NPA) under which HEI has authorized the issue and sale of $100 million of unsecured senior notes that may be drawn on or before June 2, 2023. The proceeds of the notes, when drawn, are expected to be used to refinance the $100 million term loan facility. The terms of the notes are as follows:

	HEI Series 2023A	HEI Series 2023B
Aggregate principal amount	$39 million	$61 million
Fixed coupon interest rate	6.04%	6.10%
Maturity date	6/15/2028	6/15/2033

Once drawn, interest on the notes is paid semiannually on June 15th and December 15th. The HEI NPA contains certain restrictive financial covenants that are substantially the same as the financial covenants contained in HEI’s revolving unsecured 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.

HEI term loan. On October 20, 2022, HEI entered into a term loan facility in the aggregate principal amount of $100 million. On December 28, 2022, HEI drew $35 million on the term loan, and on March 31, 2023, HEI drew the remaining $65 million at an initial interest rate of 5.81% for an initial one month interest period. Any borrowings under the facility mature on November 30, 2023. Borrowings under the facility bear interest at Term Secured Overnight Financing Rate (SOFR), as defined in the agreement, plus an applicable margin and a SOFR spread adjustment. The term loan facility contains certain restrictive financial covenants that are substantially the same as the financial covenants contained in the HEI Facility.

Utilities private placement. On January 10, 2023, the Utilities executed through a private placement pursuant to separate Note Purchase Agreements (the NPAs), the following unsecured senior notes bearing taxable interest (2023 Notes). The 2023 Notes had a delayed draw feature and the Utilities drew down all the proceeds on February 9, 2023.

	Series 2023A	Series 2023B	Series 2023C
Aggregate principal amount	$90 million	$40 million	$20 million
Fixed coupon interest rate
Hawaiian Electric	6.11%	6.25%	6.70%
Hawaii Electric Light	6.25%	—	—
Maui Electric	6.25%	—	—
Maturity date
Hawaiian Electric	2/9/2030	2/9/2033	2/9/2053
Hawaii Electric Light	2/9/2033	—	—
Maui Electric	2/9/2033	—	—
Principal amount by company:
Hawaiian Electric	$40 million	$40 million	$20 million
Hawaii Electric Light	$25 million	—	—
Maui Electric	$25 million	—	—

The 2023 Notes include substantially the same financial covenants and customary conditions as Hawaiian Electric’s credit agreement. Hawaiian Electric is also a party as guarantor under the NPAs entered into by Hawaii Electric Light and Maui Electric. The Utilities did not obtain any of the proceeds at execution and instead drew down all the proceeds on February 9, 2023. The proceeds were used to finance their respective capital expenditures, repay short-term debt used to finance or refinance capital expenditures and/or reimburse funds used for the payment of capital expenditures. The 2023 Notes may be prepaid in whole or in part at any time at the prepayment price of the principal amount plus a “Make-Whole Amount” as defined in the NPAs.

42

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 Consolidated								Hawaiian Electric Consolidated
(in thousands)	Net unrealized gains (losses) on securities		Unrealized gains (losses) on derivatives		Retirement benefit plans		AOCI		AOCI-Retirement benefit plans
Balance, December 31, 2022	$	(328,904)	$	1,991	$	(9,115)	$	(336,028)	$	2,861
Current period other comprehensive income (loss)	20,282		138		68		20,488		(45)
Balance, March 31, 2023	$	(308,622)	$	2,129	$	(9,047)	$	(315,540)	$	2,816
Balance, December 31, 2021	$	(32,037)	$	(3,638)	$	(16,858)	$	(52,533)	$	(3,280)
Current period other comprehensive income (loss)	(120,407)		3,072		176		(117,159)		51
Balance, March 31, 2022	$	(152,444)	$	(566)	$	(16,682)	$	(169,692)	$	(3,229)

Reclassifications out of AOCI were as follows:

	Amount reclassified from AOCI					Affected line item in the  Statements of Income / Balance Sheets
		Three months ended March 31
(in thousands)		2023		2022
HEI consolidated
Net unrealized gains (losses) on available-for sale investment securities - amortization of unrealized holding losses on held-to-maturity securities		$	3,677	$	—	Bank revenues
Net realized losses (gains) on derivatives qualifying as cash flow hedges		(48)		55		Interest expense
Retirement benefit plans:
Amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost		(357)		4,501		See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets		425		(4,325)		See Note 8 for additional details
Total reclassifications		$	3,697	$	231
Hawaiian Electric consolidated
Retirement benefit plans:
Amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost		$	(470)	$	4,376	See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets		425		(4,325)		See Note 8 for additional details
Total reclassifications		$	(45)	$	51

43

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 March 31, 2023
(in thousands)	Electric  utility		Bank		Other		Total
Revenues from contracts with customers
Electric energy sales - residential	$	255,550	$	—	$	—	$	255,550
Electric energy sales - commercial	254,470		—		—		254,470
Electric energy sales - large light and power	290,978		—		—		290,978
Electric energy sales - other	5,457		—		—		5,457
Bank fees	—		12,022		—		12,022
Other sales	—		—		3,907		3,907
Total revenues from contracts with customers	806,455		12,022		3,907		822,384
Revenues from other sources
Regulatory revenue	$	15,604	$	—	$	—	$	15,604
Bank interest and dividend income	—		79,479		—		79,479
Other bank noninterest income	—		2,356		—		2,356
Other	8,302		—		112		8,414
Total revenues from other sources	23,906		81,835		112		105,853
Total revenues	$	830,361	$	93,857	$	4,019	$	928,237
Timing of revenue recognition
Services/goods transferred at a point in time	$	—	$	12,022	$	—	$	12,022
Services/goods transferred over time	806,455		—		3,907		810,362
Total revenues from contracts with customers	$	806,455	$	12,022	$	3,907	$	822,384

	Three months ended March 31, 2022
(in thousands)	Electric  utility		Bank		Other		Total
Revenues from contracts with customers
Electric energy sales - residential	$	224,574	$	—	$	—	$	224,574
Electric energy sales - commercial	219,597		—		—		219,597
Electric energy sales - large light and power	241,123		—		—		241,123
Electric energy sales - other	1,426		—		—		1,426
Bank fees	—		12,996		—		12,996
Other sales	—		—		1,115		1,115
Total revenues from contracts with customers	686,720		12,996		1,115		700,831
Revenues from other sources
Regulatory revenue	12,886		—		—		12,886
Bank interest and dividend income	—		59,989		—		59,989
Other bank noninterest income	—		2,130		—		2,130
Other	9,186		—		46		9,232
Total revenues from other sources	22,072		62,119		46		84,237
Total revenues	$	708,792	$	75,115	$	1,161	$	785,068
Timing of revenue recognition
Services/goods transferred at a point in time	$	—	$	12,996	$	—	$	12,996
Services/goods transferred over time	686,720		—		1,115		687,835
Total revenues from contracts with customers	$	686,720	$	12,996	$	1,115	$	700,831

There are no material contract assets or liabilities associated with revenues from contracts with customers existing at December 31, 2022 or as of March 31, 2023. 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

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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 March 31, 2023, 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 three months of 2023, the Company contributed $2 million ($2 million by the Utilities) to its pension and other postretirement benefit plans, compared to $10 million ($10 million by the Utilities) in the first three months of 2022. The Company’s current estimate of total contributions to its pension and other postretirement benefit plans in 2023 is $8 million ($8 million by the Utilities), compared to $43 million ($42 million by the Utilities) in 2022. In addition, the Company expects to pay directly $3 million ($1 million by the Utilities) of benefits in 2023, compared to $2 million ($1 million by the Utilities) paid in 2022.

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 March 31
	Pension benefits				Other benefits
(in thousands)	2023		2022		2023		2022
HEI consolidated
Service cost	$	11,396	$	19,824	$	344	$	656
Interest cost	25,621		19,811		2,157		1,637
Expected return on plan assets	(35,195)		(35,333)		(3,405)		(3,397)
Amortization of net prior period gain	—		—		(219)		(232)
Amortization of net actuarial (gain)/losses	188		6,297		(449)		(3)
Net periodic pension/benefit cost (return)	2,010		10,599		(1,572)		(1,339)
Impact of PUC D&Os	18,133		9,551		1,425		1,219
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)	$	20,143	$	20,150	$	(147)	$	(120)
Hawaiian Electric consolidated
Service cost	$	11,019	$	19,318	$	340	$	649
Interest cost	23,698		18,462		2,063		1,573
Expected return on plan assets	(32,972)		(33,546)		(3,353)		(3,347)
Amortization of net prior period gain	—		—		(218)		(231)
Amortization of net actuarial (gain)/losses	19		6,125		(434)		—
Net periodic pension/benefit cost (return)	1,764		10,359		(1,602)		(1,356)
Impact of PUC D&Os	18,133		9,551		1,425		1,219
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)	$	19,897	$	19,910	$	(177)	$	(137)

HEI consolidated recorded retirement benefits expense of $11 million ($11 million by the Utilities) in the first three months of 2023 and $12 million ($12 million by the Utilities) in the first three months of 2022 and charged the remaining net periodic benefit cost primarily to electric utility plant.

The Utilities have implemented pension and OPEB tracking mechanisms under which all of their retirement benefit expenses (except for executive life and nonqualified pension plan expenses) determined in accordance with GAAP are recovered over time. Under the tracking mechanisms, any actual costs determined in accordance with GAAP that are over/under amounts allowed in rates are charged/credited to a regulatory asset/liability. The regulatory asset/liability for each utility will then be amortized over five years beginning with the respective utility’s next rate case.

Defined contribution plans information.  For the first three months of 2023 and 2022, 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 $2.7 million and $2.0 million, respectively, and cash contributions were $2.7 million and $1.9 million, respectively. For the first three months of 2023 and 2022, the Utilities’ expenses and cash contributions for its defined contribution plan under the HEIRSP were $1.3 million and $0.9 million, respectively.

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Note 9 · Share-based compensation

Under the 2010 Equity and Incentive Plan, as amended and restated effective March 1,2014 (EIP), 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 original 2010 Equity and Incentive Plan was amended and restated effective March 1, 2014 and an additional 1.5 million shares were added to the shares available for issuance under these programs.

As of March 31, 2023, approximately 2.7 million shares remained available for future issuance under the terms of the EIP, assuming recycling of shares withheld to satisfy statutory tax liabilities relating to EIP awards, including an estimated 0.7 million shares that could be issued upon the vesting of outstanding restricted stock units and the achievement of performance goals for awards outstanding under long-term incentive plans (assuming that such performance goals are achieved at maximum levels).

Under the 2011 Nonemployee Director Stock Plan (2011 Director Plan), HEI can issue shares of common stock as compensation to nonemployee directors of HEI, Hawaiian Electric and ASB. As of March 31, 2023, there were 207,118 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 March 31
(in millions)	2023		2022
HEI consolidated
Share-based compensation expense 1	$	2.0	$	2.1
Income tax benefit	0.3		0.3
Hawaiian Electric consolidated
Share-based compensation expense 1	0.7		0.6
Income tax benefit	0.1		0.1

1    For the three months ended March 31, 2023 and 2022, 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 March 31
(dollars in millions)	2023		2022
Shares granted	1,509		—
Fair value	$	0.1	$	—
Income tax benefit	—		—

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.

Restricted stock units.  Information about HEI’s grants of restricted stock units was as follows:

	Three months ended March 31
	2023				2022
	Shares		(1)		Shares		(1)
Outstanding, beginning of period	182,528		$	39.75	233,448		$	38.10
Granted	100,088		42.41		96,455		41.29
Vested	(80,077)		39.30		(90,380)		37.58
Forfeited	(406)		38.39		(31,178)		38.78
Outstanding, end of period	202,133		$	41.25	208,345		$	39.71
Total weighted-average grant-date fair value of shares granted (in millions)	$	4.2			$	4.0

(1)    Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.

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For the three months ended March 31, 2023 and 2022, total restricted stock units and related dividends that vested had a fair value of $3.6 million and $3.9 million, respectively, and the related tax benefits were $0.8 million and $0.6 million, respectively.

As of March 31, 2023, there was $7.5 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 2021-23, 2022-24 and 2023-25 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 Peer Group (Edison Electric Institute Index (EEI Index) for the 2021-23 and 2022-24 performance periods, and compared to the Company's compensation peer group consisting of companies in the EEI Index and approved by the Company's Compensation and Human Capital Management Committee for the 2023-25 performance period), in each case over the relevant three-year period. The other performance condition goals relate to EPS growth, cumulative EPS, return on average common equity (ROACE), renewable portfolio standards, carbon emissions reduction, 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 March 31
	2023				2022
	Shares		(1)		Shares		(1)
Outstanding, beginning of period	71,574		$	47.67	90,974		$	42.86
Granted	27,123		55.98		26,079		54.92
Vested (issued or unissued and cancelled)	(18,691)		48.62		(29,042)		41.07
Forfeited	—		—		(11,671)		42.60
Outstanding, end of period	80,006		$	50.27	76,340		$	47.70
Total weighted-average grant-date fair value of shares granted (in millions)	$	1.5			$	1.4

(1)    Weighted-average grant-date fair value per share determined using a Monte Carlo simulation model.

The grant date fair values of the shares were determined using a Monte Carlo simulation model utilizing actual information for the common shares of HEI and the Peer Group for the period from the beginning of the performance period to the grant date and estimated future stock volatility of HEI and the Peer Group over the remaining three-year performance period. The expected stock volatility assumptions for HEI and the 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.

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:

	2023		2022
Risk-free interest rate	4.19	%	1.71	%
Expected life in years	3		3
Expected volatility	33.1	%	31.0	%
Range of expected volatility for Peer Group	28.7% to 38.8%		25.4% to 76.7%
Grant date fair value (per share)	$55.98		$54.92

There were no share-based LTIP awards linked to TSR with a vesting date in 2023. For the three months ended March 31, 2022, total vested LTIP awards linked to TSR and related dividends had a fair value of $0.8 million and the related tax benefits were $0.1 million.

As of March 31, 2023, there was $2.4 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 1.7 years.

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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 March 31
	2023				2022
	Shares		(1)		Shares		(1)
Outstanding, beginning of period	309,589		$	39.50	306,342		$	38.42
Granted	108,499		42.41		104,300		41.29
Vested	(62,778)		48.07		(71,807)		37.68
Forfeited	—		—		(46,684)		36.77
Outstanding, end of period	355,310		$	38.87	292,151		$	39.89
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)	$	4.6			$	4.3

(1)    Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.

For the three months ended March 31, 2023 and 2022, total vested LTIP awards linked to other performance conditions and related dividends had a fair value of $2.9 million and $3.2 million, respectively, and the related tax benefits were $0.6 million and $0.4 million, respectively.

As of March 31, 2023, there was $7.4 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) for the three months ended March 31, 2023 were 21% and 22%, respectively. 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 2017 Tax Cuts and Jobs Act that lowered the federal income tax rate from 35% to 21% and the tax benefits derived from the low income housing tax credit investments.

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 audit is still in progress and the Company has responded to all information requests. The Company has not been notified of any material audit adjustments to date.

The Inflation Reduction Act of 2022 (IRA) was signed by President Biden on August 16, 2022. Key provisions under the IRA include a 15% corporate alternative minimum tax (CAMT) imposed on certain large corporations and a 1% excise tax on stock repurchases after December 31, 2022. Based on current interpretation of the law and current guidance available we do not believe HEI will be impacted by the CAMT or stock repurchase excise tax provisions.

The IRA also creates new tax credits and enhances others to stimulate investment in renewable energy sources. Certain provisions of the IRA became effective beginning tax year 2023. The Company continues to monitor guidance and assess related tax planning opportunities.

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Note 11 · Cash flows

Three months ended March 31	2023		2022
(in millions)
Supplemental disclosures of cash flow information
HEI consolidated
Interest paid to non-affiliates, net of amounts capitalized	$	21	$	10
Hawaiian Electric consolidated
Interest paid to non-affiliates	6		6
Income taxes paid (including refundable credits)	3		—
Supplemental disclosures of noncash activities
HEI consolidated
Property, plant and equipment
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)	50		24
Increase related to an acquisition (investing)	—		15
Right-of-use assets obtained in exchange for finance lease obligations (financing)	40		—
Right-of-use assets obtained in exchange for operating lease obligations (investing)	1		35
Common stock issued (gross) for director and executive/management compensation (financing)1	7		8
Obligations to fund low income housing investments (investing)	7		—
Unsettled trades to purchase investment securities (investing)	—		25
Other receivable related to pending sales proceeds from the sale of an equity-method investment (investing)	—		9
Hawaiian Electric consolidated
Electric utility property, plant and equipment
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)	48		21
Increase related to an acquisition (investing)	—		15
Right-of-use assets obtained in exchange for finance lease obligations (financing)	40		—
Right-of-use assets obtained in exchange for operating lease obligations (investing)	—		32

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.

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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 initially measured at fair value (less estimated costs to sell) and subsequently measured at the lower of the carrying value or fair value less selling costs. Fair values 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.

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Forward sales commitments. To be announced (TBA) mortgage-backed securities forward commitments are classified as Level 1, and consist of publicly-traded debt securities for which identical fair values can be obtained through quoted market prices in active exchange markets. The fair values of ASB’s 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.

Interest rate swaps. The Company measures its interest rate swaps at fair value. The fair values of the Company's interest rate swaps are based on the estimated amounts that the Company would receive or pay to terminate the contracts at the reporting date and are determined using interest rate pricing models and interest rate related observable inputs. The fair values of the Company's interest rate swaps are classified as a 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 amount		Quoted prices in active markets for identical assets  (Level 1)		Significant  other observable  inputs  (Level 2)		Significant unobservable inputs  (Level 3)		Total
March 31, 2023
Financial assets
HEI consolidated
Available-for-sale investment securities	$	1,419,755	$	—	$	1,404,989	$	14,766	$	1,419,755
Held-to-maturity investment securities	1,238,185		—		1,158,090		—		1,158,090
Loans, net	5,988,718		—		661		5,605,699		5,606,360
Mortgage servicing rights	8,745		—		—		18,117		18,117
Derivative assets	38,050		9		1,133		—		1,142
Financial liabilities
HEI consolidated
Deposit liabilities	843,415		—		829,709		—		829,709
Short-term borrowings—other than bank	148,802		—		148,802		—		148,802
Other bank borrowings	680,690		—		675,107		—		675,107
Long-term debt, net—other than bank	2,480,948		—		2,296,948		—		2,296,948
Derivative liabilities	250		4		—		—		4
Hawaiian Electric consolidated
Long-term debt, net	1,834,320		—		1,702,247		—		1,702,247
December 31, 2022
Financial assets
HEI consolidated
Available-for-sale investment securities	$	1,429,667	$	—	$	1,414,765	$	14,902	$	1,429,667
Held-to-maturity investment securities	1,251,747		—		1,150,971		—		1,150,971
Loans, net	5,907,514		—		821		5,453,381		5,454,202
Mortgage servicing rights	9,047		—		—		17,646		17,646
Derivative assets	16,220		18		1,330		—		1,348
Financial liabilities
HEI consolidated
Deposit liabilities	611,718		—		597,617		—		597,617
Short-term borrowings—other than bank	172,568		—		172,568		—		172,568
Other bank borrowings	695,120		—		695,095		—		695,095
Long-term debt, net—other than bank	2,384,980		—		2,122,605		—		2,122,605
Derivative liabilities	22,949		—		472		—		472
Hawaiian Electric consolidated
Short-term borrowings	87,967		—		87,967		—		87,967
Long-term debt, net	1,684,816		—		1,487,496		—		1,487,496

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Fair value measurements on a recurring basis.  Assets and liabilities measured at fair value on a recurring basis were as follows:

	March 31, 2023						December 31, 2022
	Fair value measurements using						Fair value measurements using
(in thousands)	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
Available-for-sale investment securities (bank segment)
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	$	—	$	1,283,935	$	—	$	—	$	1,292,968	$	—
U.S. Treasury and federal agency obligations	—		79,744		—		—		81,063		—
Corporate bonds	—		41,310		—		—		40,734		—
Mortgage revenue bonds	—		—		14,766		—		—		14,902
	$	—	$	1,404,989	$	14,766	$	—	$	1,414,765	$	14,902
Derivative assets
Interest rate lock commitments (bank segment)1	$	—	$	26	$	—	$	—	$	9	$	—
Forward commitments (bank segment)1	9		—		—		18		—		—
Interest rate swap (Other segment)2	—		1,107		—		—		1,321		—
	$	9	$	1,133	$	—	$	18	$	1,330	$	—
Derivative liabilities
Forward commitments (bank segment)1	$	4	$	—	$	—	$	—	$	—	$	—
Interest rate swap (Other segment)2	—		—		—		—		472		—
	$	4	$	—	$	—	$	—	$	472	$	—

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.

There were no transfers of financial assets and liabilities between Level 1 and Level 2 of the fair value hierarchy during the three months ended March 31, 2023 and 2022.

The changes in Level 3 assets and liabilities measured at fair value on a recurring basis were as follows:

	Three months ended March 31
Mortgage revenue bonds	2023		2022
(in thousands)
Beginning balance	$	14,902	$	15,427
Principal payments received	(136)		(131)
Purchases	—		—
Unrealized gain (loss) included in other comprehensive income	—		—
Ending balance	$	14,766	$	15,296

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 March 31, 2023, the weighted average discount rate was 5.07%, 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.

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. As of March 31, 2023 and December 31, 2022, there were no financial instruments measured at fair value on a nonrecurring basis.

For the three months ended March 31, 2023 and 2022, there were no adjustments to fair value for ASB’s loans held for sale.

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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 2022 Form 10-K and should be read in conjunction with such discussion and the 2022 annual consolidated financial statements of HEI and Hawaiian Electric and notes thereto included in HEI’s and Hawaiian Electric’s 2022 Form 10-K, as well as the quarterly (as of and for the three months ended March 31, 2023) condensed consolidated financial statements and notes thereto included in this Form 10-Q.

HEI consolidated

Recent developments. In the first quarter of 2023, economic conditions in Hawaii remained stable with seasonally adjusted unemployment rate at 3.5% for March 2023 and total passenger counts for the first quarter of 2023 up nearly 20% from the same quarter last year. While economic conditions remained stable during the quarter, the Utility’s kWh sales in the first quarter of 2023 were down by 1.1%, compared to the first quarter of 2022 due to the continued adoption of energy efficiency measures and distributed energy resources. 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 the decoupling mechanism.

At the Bank, due to an increase in wholesale borrowings and term certificates, which was driven primarily by strong loan growth in 2022 coupled with an outflow of core deposits which started in the latter half of 2022 and continued through the first quarter of 2023, the Bank’s asset sensitivity decreased in 2022 and remained less asset sensitive in 2023 compared to prior years. As a consequence, the increase in market interest rates in the first quarter of 2023 did not have a measurable impact on net interest income and net interest margin. For the first quarter of 2023, the Bank’s net interest margin was 2.85% compared to net interest margin of 2.91% for the linked quarter ended December 31, 2022 and 2.79% for the quarter ended March 31, 2022.

In March 2023, the banking industry experienced significant turmoil with the failures of Silicon Valley Bank and Signature Bank. The failures of these banks were in part due to a significant concentration of deposits in certain industries that contributed to a significant amount of deposit withdrawals that occurred in a short period of time. Both banks had a significant amount of uninsured deposits that exceeded the FDIC insured limits, totaling 88% and 90% for Silicon Valley Bank and Signature Bank, respectively, as of December 31, 2022, which contributed to the “run” on these institutions as depositors became concerned about their bank’s solvency.

As of March 31, 2023, ASB’s uninsured deposit base was approximately 15%. Additionally, ASB’s total deposit base is primarily composed of retail deposits, which represented 86% of the total deposit base as of March 31, 2023. Retail deposits are generally less rate sensitive and less volatile compared to commercial deposits. ASB also remains “well capitalized” with approximately $3.2 billion in liquidity, which is nearly three times the amount of uninsured deposits as of March 31, 2023.

ASB’s funding cost, which impacts its net interest margin, is driven by the mix of its funding sources, with the lowest cost source of funding provided by its core deposits. In the first quarter of 2023, ASB’s average core deposits were down approximately 2.6% from average balances in the fourth quarter of 2022, which resulted in an increase in ASB’s wholesale borrowings and term certificates to fund loan growth and increased its overall cost of funds. Looking forward, ASB expects that its deposit base will remain relatively flat to down, given the higher interest rate environment, as well as inflationary pressures on customers that may drive increased spending. ASB also expects that the higher interest rate environment will continue to pressure funding costs, which in turn will affect net interest income and net interest margin.

Over the past few months, inflation increased rapidly as reflected in the U.S. Consumer Price Index (CPI). While inflationary pressures, as measured by CPI, appear to have peaked in June of last year, inflation remains high at 5% as of March 2023. The inflationary pressures are expected to continue over the near- to medium-term and have led to higher costs for O&M and capital projects and higher interest expense at the Utility and HEI, as well as higher compensation and benefits cost at the bank.

Short-term interest rates have also increased significantly as a result of the Federal Reserve’s ongoing rate increases to the federal funds target rate. The higher interest rate environment has impacted the fair value of the Bank’s investment portfolio, which declined and was recorded as an other comprehensive loss. Unrealized losses on held-to-maturity (HTM) securities are not recorded to other comprehensive loss because ASB has the positive intent and ability to hold the securities till maturity and recover its full investment. At March, 31, 2023, the unrealized losses on HTM securities not recorded to other comprehensive losses was approximately $59 million after tax.

For further discussion of the impacts of inflation and other macro-economic factors impacting the Utilities and the Bank, see “Recent Developments” in the Electric Utility and Bank sections below.

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RESULTS OF OPERATIONS

	Three months ended March 31				%
(in thousands)	2023		2022		change	Primary reason(s)*
Revenues	$	928,237	$	785,068	18	Primarily increase for all segments.
Operating income	93,518		99,276		(6)	Lower operating income for bank segment and increase operating losses for “other” segment, partially offset by higher operating income for the electric utility segment.
Net income for common stock	54,721		69,167		(21)	Lower net income at the bank segment and higher net loss for the “other” segment, partly offset by slightly higher net income for the electric utility segment. See below for effective tax rate explanation.

*     Also, see segment discussions which follow.

The Company’s effective tax rates for the first three months of 2023 and 2022 were 21% and 20%, respectively. The effective tax rate was higher for the first quarter of 2023 primarily due to lower amortization in 2023 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, partially offset by higher nontaxable bank owned life insurance and low-income housing tax credit tax benefits in 2023.

Economic conditions.

Note: The statistical data in this section is from public third-party sources that management believes to be reliable (e.g., Department of Business, Economic Development and Tourism (DBEDT), University of Hawaii Economic Research Organization (UHERO), U.S. Bureau of Labor Statistics, Department of Labor and Industrial Relations (DLIR), Hawaii Tourism Authority (HTA), Honolulu Board of REALTORS® and national and local news media).

In the first quarter, the average daily passenger count was 20% higher than the comparable period in the prior year, but remained nearly even with 2019. The recovery in total passenger counts from the low levels in 2020 thus far has been driven by domestic travelers, with international travelers, primarily Japan, remaining at low levels, but activity is increasing. On October 11, 2022, Japan eliminated the daily entry cap into Japan, which had previously made travel to and from Hawaii more difficult. Since then, international visitor arrivals have continued to increase at a modest pace, but still 50% below 2019 levels.

Hawaii’s preliminary seasonally adjusted unemployment rate in March 2023 was 3.5%, which was higher compared to the March 2022 rate of 3.3%. The national unemployment rate in March 2023 was 3.5% compared to 3.6% in March 2022. Hawaii’s job sectors are expected to see slower job growth and may see a slight increase in the unemployment rate in 2023.

Hawaii real estate activity through March 2023, as indicated by Oahu’s home resale market, resulted in a 4.0% increase in the median sales price ($536,000) for condominiums, beating the previous record set back in June 2022, and a decrease of 5.8% for single-family homes compared to the same period in 2022, with the March median single-family home price of $1,083,750. In spite of the continued strength in sales prices, most condo and single-family homes sold for less than the original asking price in the first quarter of 2023. The number of closed sales decreased 38.9% for condominiums and 37% for single-family residential homes through the first quarter of 2023 compared to 2022.

Hawaii’s petroleum product prices relate to the price of crude oil in international markets. The price of crude oil declined in August 2022 through December 2022 and has remained relatively flat during January 2023 – March 2023.

At its March 22, 2023 meeting, the Federal Open Market Committee (FOMC) decided to raise the federal funds rate target range to 4.75%-5.0% and anticipates ongoing increases as appropriate. With inflation being above the longer-run goal of 2 percent, the FOMC raised the federal funds rate 25 basis points and intends to further reduce the Federal Reserve’s holdings of Treasury securities, agency debt, and agency mortgage-backed securities.

The most recent forecast by UHERO, issued on March 10, 2023, forecasts full year 2023 real GDP growth of 1.7%, an increase in total visitor arrivals of 6.7%, an increase in real personal income of 1.2%, and an unemployment rate of 4.1%. This forecast anticipates the Hawaii economy slowing but no recession due to U.S. and global economies improving recently in the past few months as well as a moderation of domestic inflation. Later in the year, domestic travel is expected to weaken due to economic headwinds, while the Japanese market is expected to improve but at a gradual pace. Other risks remain as the Fed continues its efforts to combat inflation, but UHERO believes that Hawaii is in a relatively good economic position and can focus on addressing long term issues such as the visitor experience, tourism capacity, housing cost and availability, aging population and climate change.

The Company expects economic conditions in Hawaii to remain relatively stable going forward, supported by the expected recovery in the international tourism market and increased construction spending in the public sector. If economic conditions

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worsen from current levels or remain depressed for an extended period of time, it could have a material unfavorable impact on the Company’s financial position or results of operations.

See also “Recent Developments” in the “Electric utility” and “Bank” sections below for further discussion of the economic impact caused by the pandemic.

“Other” segment.

	Three months ended March 31
(in thousands)	2023		2022		Primary reason(s)
Revenues	$	4,019	$	1,161	Increase in other sales at Pacific Current subsidiaries.
Operating loss	(5,877)		(4,349)		The first three months of 2023 and 2022 include $1.1 million operating losses and $0.8 million of operating income, respectively, from Pacific Current1. The higher operating loss is primarily due to lower Pacific Current asset performance. Corporate expenses for the first three months of 2023 were $0.4 million lower than the same period in 2022, primarily due to lower general and administrative expenses.
Gain on sale of equity-method investment	—		8,123		Gain on sale of an equity-method investment at Pacific Current in first quarter of 2022.
Net loss	(10,850)		(1,112)		The net loss for the first three months of 2023 was higher than the net loss for the first three months of 2022 due to the first quarter of 2022 gain on sale of an equity-method investment by Pacific Current, higher interest expense primarily due to higher average borrowings and higher average rates and 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, Mahipapa, which owns a 7.5 MW nameplate biomass facility on Kauai, Alenuihaha 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 March 31, 2023, there was no balance on HEI’s revolving credit facility or Hawaiian Electric’s revolving credit facility and the available committed capacities under the facilities were $175 million and $200 million, respectively. At the end of the quarter, HEI and Hawaiian Electric had approximately $49 million and nil of commercial paper outstanding, respectively. As of March 31, 2023, ASB’s unused FHLB borrowing capacity was approximately $2.0 billion and ASB had unpledged investment securities of $0.9 billion that were available to be used as collateral for additional borrowing capacity.

As of March 31, 2023 and December 31, 2022, the total amount of available borrowing capacity (net of commercial paper outstanding) under the Company’s committed lines of credit was approximately $326 million and $237 million, respectively.

On October 20, 2022, HEI entered into a term loan facility in the aggregate principal amount of $100 million. On December 28, 2022, HEI drew $35 million on the term loan and on March 31, 2023, HEI drew the remaining $65 million. Any borrowings under the facility mature on November 30, 2023. Borrowings under the facility bear interest at Term SOFR, as defined in the agreement, plus an applicable margin and a SOFR spread adjustment. See Note 5 of the Condensed Consolidated Financial Statements for additional information.

On March 16, 2023, HEI executed a private placement under which HEI has authorized the issue and sale of $100 million of unsecured senior notes that may be drawn on a delayed basis on or before June 2, 2023. Once drawn, the proceeds totaling $100 million are expected to be used to refinance borrowings under the term loan facility. See Note 5 of the Condensed Consolidated Financial Statements for additional information.

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The Company believes that its cash and cash equivalents, expected operating cash flow from subsidiaries, existing credit facilities, and access to the capital markets will be sufficient to meet the Company’s cash requirements over the next 12 months and beyond based on its current business plans. However, the Company expects that its liquidity will continue to be moderately impacted at the Utilities due to higher working capital requirements resulting from lingering COVID-19 impacts to the local economy and elevated fuel prices. For the Utilities, while fuel prices have moderated from its highs in 2022, they remain elevated and have increased the cost of carrying fuel inventory and have also resulted in higher customer accounts receivable balances as fuel is consumed and billed to customers. While the accounts receivable balance has decreased since December 2022, it remains elevated coming out of the pandemic and has led to higher bad debt expense and higher write-offs in 2022 and year-to-date March 2023, following the end of the moratorium on disconnections. The higher bad debt expense is expected to continue until the Utilities reinstate pre-pandemic collection practices for delinquent accounts. As of March 31, 2023, approximately $38.5 million of the Utilities’ accounts receivables were over 30 days past due. Of the over 30 days past due amounts, approximately 27% were on payment plans. In addition to the cash flow impact from delayed collection of accounts receivable, lower kWh sales relative to the level of kWh sales approved in the last rate case generally result in delayed timing of cash flows, resulting in higher working capital requirements (see “Recent Developments” 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. ASB’s cash and cash equivalents was $183 million as of March 31, 2023, compared to $156 million as of December 31, 2022. ASB remains well above the “well capitalized” level under the FDIC Improvement Act prompt correction action capital category, and while the Hawaii economic outlook remains stable, there are emerging risks from potential continued turmoil in the banking industry, inflation, and the tightening of monetary policy that increase the risk of a recession, which could create increased uncertainty regarding the impact on loan performance and the allowance for credit losses (see “Recent Developments” in the Bank section below).

If further liquidity is deemed necessary, which is not contemplated at this time, the Utilities could also reduce the pace of capital spending related to non-essential projects. Additionally, the Company has the option to issue new shares rather than purchase currently outstanding shares on the open market to satisfy share issuances under its Dividend Reinvestment and Stock Purchase Plan program. The estimated amount of equity capital that could be raised by issuing new shares, rather than utilizing open market purchases, is estimated to be approximately $25 million to $30 million on an annual basis, based on historical demand, but such future amount is dependent on a number of factors, including, without limitation, future share prices, number of shares and participants in the DRIP program, and the amount of new investment in HEI’s stock by DRIP participants.

HEI material cash requirements. HEI’s material cash requirements include: Utility capital expenditures, labor and benefit costs, O&M expenses, fuel and purchase power costs, and debt and interest payments; investments in loans and investment securities at the Bank; labor and benefits costs, shareholder dividends and debt and interest payments at HEI; and HEI equity contributions to support Pacific Current’s sustainable infrastructure investments.

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 short-term and long-term material cash requirements. However, the economic impact of higher fuel prices, inflation, higher interest rates, debt ceiling debate and tightening of monetary policy create significant uncertainty, and the Company cannot predict the future effects that these factors 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)	March 31, 2023				December 31, 2022
Short-term borrowings—other than bank, net of discount	$	149	3	%	$	173	3	%
Long-term debt, net—other than bank	2,481		51		2,385		50
Preferred stock of subsidiaries	34		1		34		1
Common stock equity	2,238		45		2,202		46
	$	4,902	100	%	$	4,794	100	%

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HEI’s commercial paper borrowings and line of credit facility were as follows:

	Average balance		Balance
(in millions)	Three months ended March 31, 2023		March 31, 2023		December 31, 2022
Commercial paper	$	54	$	49	$	50
Line of credit draws on revolving credit facility	—		—		—

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 three months of 2023 was $99 million. As of March 31, 2023, available committed capacity under HEI’s line of credit facility was $175 million.

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 three months ended March 31, 2023 and 2022 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 three months of 2023, net cash provided by operating activities of HEI consolidated was $181 million. Net cash used by investing activities for the same period was $137 million, primarily due to capital expenditures, ASB’s net increase in loans receivable and purchases of loans held for investment, partly offset by ASB’s receipt of investment security repayments and maturities and a net decrease in FHLB stock. Net cash provided by financing activities during this period was $71 million as a result of several factors, including net increases in ASB’s deposit liabilities, issuances of other bank borrowings, long-term debt and short-term borrowings, partly offset by net decreases in other bank borrowings and short-term borrowings, repayment of long-term debt and payment of common stock dividends. During the first three months of 2023, Hawaiian Electric and ASB (through ASB Hawaii) paid cash dividends to HEI of $32 million and $14 million, respectively.

Dividends.  The payout ratios for the first three months of 2023 and full year 2022 were 72% and 64%, respectively. On February 10, 2023, the HEI Board of Directors approved a 1 cent increase in the quarterly dividend from $0.35 per share to $0.36 per share, starting with the dividend in the first quarter of 2023. 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, 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 44 to 45, 64, and 77 to 78 of HEI’s MD&A included in Part II, Item 7 of HEI’s 2022 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. See also “Recent developments” in HEI’s MD&A.

In the first quarter of 2023, kWh sales volume decreased 1.1% compared to the same period in 2022. The decrease in kWh sales is primarily due to higher electricity prices in the first quarter of 2023, which impacted electricity consumption, and the continued adoption of energy efficiency measures and distributed energy resources.

Fuel costs have risen rapidly beginning in 2022 and average fuel prices have increased 35% over the same quarter in the prior year, but have decreased since December 31, 2022. Although the Utilities are able to pass through fuel costs to customers and have limited fuel cost exposure through a 2% fuel-cost risk sharing mechanism (approximately $3.7 million maximum exposure annually, and the amount the Utilities have recognized as a penalty for 2022), higher customer bills could reduce customers’ ability to pay timely or increase the risk of non-payment. In addition, the higher customer bills may lead the PUC to consider other actions to limit or delay any proposed increase in rates in order to mitigate the overall bill impact of rising fuel prices. The rising fuel costs are not expected to materially impact the Utilities’ financial position at this time.

In March 2023, the consumer price index moderated to 5% from a peak of 9.1% in June 2022. In Hawaii, the March 2023 Urban Hawaii (Honolulu) Consumer Price Index (CPI) also declined from its peak, with an increase of 3.3% over the last 12 months. Under the PBR framework, inflation risk for the Utilities is mitigated by an Annual Rate Adjustment (ARA), which is based on a formula that includes a compounded and non-compounded portion.

•The compounded portion of the ARA adjustment includes an adjustment for inflation based on the estimated change in Gross Domestic Product Price Index (GDPPI) for the upcoming year, less a predetermined annual productivity factor (currently set at zero), less a 0.22% customer dividend, applied to a basis equal to test year target revenues plus the RAM Revenue adjustments in effect prior to the implementation of PBR, plus the prior adjustment year’s compounded portion of the ARA adjustment. The GDPPI adjustment is determined using the forecasted GDPPI in October, which is effective for the following calendar year. For the 2022 calendar year, GDPPI was measured at 2.78% (net of the 0.22% customer dividend) in October 2021 and was effective in rates on January 1, 2022. For the 2023 calendar year, the forecasted 2023 GDPPI was 3.68% (net of the 0.22% customer dividend), measured in October 2022, and became effective in rates on January 1, 2023.

•The non-compounded portion of the ARA adjustment includes a subtractive component, representing the management audit savings commitment, or refund to customers, which was approved by the PUC for the years 2021 through 2025.

Accounts receivable decreased in 2023 by $53.0 million, or 18% with the number of accounts past due decreasing by 8% since December 31, 2022. The decrease in accounts receivables was primarily driven by payment on a large delinquent commercial customer account, payments on installment plans, receipt of government and other program assistance, and higher cash receipts associated with increased disconnection efforts. At this time, while accounts receivable balances remain elevated compared to pre-pandemic levels, the higher balances have 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 Revenue Balancing Account and the impact of higher fuel prices on accounts receivable balances. See “Financial Condition—Liquidity and capital resources” for additional information.

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. The Utilities deferred COVID-19 related costs through a PUC approved period that ended on December 31, 2021. In the second quarter of 2022, the Utilities filed an application to seek recovery of the COVID-19 deferred costs, not to exceed the amount of $27.8 million. On January 25, 2023, the PUC issued an order to modify the procedural schedule to allow more time for more discovery and consideration of the application. Consistent with the order, in the Utilities’ First Supplemental Report submitted to the PUC on April 28, 2023, the Utilities updated the estimated maximum COVID-19 total recovery request amount to $9.6 million as of March 31, 2023. (See discussion under “Regulatory assets for COVID-19 related costs” in Note 3 of the Condensed Consolidated Financial Statements).

Hawaii COVID-19 case counts and hospitalizations have declined following peaks in the prior years; however, a worsening of COVID-19 cases driven by new variants or a reinstatement of COVID-19 restrictions could adversely affect the ability of the Utilities’ contractors, suppliers, IPPs, and other business partners to perform or fulfill their obligations timely, or at all, or require modifications to existing contracts, which could adversely affect the Utilities’ business, increase expenses, and impact the Utilities’ ability to achieve their RPS and other climate related goals.

Regulatory Developments. On November 15, 2021, President Biden signed into law the $1.2 trillion Infrastructure Investment and Jobs Act (IIJA), which includes approximately $550 billion of new federal spending to be allocated over the next five years through various programs. The funding will help our state achieve its sustainability goals, including renewable energy, resilience, decarbonization, while also prioritizing economic development, equity and affordability. The Utilities are

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pursuing potential grant funding of projects under various programs including, but not limited to, in partnership with other organizations. To date, the Utilities have participated in the submission of three full applications totaling $168 million. Out of the three applications, the Utilities are the primary applicants for two of the submissions, and if awarded, would allow for the reduction up to $138 million in the Utilities’ recovery under the Exceptional Project Recovery Mechanism (EPRM). See “Regulatory proceedings” in Note 3 of the Condensed Consolidated Financial Statements for additional discussions.

On August 16, 2022, President Biden signed into law the Inflation Reduction Act of 2022 (IRA) that provides for $258 billion in energy-related provisions over a 10-year period. The provisions of the IRA are intended to, among other things, lower gasoline and electricity prices, incentivize clean energy investment and promote reductions in carbon emissions. The Utilities are exploring clean energy tax incentives included in the IRA that may further reduce the Utilities’ recovery under the EPRM.

The Utilities cannot predict the ultimate timing and success of securing funding from any federal government programs.

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 March 31				Increase
2023		2022		(decrease)				(dollars in millions, except per barrel amounts)
$	830	$	709	$	121			Revenues. Net increase largely due to:
						$	123	higher fuel oil prices and higher kWh generated1
						10		higher revenue from ARA adjustments
						1		higher Major Project Interim Recovery (MPIR) revenue
						(12)		lower kWh purchased and lower purchased power adjustment clause (PPAC) revenues, offset by higher purchased power energy prices2
334		221		113				Fuel oil expense1. Net increase largely due to higher fuel oil prices, higher kWh generated, and worse heat rate resulting in higher penalties for fuel efficiency
153		164		(11)				Purchased power expense1, 2. Net decrease largely due to lower kWh purchased and lower AES charges due to its closure on September 1, 2022, partially offset in part by higher purchased power energy prices
128		125		3				Operation and maintenance expenses. Net increase largely due to:
						3		increased storm costs due to inclement weather
						3		more generating facility maintenance work performed
						(1)		lower transmission and distribution preventive and corrective maintenance expense
						(1)		lower liability and legal reserve for pending claims
						(2)		transition expense in 2022 related to ownership of and responsibility for the U.S. Army’s electrical distribution system on Oahu starting March, 1, 2022
139		125		14				Other expenses. Increase due to higher revenue taxes, coupled with higher depreciation expense due to increasing investments to integrate more renewable energy and improve customer reliability and system efficiency
76		74		2				Operating income. Increase largely due to higher ARA and MPIR revenue, offset in part by higher operation and maintenance expenses and higher depreciation expense
61		59		2				Income before income taxes. Increase largely due to higher operating income, partially offset by higher interest expense due to new debt issuance
47		46		1				Net income for common stock. Increase due to higher income before income taxes. See below for effective tax rate explanation
1,936		1,957		(21)				Kilowatthour sales (millions)3
$	139.88	$	103.40	$	36.48			Average fuel oil cost per barrel
472,257		470,851		1,406				Customer accounts (end of period)

1The rate schedules of the electric utilities currently contain energy cost recovery clauses (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.

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3 kWh sales were lower compared to prior year primarily due to higher electricity prices in the first quarter of 2023 which impacted electricity consumption, and the continued adoption of energy efficiency measures and distributed energy resources.

The Utilities’ effective tax rates for the first three months of 2023 and 2022 were 22% and 21%, respectively. The effective rates were higher for the first three months of 2023 primarily due to lower amortization in 2023 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.

Hawaiian Electric’s consolidated ROACE was 8.2% and 8.1% for the twelve months ended March 31, 2023 and March 31, 2022, respectively.

The net book value (cost less accumulated depreciation) of utility property, plant and equipment (PPE) as of March 31, 2023 amounted to $5 billion, of which approximately 24% related to generation PPE, 67% related to transmission and distribution PPE, and 9% related to other PPE. Approximately 7% 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 its decarbonization goals that are aligned with 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” 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’ decarbonization and renewable energy commitments, facilitating and promoting beneficial electrification, and deploying carbon removal and offsets among other levers to reduce statewide emissions.

In the fourth quarter of 2021, the Utilities outlined their Climate Action Plan to cut carbon emissions from power generation 70% by 2030, compared to a 2005 baseline. The emissions covered by this goal include stack emissions from generation owned by Hawaiian Electric and IPPs who sell electricity to the Utilities. The 2030 commitment would provide a significant portion of the reduction the entire Hawaii economy needs to meet the U.S. target of cutting carbon emissions by at least 50% economy-wide by 2030. Hawaiian Electric has also committed to achieving net zero carbon emissions from power generation by 2045 or sooner. Key elements of the 2030 plan include the closure of the state’s last coal-fired IPP plant that occurred in September 2022, increasing rooftop solar by more than 50% over 2021 levels, retiring six fossil fuel generating units, adding at least 1 GW of renewable generation to what was already in place in 2021, increasing grid-scale and customer-owned storage, expanding geothermal resources, and creating customer incentives for using clean, lower-cost energy at certain times of the day and using less fossil-fueled energy at night. The retirement of fossil-fueled generating units to achieve the Utilities’ 70% decarbonization goal is consistent with state policy and supported by Hawaii State law. See “Forecast of capital expenditures—Liquidity and capital resources” for a discussion of potential capital expenditures related to decarbonization efforts.

On September 1, 2022, the last coal-fired IPP plant in the state, providing approximately 10% of Oahu’s generation, ceased operations, removing a significant source of GHG emissions from the Utilities’ generation mix. In advance of the retirement of the coal-fired IPP plant, the Utilities developed plans, including contingency plans, to ensure reliable service through the transition period. These plans include the anticipated addition of renewable energy/storage projects, reserve capacity from existing generation sources, the acceleration of maintenance work during periods with anticipated higher reserve levels, and multiple demand response/DER programs. For example, the state’s largest solar plus battery storage project to date, totaling 39 MW, reached commercial operations on July 31, 2022.

While the Utilities continue to execute on their plans, delays and cancellations in the commercial operation of new renewable third-party generation resources and higher costs as a result of supply chain issues and inflationary pressures, as well as federal policies related to solar panel imports, have slowed the pace of progress toward achieving the Utilities’ 70% GHG emissions reduction goal. Despite these headwinds, the Utilities currently believe that the 70% GHG emissions reduction target remains achievable; however, additional renewable energy procurements and timely construction of significant generating

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capacity beyond the Stage 3 RFPs are required. Future events that impact the pace and amount of newly installed renewable variable and firm generation, including unexpected issues with existing generation, among other factors, could disrupt the ability of the Utilities to deliver reliable service. Also, see the “Developments in renewable energy efforts—New renewable PPAs” section below.

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’ strategies and plans are fully aligned in meeting these targets.

The Utilities have made significant progress on the path to clean energy and have been successful in achieving RPS goals. To date the Utilities have met all of the statutory RPS goals, including exceeding the last milestone RPS target of 30% for 2020, where it achieved an RPS of 34.5%. In July 2022, Governor Ige signed Act 240 (H.B.2089), that amended the RPS calculation from renewable energy as a percentage of sales to renewable energy as a percentage of total generation. The amended RPS calculation results in a lower calculated percentage than the amount calculated under the previous methodology. For example, the 2022 RPS achieved under the revised RPS calculation would have been 31.8% versus 39.1% under the prior method. The change in the definition is to be applied prospectively to future milestone measurements and will require that the Utilities acquire more renewable energy than under the previous RPS calculation to comply with the RPS milestones; however, the Utilities expect to continue to meet the RPS milestones under the amended RPS law. (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 total generation in 2022, a 1% shortfall in meeting the 2030 RPS requirement of 40% would translate into a penalty of approximately $2.1 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. Conversely, the Utilities have incentives under PIMs that provide a financial reward for accelerating the achievement of renewable generation as a percentage of total generation, including customer supplied generation. The Utilities may earn a reward for the amount of system generation above the interpolated statutory RPS goal at $20/MWh in 2022, $15/MWh in 2023, and $10/MWh for the remainder of the multi-year rate period.

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 trended lower over time as privately-owned DER have been added to the grid and energy efficiency measures have been put into place. Other regulatory mechanisms under the PBR framework reduce some of the regulatory lag during the multi-year rate plan (MRP), such as the annual revenue adjustment to provide annual changes in utility revenues, including inflationary adjustments, and the exceptional project recovery mechanism, which allows the Utilities to recover and earn on certain approved eligible projects placed into service. See “Regulatory proceedings” in Note 3 of the Condensed Consolidated Financial Statements.

Integrated Grid Planning. Achieving high levels of renewable energy and a carbon free electric system will require modernizing the grid through coordinated energy system planning in partnership with local communities and stakeholders. To accomplish this, the Utilities are implementing an innovative systems approach to energy planning intended to yield the most cost-effective renewable energy and decarbonization pathways that incorporates customer and stakeholder input.

The Integrated Grid Planning (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

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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. On March 31, 2023, the Utilities submitted their draft Integrated Grid Plan: A pathway to a clean energy future for stakeholder and public comments. The Integrated Grid Plan proposes actionable steps to decarbonize the electric grid on the State of Hawaii’s timeline, with a flexible framework that can adapt to future technologies. The Integrated Grid Plan is the culmination of more than five years of partnership with stakeholders and community members across the islands. Together, they forecasted future energy needs and identified strategies to meet Hawaii’s growing energy demand with 100% renewable resources.

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 132 MW of grid services with focus on capacity reduction (60 MW) similarly in response to the potential reserve shortfall from the AES coal plant retirement that occurred on September 1, 2022. The Utilities executed a GSPA for a total grid services amount of 97.4 MW and filed with the PUC to request approval on March 16, 2022. The procedural schedule steps are completed and the GSPA is ready for the PUC’s decision. As of March 31, 2023, the PUC has not ruled on this GSPA approval request.

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. As of March 31, 2023, the Utilities have received and approved the applications totaling approximately 21 MW on Oahu.

On March 30, 2022, the Utilities filed with the PUC to request expanding the EDRP for up to 15 MW on the island of Maui and received PUC approval on May 20, 2022. The EDRP on Maui became effective as of June 1, 2022. Subsequently on June 23, 2022, the PUC approved the cost recovery of the additional incentives for both Oahu and Maui through the Demand Side Management Surcharge. As of March 31, 2023, the Utilities have received and approved the applications totaling approximately 2.8 MW on Maui.

On October 31, 2022, the PUC issued an order, directing the Utilities to solicit comments from all interested parties and stakeholders on the Utilities’ Draft Grid Services RFP filed on June 30, 2022. The proposed Draft Grid Services RFP focused only on Maui and is seeking 15 MW of grid services. On December 22, 2022, the PUC issued an order approving Hawaiian Electric to proceed with the RFP with modifications. Hawaiian Electric submitted an update to the RFP per the order on January 16, 2023, and issued the RFP on February 1, 2023.

Grid modernization. The overall goal of the Grid Modernization Strategy is to deploy modern grid investments at an appropriate priority, sequence and pace to cost-effectively maximize flexibility, minimize the risk of redundancy and obsolescence, deliver customer benefits and enable greater DER and renewable energy integration. Under the Grid Modernization Strategy, the Utilities expect that new technology will help increase adoption of private rooftop solar and make use of rapidly evolving products, including storage and advanced inverters. On March 25, 2019, the PUC approved a plan for the Utilities to implement Phase 1 of their Grid Modernization Strategy, which is the proportional deployment of advanced metering infrastructure (AMI). On February 28, 2022, the PUC expanded the scope of Phase 1 to the full service territory with a completion date set for the third quarter of 2024. The estimated cost of full deployment (including proportional deployment) is approximately $143 million in capital and deferred software cost and is expected to be incurred over five years. As of March 31, 2023, approximately $95 million of capital and deferred software cost has been incurred to date under Phase 1 and is currently being recovered under the MPIR mechanism until such costs are included in base rates. On June 24, 2022, the PUC approved with certain conditions the Utilities’ request to aggregate the per-meter and network cost caps and to recover O&M costs associated with full-service territory AMI deployment under the MPIR mechanism. As of March 31, 2023, the Utilities have deployed about 237,000 advanced meters, servicing approximately 50% of total customers.

The Utilities filed an application with the PUC on September 30, 2019 for an Advanced Distribution Management System (ADMS) as part of Phase 2 of their Grid Modernization Strategy implementation. However, on December 30, 2019, the PUC suspended the Utilities’ application for the ADMS pending the Utilities’ filing of a supplemental application for the broad deployment of field devices. This supplement and update to the Grid Modernization Strategy 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 software costs 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. On November 16, 2021, the PUC suspended the Utilities’

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ADMS and Phase 2 field device application to focus the Utilities’ attention on completing Phase 1. The Utilities filed a Motion for Reconsideration with the PUC in response to the suspension, but the motion was denied. The PUC subsequently clarified that the Utilities may resume the Phase 2 docket no earlier than six months before Phase 1 is scheduled to be completed in the third quarter of 2024. Resumption of the Phase 2 proceeding would likely commence six months prior to the scheduled completion date selected by the PUC. On April 17, 2023, the Utilities filed a motion with the PUC, requesting the suspended docket to be reopened and to allow the Utilities to file an updated and supplemented application for updated project costs. On May 3, 2023, the PUC granted the motion to resume the docket, and will host a technical conference on the updated application on May 19, 2023.

Community-based renewable energy. In December 2017, the PUC adopted a community-based renewable energy (CBRE) program framework which allows customers who cannot, or chose not to, take advantage of private rooftop solar to receive the benefits of renewable energy to help offset their monthly electric bills and support clean energy for Hawaii. The program has two phases.

The first phase, which commenced in July 2018, totaling 8 MW of solar photovoltaic (PV) only with one credit rate for each island, closed on April 9, 2020. Two phase 1 projects (28.32 kW on Maui and 270 kW on Oahu) have been operational for two years, with four additional phase 1 projects expected to become operational in 2023 (second quarter: Oahu: 3,000kW, Hawaii Island: 750kW and Molokai: 250kW; third quarter: Oahu: 1,720kW).

The second phase, which commenced on April 9, 2020 and subsequently expanded on July 27, 2021, allows over 250 MW across all Hawaiian Electric service territories in two tranches for small (under 250 kW), mid-tier 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, 23 MW of capacity for dedicated-LMI projects were awarded on November 15, 2022 through three island specific RFPs for Oahu, Maui and Hawaii Island. LMI projects do not have a size cap nor do they decrease the 250 MW capacity available to other projects. The dedicated-LMI projects are expected to become operational in 2025.

The Utilities issued the CBRE Tranche 1 RFPs for Oahu, Maui and Hawaii on April 14, 2022. The RFPs closed on August 17, 2022, and proposals were evaluated. Tranche 1 projects, which are greater than or equal to 250 kW, were awarded on February 22, 2023. The Tranche 1 projects are expected to become operational in 2025 or 2026.

For Lanai, the Utilities combined the previously issued Variable Renewable Dispatchable Generation Paired with Energy Storage RFP and the CBRE RFP to optimize the benefits of procuring renewable energy, spur development and increase 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.

One CBRE proposal for Lanai was selected but negotiations were terminated on June 15, 2022. With the concurrence of the Independent Observer, a replacement proposal was selected on July 1, 2022. On July 25, 2022, the Utilities announced the selection of a new developer for the Lanai CBRE RFP. On September 21, 2022, the Utilities were informed by Pulama Lanai of a project being planned on Lanai to remove the two large resorts from the grid, which represent approximately 40% of the load of the island and raises great uncertainty around the future energy needs for Lanai. On September 28, 2022, the Utilities notified the PUC that ongoing negotiations for the Lanai CBRE project will continue, but that the Utilities will not execute a PPA at this time given the uncertainty due to the Pulama Lanai notification. On Molokai, proposals were only received from a single community co-op group. After evaluation of these proposals and with concurrence of the independent observer, the Utilities filed a letter on September 9, 2022, proposing to close the Molokai CBRE RFP and to work with the lone bidder to improve certain aspects of its two proposed projects outside of the RFP process for the benefit of the residents of Molokai. Discussions are ongoing.

The Utilities CBRE Phase 2 Rule 29 became effective on March 10, 2022. The Utilities are currently accepting project applications for small CBRE projects less than 250 kW in size. The PUC reserved 45 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. The Utilities have developed a CBRE Portal where Subscriber Organizations can apply for small project capacity and manage subscribers for all CBRE projects in the program. Customers can also use the CBRE Portal to solicit quotes, compare, and subscribe to a project once the Subscriber Organization has added their project to the portal.

Microgrid services tariff proceeding. In enacting Act 200 of 2018, the Hawaii legislature found that Hawaii’s residents and businesses were vulnerable to disruptions in the islands’ energy systems caused by extreme weather events or other disasters, and stated its belief that the use of microgrids would build energy resiliency into Hawaii’s communities, thereby increasing public safety and security. The purpose of Act 200 was therefore to encourage and facilitate the development and use of microgrids through the establishment of a standard microgrid services tariff. In July 2018, pursuant to Act 200, the PUC opened a proceeding to investigate the establishment of a microgrid services tariff. In August 2019, the PUC issued an order

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prioritizing items for resolution in the docket and directed the Parties to establish working groups (the Working Group) to address issues identified by the PUC.

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, specifically identifying the objective for Phase 2 to promote self-sufficiency and resilience among microgrid project operators, as well as to further streamline the Microgrid Services Tariff where applicable. Furthermore, the PUC 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, which the parties submitted by October 21, 2021.

On April 1, 2022, the PUC established its Prioritized Issues for Resolution for Phase 2 of the Microgrid proceeding, which includes the following: 1) Microgrid Compensation and Grid Services; 2) Utility Compensation; 3) Customer Protection and Related Considerations; 4) Interconnection; and 5) Working Group coordination with related microgrid and resilience Initiatives at Hawaiian Electric and government agencies. Furthermore, the PUC established a procedural schedule to consist of quarterly status conference meetings with the PUC, a Phase 2 Working Group Report, draft of a revised Microgrid Service Tariff, Party comments to the proposed Microgrid Service Tariff, followed by a PUC D&O.

On June 30, 2022, the PUC provided further guidance to the Working Group to prioritize discussion of the microgrid types in the following order: 1) Hybrid Microgrid - Third Party Developer using Utility lines/infrastructure; 2) Hybrid Microgrid - Utility Project with Partners; and 3) Customer Microgrid. Additionally, the PUC instructed the Working Group to discuss microgrid compensation and continue the involvement of microgrid developers in working group meetings.

The Working Group met from April 2022 through October 2022 to discuss the PUC’s objectives and respond to the Phase 2 priority issues. On October 31, 2022, the PUC issued a guidance letter and advised that the Working Group propose a new timeline for the Report. The Utilities and the Consumer Advocate filed a joint letter with a revised timeline on November 10, 2022. On November 21, 2022, the PUC issued an order to suspend the Phase 2 procedural schedule while it reviews the joint letter.

Decoupling. See “Decoupling” in Note 3 of the Condensed Consolidated Financial Statements for a discussion of decoupling.

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 2022, 2021 and 2020 did not trigger the earnings sharing mechanism for the Utilities.

Actual and PUC-allowed returns, as of March 31, 2023, were as follows:

%	Rate-making Return on rate base (RORB)*			ROACE**			Rate-making ROACE***
Twelve months ended  March 31, 2023	Hawaiian Electric	Hawaii Electric Light	Maui Electric	Hawaiian Electric	Hawaii Electric Light	Maui Electric	Hawaiian Electric	Hawaii Electric Light	Maui Electric
Utility returns	7.42	5.59	6.23	8.88	6.10	6.97	9.95	6.65	7.83
PUC-allowed returns	7.37	7.52	7.43	9.50	9.50	9.50	9.50	9.50	9.50
Difference	0.05	(1.93)	(1.20)	(0.62)	(3.40)	(2.53)	0.45	(2.85)	(1.67)

*      Based on recorded operating income and average rate base, both adjusted for items not included in determining electric rates.

**    Recorded net income divided by average common equity.

***  ROACE adjusted to remove items not included by the PUC in establishing rates, such as incentive compensation.

The gap between PUC-allowed ROACEs and the ROACEs achieved is primarily due to the exclusion of certain expenses from rates (for example, incentive compensation and charitable contributions), and depreciation, O&M expense and return on rate base that are in excess of what is currently being recovered through rates (the last rate case plus authorized RAM adjustments and ARA revenues).

Regulatory proceedings.  On December 23, 2020, the PBR D&O was issued, establishing the PBR Framework. The PBR Framework implemented a five-year 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. See also “Regulatory proceedings” in Note 3 of the Condensed Consolidated Financial Statements.

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Developments in renewable energy efforts.  The Utilities’ renewable energy goals depend, in large part, on the success of renewable projects developed and operated by independent power producers. Beginning in 2017, the Utilities embarked on an ambitious procurement effort, selecting multiple solar plus storage efforts to help reach the Utilities renewable portfolio standards goals as well as to assist the Utilities in retiring fossil fuel generation. Several of the recently procured projects have experienced delays as a result of supply chain disruptions caused by impacts from the COVID-19 pandemic, solar product detentions at U.S. ports of entry ordered by the U.S. Customs and Border Protection agency, and unforeseen site conditions which resulted in unanticipated project costs or in some cases the inability to effectively use previously identified project sites. These impacts have resulted in five Stage 2 projects declared null and void by the independent power producers and one Stage 2 project mutually terminating its PPA with the Utilities. Projects have also indicated potential impacts from the investigation launched by the U.S. Department of Commerce on March 28, 2022, in response to a request by Auxin Solar Inc. in regards to solar panel imports. On June 6, 2022, President Biden created a bridge to temporarily facilitate U.S. solar deployers’ ability to source certain imported solar modules and cells free of certain duties for 24 months in order to ensure the U.S. has access to a sufficient supply of solar modules to meet electricity generation needs. The Utilities are in discussions with several project developers regarding requests to increase previously approved prices and extend guaranteed commercial operations dates for those projects in order to ensure their viability given the impact of these recent market conditions. Significant project delays or failures of these projects increase the risk of the Utilities not meeting the renewable portfolio standards or other climate related goals, eligibility for performance incentive mechanisms associated with the speed of increasing renewable generation, and the ability to retire fossil fuel units. 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.

•On November 16, 2021, Hawaii Electric Light and Hawi Renewable Development, LLC (HRD) entered into an Amended and Restated Power Purchase Agreement (HRD ARPPA). Under the HRD ARPPA, HRD would make modifications to upgrade and repower the existing wind facility to enable it to continue to provide up to 10.56 MW of energy at a cost savings for customers. The HRD ARPPA is delinked from the price of fossil fuel and extends the term of the existing PPA by 20 years following the commercial operations date. On December 17, 2021, Hawaii Electric Light filed an application for approval of the HRD ARPPA, requesting a decision no later than June 15, 2022. On June 17, 2022, HRD notified the Utilities that the lead time for delivery and price of equipment needed for the repowering project had increased such that it would prevent HRD from achieving the required guaranteed commercial operation date. Additionally, HRD informed the Utilities that drastic changes in the market conditions had significantly impacted the financial viability of the project. On June 24, 2022, the Utilities requested that the PUC put the procedural schedule on hold to allow HRD time to re-evaluate its plans and determine what is needed to keep the project financially viable. On January 11, 2023, Hawaii Electric Light and HRD entered into a First Amendment to the HRD ARPPA (First Amendment). The First Amendment includes an extension of the Guaranteed Commercial Operations Date (GCOD) by 26 months to accommodate the delayed delivery of components, and a temporary price increase until HRD recovers its estimated increased costs specified in the First Amendment. On January 27, 2023, Hawaii Electric Light requested the PUC to resume the docket and on February 3, 2023, Hawaii Electric Light and the Consumer Advocate submitted a proposed procedural schedule to accommodate additional steps to review the First Amendment. The Amendment is currently pending approval before the PUC.

•On December 31, 2019, Hawaii Electric Light and Puna Geothermal Ventures entered into an Amended and Restated Power Purchase Agreement (PGV ARPPA). The PGV 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 16, 2022, the PUC issued a D&O, approving the PGV ARPPA, subject to conditions, that include requiring completion of a final environmental review prior to construction. On March 28, 2022, Puna Pono Alliance filed a Motion for Reconsideration seeking reconsideration, modification and/or vacation of the D&O. On June 6, the PUC denied Puna Pono’s Motion for Reconsideration. PGV notified the Utilities that changes in market conditions that transpired since the terms of the PGV ARPPA were negotiated impacted the financial viability of the Project, and that an amendment to the PGV ARPPA was necessary to mitigate the impacts. On March 27, 2023, the Utilities and PGV executed the First Amendment to the PGV ARPPA which increases the capacity payment and extends the GCOD. An application requesting approval of the First Amendment to the PGV ARPPA was filed on April 4, 2023.

•Under a request for proposal process governed by the PUC and monitored by independent observers, in February 2018, the Utilities issued Stage 1 Renewable 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. To date, summarized information for a total of eight PPAs is as follows:

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•

Utilities	Number of contracts	Total photovoltaic size (MW)	BESS Size (MW/MWh)	Guaranteed commercial operation dates	Contract term (years)	Total projected annual payment (in millions)
Hawaiian Electric	4	139.5	139.5/558	7/31/22, 1/11/23, 1/20/23* & 8/31/23**	20 & 25	$	32.0
Hawaii Electric Light	2	60	60/240	12/2/22** & 4/21/23	25	14.9
Maui Electric	2	75	75/300	4/28/23* & 10/27/23	25	17.6
Total	8	274.5	274.5/1,098			$	64.5

* Project delays have resulted in Guaranteed Commercial Operations Date being missed.

** Dates would change upon PUC approval of a PPA amendment.

The Utilities have received PUC approvals to recover the total projected annual payment of $64.5 million for the eight PPAs through the PPAC to the extent such costs are not included in base rates. To date, the Utilities filed six requests with the PUC for approval of amendments related to previously-approved PPAs for changes in pricing and/or guaranteed commercial operations dates to support completion of the projects while maintaining system reliability. The PUC has approved four amendments and two requests filed in February 2023 are pending PUC approval. On July 31, 2022, Mililani I Solar on Oahu, the first Stage 1 solar-pus-storage project, was placed into service. Waiawa Solar project on Oahu and the AES Waikoloa Solar project on Hawaii Island also reached commercial operations on January 11, 2023 and April 21, 2023, respectively. See also “Stage 1 renewable PPAs” in Note 3 of the Condensed Consolidated Financial Statements.

•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. To date, the Utilities had filed 11 PPAs. Additionally, two GSPAs and two applications for commitments of funds for capital expenditures for approval of the utility self-build projects were filed with the PUC. Of the 11 filed PPAs, six PPAs were declared null and void by the independent power producers and one PPA was mutually terminated. The most recent of these six PPAs was declared null and void by the developer on March 10, 2023; the Utilities filed a notice with the PUC on March 15, 2023. The four remaining projects have received PUC approval. On May 2, 2023, the Utilities filed a letter with the PUC requesting approval of an amendment to increase price and to change the guaranteed commercial operation date of a previously-approved PPA for Stage 2 on Oahu. The two GSPAs were approved by the PUC in December 2020. The two utility Self-Build projects are still pending PUC approval.

A summary of the remaining four approved Stage 2 PPAs, is as follows:

Utilities	Number of contracts		Total photovoltaic size (MW)	BESS Size (MW/MWh)			Guaranteed commercial operation dates	Contract term (years)	Total projected annual payment (in millions)
Hawaiian Electric	3		79	79	/	443	5/17/23, 10/30/23**, & 4/9/2024	20 & 25	$	28.8
Hawaiian Electric	1	*	N/A	185	/	565	12/30/2022***	20	24.0
Total	4		79	264	/	1,008			$	52.8

* See further discussion under “Review of Interconnection Process and Kapolei Energy Storage Power Purchase Agreement” below.

** Dates would change upon PUC approval of a PPA amendment.

*** Project delays have resulted in Guaranteed Commercial Operations Date being missed.

The total projected annual payment of $52.8 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:

Utilities	Fast Frequency Response - 1 (MW)	Fast Frequency Response - 2 (MW)	Capacity - Load Build (MW)	Capacity - Load Reduction (MW)
Hawaiian Electric	—	26.7	14.5	19.4
Hawaii Electric Light	6.0	—	3.2	4.0
Maui Electric	6.1	—	1.9	4.7
Total	12.1	26.7	19.6	28.1

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A summary of the utility self-build projects that are pending PUC approval is as follows:

Utilities	Number of contracts		BESS Size (MW/MWh)	Guaranteed commercial operation dates
Hawaii Electric Light	1	*	12/12	12/30/22
Maui Electric	1		40/160	4/28/23
Total	2		52/172

* The Utility Self-Build project was denied by the PUC on May 25, 2022 and the Utilities have filed a motion for reconsideration with the PUC.

Tariffed renewable resources.

•As of March 31, 2023, there were approximately 580 MW, 127 MW and 140 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 March 31, 2023, an estimated 37% of single family homes on the islands of Oahu, Hawaii and Maui have installed private rooftop solar systems, and approximately 21% of the Utilities’ total customers have solar systems.   

•The Utilities began accepting energy from feed-in tariff projects in 2011. As of March 31, 2023, there were 44 MW, 2 MW and 6 MW of installed feed-in tariff capacity from renewable energy technologies at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively.

Biofuel sources.

•On June 30, 2021, the Utilities issued an RFP for all fuels, including biodiesel, for supply commencing January 1, 2023. The Utilities and Pacific Biodiesel Technologies, LLC (PBT) signed an agreement on December 13, 2021 for supply of biodiesel on all islands commencing January 1, 2023, which was approved by the PUC on December 1, 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 2024.

•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 2024, and will continue with no volume purchase requirements.

Requests for renewable proposals, expressions of interest, and information.

•On November 22, 2021, CBRE RFPs for Molokai and Lanai were opened. The RFP for Lanai sought a single PV paired with storage project, which included a 3 MW portion, reserved for CBRE. The Lanai RFP closed on February 14, 2022 and the Molokai RFP closed on March 1, 2022. A project was selected in the Lanai RFP but negotiations were terminated. On July 1, 2022, a replacement project was selected and negotiations commenced. The RFP for Molokai sought 2.75 MW of new PV paired with storage projects for CBRE generation. No projects were selected in the Molokai RFP. However, with the concurrence of the independent observer, the Utilities are working with the lone bidder outside of the RFP process.

•On March 17, 2022, the CBRE LMI RFPs for Oahu, Maui and Hawaii were opened and proposals were received, In November 2022, seven projects were selected consisting of one standalone PV project on Oahu, three paired PV with storage projects on Maui, and three paired PV with storage projects on Hawaii Island. The Utilities opened the CBRE Tranche 1 RFPs for Oahu, Maui and Hawaii on April 14, 2022. In March 2023, five projects were selected consisting of one paired PV with storage project on Oahu and four standalone PV projects on Hawaii Island. See “Transition to a decarbonized and sustainable energy future—Community-based renewable energy” for additional information.

•On January 21, 2021, the PUC requested the Stage 3 RFP be launched for Hawaii island, and the Utilities filed the draft RFP, including model contracts for PV+BESS, wind+BESS, standalone storage, firm renewable generation, and DER aggregators on October 15, 2021. The RFP scope was guided by the results of the Grid Needs Assessment. The final Stage 3 RFP, seeking 325 GWh per year of energy and 65 MW of renewable firm capacity, was filed on November 7, 2022 and was issued on November 21, 2022. Proposals were received on April 20, 2023. The PUC also directed the Utilities to develop Stage 3 RFPs for Oahu and Maui. For Oahu, the Utilities are seeking 500 to 700 MW of renewable firm capacity, and at least 965 GWh of renewable dispatchable energy annually. For Maui, the Utilities are procuring at least 40 MW of renewable firm capacity, and at least 425 GWh of renewable dispatchable energy annually. The Stage 3 RFPs for Oahu and Maui opened for bids on January 20, 2023. On March 15, 2023, the PUC denied the Utility’s request to not advance its own proposal to meet the Maui firm capacity need as required under the

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Framework for Competitive Bidding, and on April 5, 2023, denied the Utility’s motion to modify the Maui RFP to allow a self-build, ordering the Utility to submit a proposal for the firm capacity need, or in the alternative, file a request to suspend the firm generation portion of the Maui RFP to make adjustments as ordered by the PUC, including an extension of the bidding period for firm generation proposals. The Utility filed its request on April 12, 2023, which the PUC granted on April 14, 2023. The updated Maui RFP was filed on April 27, 2023. Proposals for the Oahu RFP and the variable generation portion of the Maui RFP were received on April 20, 2023. The Utility submitted a proposal that is consistent with the reliability requirements under the competitive bidding framework as directed by the PUC. Best and final offers for the Oahu RFP and the variable generation portion of the Maui RFP are due on July 14, 2023 and final award selection is in October 2023, with negotiations of the PPAs expected to be completed in the later part of 2024.

•On November 17, 2021, the Utilities filed a request with the PUC to develop an RFP for firm renewable generation for Oahu. On December 22, 2021, the PUC issued guidance to the Utilities on proceeding with such RFP. The Utilities filed a draft RFP on February 28, 2022. Per the PUC’s March 23, 2022 letter, the Utilities will pursue firm renewable generation as a part of the Stage 3 Oahu RFP.

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 GCODs 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 Utilities report the tracked cost on a monthly basis. The full text of the Order, Motion for Reconsideration and request for a Stay of the Order, and clarification Order as well as the tracked costs can be found on the PUC website at dms.puc.hawaii.gov/dms (Docket No. 2021-0024).

•During the 2022 Legislative Session, the Hawaii State Legislature passed Senate Bill 2474 SD 2 HD 1 CD 1, which was signed into law on June 27, 2022 as Act 201. The law requires that the PUC contract with a qualified consultant to conduct a study on the accessibility of Hawaii’s electric system and procedures for interconnection to Hawaii’s electric system, including but not limited to the timeliness and costs of interconnection. The PUC contracted with PA Consulting to conduct the study as well as act as the Independent Engineer for the Stage 3 Request for Proposal procurement. The report was submitted to the PUC on December 28, 2022 and did not find any wrongdoing on the part of the utility. The report made minor recommendations for Hawaiian Electric to review interconnection related tariff/rules and revise, if necessary, to provide technical clarity in terms of interconnection requirements, to establish a database for the purpose of centralizing all information related to all interconnection projects they manage, including their self-build and IPP-built projects, and to develop comparable interconnection cost metrics for self-build and IPP-built projects so that interconnection costs can be directly compared. The PUC stated its intent to address the recommendations that are directed to Hawaiian Electric through various proceedings related to the interconnection process. Hawaiian Electric will be working on these recommendations. The contracted consultant is also planning a second phase of the study, to be completed in 2023, which will include the assessment and recommendation of remaining issues listed in Act 201 that are not covered in Phase 1.

•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

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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).

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. On June 30, 2021, the Utilities issued two RFPs for all fuels for supply commencing January 1, 2023. On February 1, 2022, the Utilities and PAR Hawaii Refining, LLC (PAR Hawaii) entered into a fuel supply contract commencing January 1, 2023. On December 1, 2022, the PUC issued a decision and order (D&O) approving the PAR Hawaii fuels contract and recovery of associated costs through ECRC.

On March 3, 2022, as part of economic sanctions amid the Russia-Ukraine war, PAR Hawaii announced that it is suspending all purchases of Russian crude oil, which accounts for at least 25% of Hawaii’s supply. The average fuel oil cost per barrel has increased 35% over the same quarter in prior year. The Utilities are taking additional measure to ensure adequate supply of fuel by entering into a backup fuel supply contract with Vitol Inc. (Vitol) commencing on December 1, 2022 through June 30, 2023 with annual extensions if mutually agreed by both parties. The PUC issued the final D&O approving the Vitol backup fuels supply contract on December 1, 2022 and the costs incurred under the contract with Vitol are recovered in the Utilities’ respective ECRCs.

FINANCIAL CONDITION

Liquidity and capital resources. As of March 31, 2023, Hawaiian Electric had no commercial paper outstanding, no amount outstanding on its revolving credit facility and the total amount of available borrowing capacity under the Utilities’ committed line of credit was $200 million.

Hawaiian Electric expects that its liquidity will continue to be moderately impacted at the Utilities due to higher fuel prices and lingering COVID-19 impacts to the local economy. Higher accounts receivable balances and bad debt expense may result in higher write-offs in the future. In addition to the cash flow impact from delayed collection of accounts receivable, lower kWh sales relative to the level of kWh sales approved in the last rate case generally result in delayed timing of cash flows, resulting in higher working capital requirements. However, the Utilities’ liquidity and access to capital remains adequate and is expected to remain adequate. As of March 31, 2023, the total amount of available borrowing capacity (net of commercial paper outstanding) under the Utilities’ committed lines of credit and cash and cash equivalents was approximately $316 million.

The Utilities are continuing the disconnection process on a tiered basis, expanding the targeted balances, which is expected to further reduce delinquent accounts receivable balances and accelerate cash collections.

Hawaiian Electric’s consolidated capital structure was as follows:

(dollars in millions)	March 31, 2023				December 31, 2022
Short-term borrowings, net	$	—	—	%	$	88	2	%
Long-term debt, net	1,834		43		1,685		41
Preferred stock	34		1		34		1
Common stock equity	2,359		56		2,344		56
	$	4,227	100	%	$	4,151	100	%

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Information about Hawaiian Electric’s commercial paper borrowings, borrowings from HEI and line of credit facility were as follows:

	Average balance		Balance
(in millions)	Three months ended March 31, 2023		March 31, 2023		December 31, 2022
Short-term borrowings1
Commercial paper	$	25	$	—	$	88
Borrowings from HEI	—		—		—
Line of credit draws on revolving credit facility	—		—		—

1   The maximum amount of external short-term borrowings by Hawaiian Electric during the first three months of 2023 was approximately $96 million. At March 31, 2023, Hawaiian Electric had no short-term borrowings from Hawaii Electric Light and Maui Electric.

Hawaiian Electric utilizes short-term debt, typically commercial paper, to support normal operations, to refinance short-term debt and for other temporary requirements. Hawaiian Electric also borrows short-term from HEI for itself and on behalf of Hawaii Electric Light and Maui Electric, and Hawaiian Electric may borrow from or loan to Hawaii Electric Light and Maui Electric on a short-term basis. The intercompany borrowings among the Utilities, but not the borrowings from HEI, are eliminated in the consolidation of Hawaiian Electric’s financial statements. The Utilities periodically utilize long-term debt, borrowings of the proceeds of special purpose revenue bonds (SPRBs) issued by the State of Hawaii Department of Budget and Finance (DBF) and the issuance of privately placed unsecured senior notes bearing taxable interest, to finance the Utilities’ capital improvement projects, or to repay short-term borrowings used to finance such projects. The PUC must approve issuances, if any, of equity and long-term debt securities by the Utilities.

Credit agreement. Hawaiian Electric has a $200 million line of credit facility with no amount outstanding at March 31, 2023. See Note 5 of the Condensed Consolidated Financial Statements for additional information.

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 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 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. On January 31, 2023, the PUC approved the Utilities’ requests to issue the remaining unused amounts of the SPRBs during the period January 1, 2023 through June 30, 2024, and the certification and approval of supplemental projects eligible to be financed by the SPRB proceeds.

Taxable debt. On December 20, 2022, the Utilities received PUC approval to issue, over a four-year period from January 1, 2023 to December 31, 2026, unsecured obligations bearing taxable interest (Hawaiian Electric up to $230 million, Hawaii Electric Light up to $65 million and Maui Electric up to $105 million), to finance capital expenditures, repay long-term and/or short-term debt used to finance or refinance capital expenditures, and/or to reimburse funds used for payment of capital expenditures. Pursuant to the approval, on January 10, 2023, the Utilities executed through a private placement, $150 million in unsecured senior notes (2023 Notes). The 2023 Notes had a delayed draw feature and the Utilities drew down all the proceeds on February 9, 2023. See Note 5 of the Condensed Consolidated Financial Statements for additional information and see summary table below for remaining authorized amounts.

(in millions)	Hawaiian Electric		Hawaii Electric Light		Maui Electric
Total “up to” amounts of taxable debt authorized from 2023 through 2026	$	230	$	65	$	105
Less:
Taxable debt executed in January 2023, but issued on February 9, 2023	100		25		25
Remaining authorized amounts	$	130	$	40	$	80

As of March 31, 2023, Hawaiian Electric, Hawaii Electric Light, and Maui Electric have $130 million, $40 million, and $80 million, respectively of remaining taxable debt authorization.

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Equity. On December 20, 2022, the Utilities received PUC approval to issue and sell each utility’s common stock over a four-year period from January 1, 2023 through December 31, 2026 (Hawaiian Electric’s sale/s to HEI of up to $75 million, Hawaii Electric Light sale/s to Hawaiian Electric of up to $25 million, and Maui Electric sale/s to Hawaiian Electric of up to $55 million) and the purchase of Hawaii Electric Light and Maui Electric common stock by Hawaiian Electric from 2023 through December 31, 2026. As of March 31, 2023, Hawaiian Electric, Hawaii Electric Light, and Maui Electric have $75 million, $25 million, and $55 million, respectively, of unused common stock authorization.

Cash flows. The following table reflects the changes in cash flows for the three months ended March 31, 2023 compared to the three months ended March 31, 2022:

	Three months ended March 31
(in thousands)	2023		2022		Change
Net cash provided by operating activities	$	169,355	$	76,775	$	92,580
Net cash used in investing activities	(120,594)		(74,864)		(45,730)
Net cash provided by financing activities	28,019		(25,974)		53,993

Net cash provided by operating activities. The increase in net cash provided by operating activities was primarily driven by higher cash receipts from large delinquent commercial customer accounts, receipts from customers associated with increased disconnection efforts, receipts of payments on installment plans, and receipt of government and other program assistance, partially offset by higher cash paid for accounts payable due to timing.

Net cash used in investing activities. The increase in net cash used in investing activities was primarily driven by a increase in capital expenditures related to construction activities.

Net cash provided by financing activities. The increase in net cash provided by financing activities was driven by higher proceeds from issuance of long-term debts, partially offset by repayment of short-term borrowings.

Material cash requirements. Material cash requirements of the Utilities include O&M expenses, including labor and benefit costs, fuel and purchase power costs, repayment of debt and interest payments, operating lease obligations, its forecasted capital expenditures and investments, its expected retirement benefit plan contributions and other short-term and long-term material cash requirements. The cash requirements for O&M, fuel and purchase power costs, debt and interest payments, and operating lease obligations are generally funded through the collection of the Utilities’ revenue requirement established in the last rate case and other mechanisms established under the regulatory framework. The cash requirements for capital expenditures are generally funded through retained earnings, the issuance of debt, and contributions of equity from HEI and generally recovered through the Utilities’ revenue requirement or other capital recovery mechanisms over time. The Utilities believe that their ability to generate cash is adequate to maintain sufficient liquidity to fund their material cash requirements. However, the economic impact of higher fuel prices, inflation, higher interest rates, tightening of monetary policy, the ongoing COVID-19 pandemic and geopolitical situations, create significant uncertainty, and the Utilities cannot predict the extent or duration of these conditions, 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.

Forecast capital expenditures. For the five-year period 2023 through 2027, the Utilities forecast approximately $2.2 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. Approximately $1.6 billion is related to replacement and modernization of generation, transmission and distribution assets; approximately $0.3 billion is related to climate-related projects to transition to renewable energy or mitigate climate impacts by increasing the resilience of the system, and approximately $0.3 billion for targeted efforts to improve reliability. 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 2023 to 2027 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. See also “Recent developments” in HEI’s MD&A.

The Hawaii economy continued to improve in the first quarter of 2023 as travel and other COVID-19 related business restrictions were lifted and visitor arrivals increased, which have helped drive a growing labor market and tax collections. Domestic visitor arrivals exceeded pre-pandemic levels in 2022 and continued to improve into 2023 due to pent up demand from leisure travelers. The state and county governments have also lifted all COVID-related travel restrictions for arriving domestic passengers. International visitor arrivals continued to lag significantly behind pre-pandemic levels but have gradually increased as certain Asian countries began loosening travel restrictions. COVID cases caused by the new variants remain relatively stable at low levels along with hospitalization rates.

As of May 3, 2023, the Federal Reserve raised the federal funds rate to a current target range of 5.00%-5.25% in response to continued inflationary pressures in the economy. The increase in interest rates has been neutral to ASB’s net interest margin as higher yield on earning assets were offset by an increase in yields on deposits and other borrowings. The higher interest rates have also reduced mortgage refinance and purchase activity, negatively impacting mortgage banking income. Additionally, the tight labor market and inflationary pressures have increased compensation and benefit expenses, which have partially offset the benefit of a higher interest rate environment.

ASB experienced continued loan growth in 2023 as total loans increased $83 million compared to 2022 total loans. There was demand for commercial real estate, commercial, home equity line of credit and consumer loan products. The consumer loan portfolio growth also included purchases of solar and sustainable home improvement loans from a third party.

Deposit growth, which had previously funded loan growth and investment security purchases, has slowed and required ASB to increase its other borrowings to fund the loan portfolio growth, thereby increasing the Bank’s funding costs and reducing its balance sheet sensitivity. Additional federal funds rate increases may not further increase the Bank’s net interest margin if core deposit growth ceases and funding is replaced with other borrowings.

For the quarter ended March 31, 2023, ASB recorded a $1.2 million provision for credit losses, primarily driven by additional reserves required for loan portfolio growth, partly offset by the release of reserves for lower loss rates due to improved credit quality. The provision for credit losses in future quarters will be dependent on future economic conditions and changes to borrower credit quality at that time.

At March 31, 2023, the investment securities portfolio balance decreased approximately $23 million, as slowing deposit growth resulted in lower excess liquidity and the need for other sources to fund the loan growth. Investment securities portfolio repayments were used as a funding source for the loan growth and ASB did not purchase any investment securities. The change in interest rates in the first quarter of 2023 resulted in lower unrealized losses in the available-for-sale investment securities portfolio which increased the investment portfolio balance.

In the first quarter of 2023, the increase in interest rates and the collapse of a few financial institutions had caused turmoil in the banking industry. Due to the failure of these financial institutions, the focus on the banking industry has been around capital levels, uninsured deposits and liquidity. ASB’s regulatory capital ratios are above the “well-capitalized” and regulatory requirements including the conservation buffers. Approximately 85% of the Bank’s deposits are fully insured by the Federal Deposit Insurance Corporation. ASB has access to approximately $3 billion in funding sources to meet its liquidity needs.

ASB continues to maintain its low-risk profile, strong balance sheet and straightforward community banking business model.

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	Three months ended March 31				Increase
(in millions)	2023		2022		(decrease)		Primary reason(s)
Interest and dividend income	$	79	$	60	$	19
							Average loan portfolio yields were 76 basis points higher—loan yields continued to increase in 2023 due to the interest rate environment as adjustable rate loan yields repriced with rising interest rates and new loan production yields were higher than the portfolio rates.
							Average loan portfolio balances increased $841 million - commercial real estate, home equity line of credit and commercial loan portfolio average balances increased $321 million, $180 million and $23 million, respectively, due to demand for these loan types. Residential loan portfolio average balances increased $186 million due to the Bank’s decision to portfolio a larger portion of the residential loan production. Consumer loan portfolio average balances increased $131 million primarily due to the purchase of solar and sustainable home improvement loans.
							Average investment securities portfolio balances decreased $91 million—repayments in the investment securities portfolio were used to fund the loan portfolio growth.
							Average investment securities portfolio yields were 9 basis points higher—benefited from lower amortization of premiums in the investment portfolio.
Noninterest income	14		16		(2)
							Lower mortgage banking income - lower residential loan sale volume due to lower production volume as the higher interest rate environment has reduced the demand for residential mortgage loans. ASB’s decision to portfolio a larger portion of the residential loan production also reduced the amount of loans sold on the secondary market.
							Lower gain on sale of real estate - due to the sale of a branch property owned by ASB. The branch was closed in January 2022. No similar sale in 2023.
Less: gain on sale of real estate	—		(1)		1		Gain on sale of real estate, 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 real estate in the condensed consolidated statements of income, and accordingly, is reflected in operating expenses below as a separate line item and excluded from Revenues.
Revenues	93		75		18		The increase in revenues for the three months ended March 31, 2023 compared to the same period in 2022 was primarily due to higher interest and dividend income partly offset by lower noninterest income.
Interest expense	15		1		14
							Interest expense on deposits and other borrowings increased in 2023 compared to 2022 due to an increase in balances and yields of other borrowings and term certificates.
							Average core deposit balances decreased $351 million; average term certificate balances increased $328 million.
							Average deposit yields increased from 5 basis points to 34 basis points. The increase was primarily due to the increase in term certificate yields of 233 basis points and the shift in mix of deposits from low cost core deposits to term certificates.
							Average other borrowings increased $625 million and average yields increased 431 basis points. Other borrowings were used to fund the growth in the loan portfolio. The higher yields was reflective of the higher interest rate environment.
Provision for credit losses	1		(3)		4
							2023 provision for credit losses was due primarily for the growth in the loan portfolio.
							2023 provision for credit losses also included the release of credit loss reserves for improved credit loss rates as a result of improved economic outlook and good credit trends.
							2022 negative provision for credit losses reflected a stable economic outlook, good credit trends including lower net charge-offs and improved credit loss rates which included credit upgrades in the commercial real estate loan portfolio.
							2022 negative provision for credit losses was also due to the release of credit loss reserves for a commercial real estate credit.
							Delinquency rates have decreased—from 0.27% at March 31, 2022 to 0.22% at March 31, 2023 due to lower residential 1-4 family loan delinquencies.
							Net charge-off to average loans have increased—from 0.01% at March 31, 2022 to 0.14% at March 31, 2023 primarily due to higher consumer loan portfolio net charge-offs and the charge-off of a residential loan.

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	Three months ended March 31		Increase
(in millions)	2023	2022	(decrease)	Primary reason(s)
Noninterest expense	54	48	6
				Higher compensation and benefits expenses and deposit account expenses.
				Higher base compensation and employee benefit costs were due to merit increases, market adjustments and higher performance-based compensation.
Gain on sale of real estate	—	(1)	1
Expenses	70	45	25	The increase in expenses for the three months ended March 31, 2023 compared to the same period in 2022 was due to higher interest expenses, higher provision for credit losses and higher noninterest expense partly offset by higher gain on sale of real estate in 2022.
Operating income	23	30	(7)	The decrease in operating income for the three months ended March 31, 2023 compared to the same period in 2022 was primarily due to higher interest expenses, higher noninterest expenses, higher provision for credit losses and lower noninterest income, partly offset by higher interest income.
Net income	19	24	(5)	Net income for the three months ended March 31, 2023 was lower than the same period in 2022 due to lower operating income and lower gain on sale of real estate, partly offset by lower income tax expense.

ASB’s return on average assets, return on average equity and net interest margin were as follows:

	Three months ended March 31
(%)	2023	2022
Return on average assets	0.78	1.04
Return on average equity	15.51	13.70
Net interest margin	2.85	2.79

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	Three months ended March 31
	2023					2022
(dollars in thousands)	Average balance		Interest income/ expense		Yield/ rate (%)	Average balance		Interest  income/ expense		Yield/ rate (%)
Assets:
Interest-earning deposits	$	10,213	$	121	4.76	$	134,835	$	66	0.20
FHLB stock	30,089		426		5.74	10,000		74		3.00
Investment securities
Taxable	3,042,254		13,696		1.80	3,131,482		13,554		1.73
Non-taxable	68,278		498		2.92	69,600		367		2.11
Total investment securities	3,110,532		14,194		1.83	3,201,082		13,921		1.74
Loans
Residential 1-4 family	2,489,203		22,615		3.63	2,303,446		20,113		3.49
Commercial real estate	1,458,452		17,247		4.74	1,137,295		9,211		3.25
Home equity line of credit	1,021,294		9,028		3.59	840,974		6,223		3.00
Residential land	20,296		277		5.45	20,822		257		4.93
Commercial	784,733		10,397		5.33	761,525		6,812		3.60
Consumer	245,245		5,393		8.89	113,826		3,459		12.33
Total loans 1,2	6,019,223		64,957		4.34	5,177,888		46,075		3.58
Total interest-earning assets 3	9,170,057		79,698		3.49	8,523,805		60,136		2.83
Allowance for credit losses	(72,113)					(71,135)
Noninterest-earning assets	466,289					709,010
Total assets	$	9,564,233				$	9,161,680
Liabilities and shareholder’s equity:
Savings	$	3,143,103	$	222	0.03	$	3,258,551	$	207	0.03
Interest-bearing checking	1,332,214		630		0.19	1,331,008		64		0.02
Money market	197,026		586		1.21	205,363		33		0.07
Time certificates	739,683		5,399		2.96	411,372		643		0.63
Total interest-bearing deposits	5,412,026		6,837		0.51	5,206,294		947		0.07
Advances from Federal Home Loan Bank	502,222		5,870		4.68	—		—		—
Borrowings from Federal Reserve Bank	66,722		719		4.37	—		—		—
Securities sold under agreements to repurchase	146,368		1,132		3.14	90,279		5		0.02
Total interest-bearing liabilities	6,127,338		14,558		0.96	5,296,573		952		0.07
Noninterest bearing liabilities:
Deposits	2,745,317					2,973,597
Other	213,019					194,449
Shareholder’s equity	478,559					697,061
Total liabilities and shareholder’s equity	$	9,564,233				$	9,161,680
Net interest income			$	65,140				$	59,184
Net interest margin (%) 4					2.85					2.79

1   Includes loans held for sale, at lower of cost or fair value.

2   Includes recognition of net deferred loan fees of $0.8 million and $1.9 million for the three months ended March 31, 2023 and 2022, respectively, together with interest accrued prior to suspension of interest accrual on nonaccrual loans. Includes nonaccrual loans.

3   For the three months ended March 31, 2023 and 2022, the taxable-equivalent basis adjustments made to the table above were not material.

4   Defined as net interest income, on a fully taxable equivalent basis, as a percentage of average total interest-earning assets.

Earning assets, costing liabilities, contingencies and other factors.  Earnings of ASB depend primarily on net interest income, which is the difference between interest earned on earning assets and interest paid on costing liabilities. The interest rate environment has been impacted by disruptions in the financial markets over a period of several years. The Federal Open Market Committee increased its federal funds rate target range to 4.25% - 4.50% in 2022 to combat signs of inflation. ASB’s

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net interest income and net interest margin has started to increase but still remains at lower levels. A return to the recent low interest rate environment may 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 a composition of ASB’s loan portfolio.

Home equity — key credit statistics. The home equity line of credit (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 March 31, 2023, approximately 39% 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 56% of ASB’s HELOC loan portfolio is in a first lien position.

Loan portfolio risk elements.  See Note 4 of the Condensed Consolidated Financial Statements.

Investment securities.  ASB’s investment portfolio was comprised as follows:

	March 31, 2023				December 31, 2022
(dollars in thousands)	Balance		% of total		Balance		% of total
U.S. Treasury and federal agency obligations	$	139,644	5	%	$	140,957	5	%
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	2,462,220		92		2,484,821		92
Corporate bonds	41,310		2		40,734		2
Mortgage revenue bonds	14,766		1		14,902		1
Total investment securities	$	2,657,940	100	%	$	2,681,414	100	%

ASB continues to invest in high-grade investment securities. 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.

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. In 2023, deposits increased by $60.9 million, as an outflow of core deposits was replaced with time certificates. Core deposit retention and sustained growth will remain challenging in the current rising interest rate environment. Advances from the FHLB of Des Moines, securities sold under agreements to repurchase, borrowings from the Federal Reserve Bank and federal funds purchased continue to be additional sources of funds. As of March 31, 2023 and December 31, 2022, ASB’s costing liabilities consisted of 92% deposits and 8% borrowings. The weighted average cost of deposits for the first three months of 2023 and 2022 was 0.34% and 0.05%, respectively. As of March 31, 2023 and December 31, 2022, ASB had approximately $1.2 billion of deposits that were uninsured.

Federal Home Loan Bank of Des Moines and Federal Reserve Bank. As of March 31, 2023 and December 31, 2022, ASB had nil and $414 million of advances outstanding at the FHLB of Des Moines, respectively. As of March 31, 2023, the unused borrowing capacity with the FHLB of Des Moines was $2.0 billion. As of March 31, 2023 and December 31, 2022, ASB had $550 million and nil borrowings from the Federal Reserve Bank, respectively. The FHLB of Des Moines and Federal Reserve Bank are important sources 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.

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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 March 31, 2023, ASB had an unrealized loss, net of taxes, on available-for-sale investment securities (including securities pledged for repurchase agreements) in AOCI of $308.6 million compared to an unrealized loss, net of taxes, of $328.9 million as of December 31, 2022. The unrealized losses were due to changes in interest rates and did not affect regulatory capital ratios. See “Item 3. Quantitative and qualitative disclosures about market risk” for a discussion of ASB’s interest rate risk sensitivity.

During the first three months of 2023, ASB recorded a provision for credit losses of $1.2 million in the allowance for credit losses for growth in the loan portfolio partly offset by the release of credit loss reserves for improved credit trends and lower credit loss rates. During the first three months of 2022, ASB recorded a negative provision for credit losses of $3.8 million in the allowance for credit losses reflecting a stable economic outlook, good credit trends including lower net charge-offs and credit upgrades in the commercial real estate loan portfolio, and the release of reserves for a nonperforming commercial real estate loan.

	Three months ended March 31						Year ended December 31, 2022
(in thousands)	2023			2022
Allowance for credit losses, beginning of period	$	72,216		$	71,130		$	71,130
Provision for credit losses	1,175			(3,763)			2,537
Less: net charge-offs	2,095			156			1,451
Allowance for credit losses, end of period	$	71,296		$	67,211		$	72,216
Ratio of net charge-offs during the period to average loans outstanding (annualized)	0.14		%	0.01		%	0.03		%

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 three months ended March 31, 2023 and 2022, ASB recorded a provision for credit losses for unfunded commitments of nil and $0.5 million, respectively. As of March 31, 2023 and December 31, 2022, the reserve for unfunded loan commitments was $4.4 million.

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.”

FINANCIAL CONDITION

Liquidity and capital resources.

(dollars in millions)	March 31, 2023		December 31, 2022		% change
Total assets	$	9,610	$	9,546	1
Investment securities	2,658		2,681		(1)
Loans held for investment, net	5,988		5,907		1
Deposit liabilities	8,231		8,170		1
Other bank borrowings	681		695		(2)

As of March 31, 2023, ASB was one of Hawaii’s largest financial institutions based on assets of $9.6 billion and deposits of $8.2 billion.

As of March 31, 2023, ASB’s unused FHLB borrowing capacity was approximately $2.0 billion. As of March 31, 2023, 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 three months ended March 31, 2023, net cash provided by ASB’s operating activities was $15 million. Net cash used during the same period by ASB’s investing activities was $16 million, primarily due to a net increase in loans receivable of $69 million, purchases of loans held for investment of $13 million and additions to premises and equipment of $1 million, partly offset by the receipt of investment security repayments and maturities of $50 million and a net decrease in FHLB stock of

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$17 million. Net cash provided by financing activities during this period was $28 million, primarily due to increases in deposit liabilities of $61 million partly offset by a net decrease in other borrowings of $14 million, a net decrease in mortgage escrow deposits of $4 million and $14 million in common stock dividends to HEI (through ASB Hawaii).

For the three months ended March 31, 2022, net cash provided by ASB’s operating activities was $24 million. Net cash used during the same period by ASB’s investing activities was $152 million, primarily due to purchases of available-for-sale securities of $291 million and additions to premises and equipment of $1 million, partly offset by the receipt of investment security repayments and maturities of $109 million, a net decrease in loans of $28 million, proceeds from redemption of bank owned life insurance of $2 million and proceeds from the sale of real estate of $1 million. Net cash provided by financing activities during this period was $147 million, primarily due to increases in deposit liabilities of $117 million and a net increase in repurchase agreements of $49 million, partly offset by a net decrease in mortgage escrow deposits of $4 million and $15 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 March 31, 2023, ASB was well-capitalized (well-capitalized ratio requirements noted in parentheses) with a Tier-1 leverage ratio of 7.7% (5.0%), common equity Tier-1 ratio of 12.0% (6.5%), Tier-1 capital ratio of 12.0% (8.0%) and total capital ratio of 13.1% (10.0%). As of December 31, 2022, ASB was well-capitalized (well-capitalized ratio requirements noted in parentheses) with a Tier-1 leverage ratio of 7.8% (5.0%), common equity Tier-1 ratio of 12.2% (6.5%), Tier-1 capital ratio of 12.2% (8.0%) and total capital ratio of 13.1% (10.0%). All dividends are subject to review by the OCC and FRB and receipt of a letter from the FRB communicating the agencies’ non-objection to the payment of any dividend ASB proposes to declare and pay to HEI (through ASB Hawaii).

Item 3. Quantitative and Qualitative Disclosures About Market Risk

The Company considers interest-rate risk (a non-trading market risk) to be a significant market risk for ASB as it could potentially have material impacts on the Company’s results of operations, financial condition and liquidity. For additional quantitative and qualitative information about the Company’s market risks, see HEI’s and Hawaiian Electric’s Quantitative and Qualitative Disclosures About Market Risk in Part II, Item 7A of HEI’s 2022 Form 10-K (pages 78 to 80).

ASB’s interest-rate risk sensitivity measures as of March 31, 2023 and December 31, 2022 constitute “forward-looking statements” and were as follows:

Change in interest rates	Change in NII (gradual change in interest rates)				Change in EVE (instantaneous change in interest rates)
(basis points)	March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
+300	2.2	%	(0.1	%)	6.2	%	5.1	%
+200	1.5		—		4.8		3.8
+100	0.8		—		3.0		2.1
-100	(0.9)		(0.3)		(3.6)		(3.4)
-200	(1.4)		(0.9)		(8.0)		(7.8)
-300	(2.1)		(1.7)		(14.6)		(13.8)

ASB’s net interest income (NII) sensitivity profile was more asset sensitive as of March 31, 2023 compared to December 31, 2022, primarily driven by a shift in the bank’s liability mix as Federal Reserve Bank borrowings replaced short-term FHLB borrowings which increased NII sensitivity.

Economic value of equity (EVE) sensitivity increased as of March 31, 2023 compared to December 31, 2022 as the duration of liabilities lengthened. The further inversion of the yield curves lengthened the duration of core deposits. In addition, the bank’s liability mix shifted as Federal Reserve Bank borrowings replaced short-term FHLB borrowings which increased EVE sensitivity.

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

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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.

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 first quarter of 2023 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 first quarter of 2023 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 2022 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 20 to 33 of HEI’s and Hawaiian Electric’s 2022 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 first quarter of 2023 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
January 1 to 31, 2023	14,443	$41.78	—	NA
February 1 to 28, 2023	13,325	$42.18	—	NA
March 1 to 31, 2023	190,234	$38.83	—	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,” 8,207 of the 14,443 shares, 5,338 of the 13,325 shares and 162,977 of the 190,234 shares were purchased for the DRIP; 4,991 of the 14,443 shares, 5,722 of the 13,325, shares and 22,321 of the 190,234 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

 

HEI Exhibit 4	Hawaiian Electric Industries Retirement Savings Plan, restatement effective October 6, 2022.
HEI Exhibit 31.1	Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Scott W. H. Seu (HEI Chief Executive Officer)
HEI Exhibit 31.2	Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Paul K. Ito (HEI Chief Financial Officer)
HEI Exhibit 32.1	HEI Certification Pursuant to 18 U.S.C. Section 1350
HEI Exhibit 101.INS	XBRL 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.SCH	Inline XBRL Taxonomy Extension Schema Document
HEI Exhibit 101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase Document
HEI Exhibit 101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase Document
HEI Exhibit 101.LAB	Inline XBRL Taxonomy Extension Label Linkbase Document
HEI Exhibit 101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase Document
HEI Exhibit 104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
Hawaiian Electric Exhibit 31.3	Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Shelee M. T. Kimura (Hawaiian Electric Chief Executive Officer)
Hawaiian Electric Exhibit 31.4	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 Exhibit 32.2	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/ Scott W. H. Seu	By	/s/ Shelee M. T. Kimura
	Scott W. H. Seu		Shelee M. T. Kimura
	President and Chief Executive Officer		President and Chief Executive Officer
	(Principal Executive Officer of HEI)		(Principal Executive Officer of Hawaiian Electric)
By	/s/ Paul K. Ito	By	/s/ Tayne S. Y. Sekimura
	Paul K. Ito		Tayne S. Y. Sekimura
	Executive Vice President,		Senior Vice President,
	Chief Financial Officer and Treasurer		Chief Financial Officer and Treasurer
	(Principal Financial Officer of HEI)		(Principal Financial Officer of Hawaiian Electric)
Date: May 9, 2023		Date: May 9, 2023

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EX-4

HEI Exhibit 4

HAWAIIAN ELECTRIC INDUSTRIES RETIREMENT SAVINGS PLAN

(Restatement effective October 6, 2022)

Table of Contents

PAGE

INTRODUCTION	1
DEFINITIONS	2
ARTICLE I PARTICIPATION	2
Section 1.1Eligibility to Participate	2
Section 1.1.A Eligibility Rules for “Regular Part-time Under Twenty (20) Hours Non-Bargaining Unit Employees”	2
Section 1.2Reemployment	5
Section 1.3Duration of Participation	5
ARTICLE II CONTRIBUTIONS	6
Section 2.1Salary Reduction Contributions	6
Section 2.2Eligible Automatic Contribution Arrangement	8
Section 2.3Roth Salary Reduction Contributions	11
Section 2.4 Matching Contributions for Participants First Employed by a Participating Employer After April 30, 2011 and Before January 1, 2022 (or Deemed To Be New Employees After April 30, 2011 and Before January 1, 2022, Under Section 1.2 of the HEI Retirement Plan)	13
Section 2.5Non-Elective Contributions for Participants First Employed by a Participating Employer After December 31, 2021 (or Deemed To Be New Employees After December 31, 2021, Under Section 1.2 of the HEI Retirement Plan)	14
Section 2.6Return of Contributions	14
Section 2.7Rollover Contributions	15
Section 2.8USERRA Rights of Participants Returning from Qualified Military Service	16
Section 2.9Qualified Nonelective Contributions	16
ARTICLE III NONDISCRIMINATION RULES; LIMITATIONS ON CONTRIBUTIONS	18
Section 3.1Section 401(k) Nondiscrimination Rules	18
Section 3.2 Maximum Elective Deferrals	21
Section 3.3Section 401(m) Nondiscrimination Rules	23
Section 3.4 Section 415 Limitations	25

i

Table of Contents

PAGE

Section 3.5 Forfeiture of Matching Contributions	26
ARTICLE IV ACCOUNTING AND INVESTMENTS	28
Section 4.1 Assets To Be Held by Trustee	28
Section 4.2 Accounting and Expenses	28
Section 4.3 Investment of Accounts	30
Section 4.4 General Investment Powers of the PIC	34
Section 4.5 Plan Loans to Active Participants	35
ARTICLE V VESTING AND FORFEITURES	39
Section 5.1Vesting	39
Section 5.2Forfeitures	41
ARTICLE VI PAYMENT OF VESTED BENEFITS	43
Section 6.1 Severance from Employment	43
Section 6.2 Small Account Balances	43
Section 6.3 Statutory Commencement Date	43
Section 6.4 Forms of Benefit Following Severance from Employment	43
Section 6.5 Installment Option for HEISOP Subaccounts	44
Section 6.6 Periodic Payments of Minimum Distributions	45
Section 6.7 Death Benefits	45
Section 6.8Required Minimum Distributions	46
Section 6.9In-Service Withdrawals	51
Section 6.10 Qualified Domestic Relations Orders	53
Section 6.11 Eligible Rollover Distributions	54
Section 6.11.A Roth In-Plan Conversions	57
Section 6.12 Special Rules for Participants Called to Military Service	57
ARTICLE VII ADMINISTRATION	59

ii

Table of Contents

PAGE

Section 7.1 PIC, Administrative Committee, and Investment Committee	59
Section 7.2 Plan Administrator	60
Section 7.3 Trust Agreement	61
Section 7.4 Bonding	61
Section 7.5 Indemnification	61
ARTICLE VIII CLAIMS PROCEDURES	62
Section 8.1 Claims for Benefits	62
Section 8.2 Appeal	62
Section 8.3 Other Remedies	63
ARTICLE IX AMENDMENT, TERMINATION, AND MERGER	64
Section 9.1 Amendment	64
Section 9.2 Termination or Discontinuance	64
Section 9.3 Merger or Spinoff	64
ARTICLE X MISCELLANEOUS	66
Section 10.1No Right to Employment	66
Section 10.2 Inalienability	66
Section 10.3 Facility of Payment	66
Section 10.4 Construction of Plan	66
Section 10.5 Benefits Payable From Trust	67
ARTICLE XI TOP-HEAVY RULES	68
Section 11.1 Determination of Top-Heavy Status	68
Section 11.2Special Top-Heavy Rules	70
ARTICLE XII DEFINITIONS	72
ARTICLE XIII EXECUTION	78

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INTRODUCTION

Hawaiian Electric Industries, Inc. (the “Company”) established the Hawaiian Electric Industries Retirement Savings Plan (the “Plan”) effective April 1, 1984, to enable the eligible employees of the Company and its participating subsidiaries to save for retirement on a tax-deferred basis.

The Plan document was restated effective January 1, 2008. On June 16, 2011, the Internal Revenue Service issued a favorable determination letter with respect to the 2008 Plan restatement.

The Plan was again restated, effective May 1, 2011, to (a) add a matching contribution and associated vesting schedule for participants who are first employed by a participating employer after April 30, 2011 (or who are deemed to be new employees after April 30, 2011, under Section 1.2 of the Retirement Plan for Employees of Hawaiian Electric Industries, Inc. and Participating Subsidiaries); and (b) designate Hawaiian Electric Industries, Inc., the corporate entity, as the Plan “Administrator,” as defined in the Employee Retirement Income Security Act of 1974, as amended.

The Plan was again restated, effective January 1, 2013, to incorporate all amendments required by the 2011 Cumulative List of Changes in Plan Qualification Requirements, including amendments required to comply with the Pension Protection Act of 2006, the Heroes Earnings Assistance and Relief Tax Act of 2008 (the “HEART Act”), and the Worker, Retiree, and Employer Recovery Act of 2008 (“WRERA”).

This restatement, which is effective October 6, 2022, incorporates all prior amendments, including to add a non-elective contribution and associated vesting schedule participants who are first employed by a participating employer after December 31, 2021 (or who are deemed to be new employees after December 31, 2021, under Section 1.2 of the Retirement Plan for Employees of Hawaiian Electric Industries, Inc. and Participating Subsidiaries).

The Plan is an individually designed, single-employer defined contribution retirement plan that covers both bargaining unit and non-bargaining unit employees. The Plan is intended to meet the tax-qualification requirements in Sections 401(a) and 401(k) of the Internal Revenue Code. The Plan is a remedial amendment Cycle B plan.

A participant’s benefits and rights under the Plan shall be determined in accordance with the terms of the Plan in effect on the date the participant terminates employment and shall not be affected by any subsequent amendment to the Plan, unless, and only to the extent, specifically provided for in such amendment or otherwise required by law.

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DEFINITIONS

Capitalized terms used in this document are defined in Article XII.

ARTICLE I
PARTICIPATION

Section 1.1        Eligibility to Participate

(a)Non-Bargaining Unit Employees.

A non-bargaining unit Eligible Employee shall become eligible to participate as of the date he or she first performs one (1) Hour of Service for a Participating Employer.

(b)Bargaining Unit Employees.

An Eligible Employee whose employment with a Participating Employer is governed by a collective bargaining agreement shall become eligible to participate as of the date he or she first (1st) performs one (1) Hour of Service as a “regular” bargaining unit Eligible Employee. “Regular” employment is defined by reference to the governing collective bargaining agreement.

Section 1.1.A     Eligibility Rules for “Regular Part-time Under Twenty (20) Hours Non-Bargaining Unit Employees”

(a)General Rule.

An Eligible Employee who is classified by a Participating Employer as a “regular part-time under twenty (20) hours non-bargaining unit employee” shall become eligible for either the Matching Contributions described in Section 2.4 or the Non-Elective Contributions described in Section 2.5 with the first (1st) paycheck on or after the “Entry Date” following the date such Eligible Employee completes one (1) “Year of Eligibility Service”. There are two (2) Entry Dates ̶ January 1st and July 1st. A “Year of Eligibility Service” is a computation period of twelve (12) consecutive months during which a regular part-time under twenty (20) hours non-bargaining unit employee is credited with at least one thousand (1000) Hours of Service. The initial computation period shall begin on the date the regular part-time under twenty (20) hours non-bargaining unit employee first performs one (1) Hour of Service with a Participating Employer or Associated Company. If the regular part-time under twenty (20) hours non-bargaining unit employee does not complete one thousand (1000) Hours of Service in the initial computation period, subsequent computation periods shall be the Plan Year, beginning with the Plan Year following the Plan Year in which the regular part-time under twenty (20) hours non-bargaining unit employee first performs one (1) Hour of Service.

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(b)Changes in Classification

(i)Change from Regular Part-time Under Twenty (20) Hours Non-Bargaining Unit Employee.

If a regular part-time under twenty (20) hours non-bargaining unit employee who has not yet met the one (1)-year, one thousand (1000) hour service requirement in Section 1.1.A(a) to become eligible for either Matching Contributions or Non-Elective Contributions changes classification to a non-bargaining unit Eligible Employee that is not a regular part-time under twenty (20) hours non-bargaining unit employee, such Eligible Employee shall immediately become eligible for either Matching Contributions or Non-Elective Contributions, as described in Sections 2.4 and 2.5. If a regular part-time under twenty (20) hours non-bargaining unit employee who has not yet met the one (1)-year, one thousand (1000) hour service requirement in Section 1.1.A(a) to become eligible for either Matching Contributions or Non-Elective Contributions becomes a bargaining unit Eligible Employee, such employee shall become eligible for either Matching Contributions or Non-Elective Contributions in accordance with the eligibility rules for bargaining unit Eligible Employees in Section 1.1(b) and as described in Sections 2.4 and 2.5.

(ii)Change to Regular Part-time Under Twenty (20) Hours Non-Bargaining Unit Employees.

If a non-bargaining unit Eligible Employee who is not a regular part-time under twenty (20) hours non-bargaining unit employee changes classification to become a regular part-time under twenty (20) hours non-bargaining unit employee, the change will have no impact on such Eligible Employee's eligibility for either Matching Contributions or Non-Elective Contributions, as described in Sections 2.4 and 2.5. If the non-bargaining unit Eligible Employee was eligible for either Matching Contributions or Non-Elective Contributions under either Section 2.4 or Section 2.5 at the time of the change in classification, the non-bargaining unit Eligible Employee will continue to be eligible for either Matching Contributions or Non-Elective Contributions after the change in classification, depending on their hire date as described in Sections 2.4 and 2.5. If a bargaining unit Eligible Employee changes classification to become a regular part-time under twenty (20) hours non-bargaining unit employee before becoming a Participant in accordance with Section 1.1(b), such Eligible Employee will be subject to the one (1)-year, one thousand (1000) hour service requirement in Section 1.1.A(a) to become eligible for either Matching Contributions or Non-Elective Contributions, as described in Sections 2.4 and 2.5. If Hours of Service have not been counted for such Eligible Employee, such Eligible Employee shall be credited with ten (10) Hours of Service for each work day of employment as a bargaining unit employee.

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(c)Break-in-Service Rules.

If a regular part-time under twenty (20) hours non-bargaining unit employee terminates employment with the Participating Employers after having met the one (1)-year, one thousand (1000) hour service requirement in Section 1.1.A(a) to become eligible for either Matching Contributions or Non-Elective Contributions, such regular part-time under twenty (20) hours non-bargaining unit employee shall be eligible for either Matching Contributions or Non-Elective Contributions immediately upon return to employment with a Participating Employer, depending on their hire date as described in Sections 2.2 and 2.3. However, if a regular part-time under twenty (20) hours non-bargaining unit employee incurs a “One (1)-Year Break in Service” before meeting the one (1)-year, one thousand (1000) hour service requirement for either Matching Contributions or Non-Elective Contributions in Section 1.1.A(a), such regular part-time under twenty (20) hours non-bargaining unit employee must complete one (1) “Year of Eligibility Service,” upon return to employment before becoming eligible for either Matching Contributions or Non-Elective Contributions, depending on their hire date as described in Sections 2.4 and 2.5. For purposes of this Section 1.1.A(c) only, a “One (1)-Year Break in Service” means a twelve (12) consecutive month computation period during which the Employee does not complete more than five hundred (500) Hours of Service. The twelve (12) month computation periods used for determining eligibility under Section 1.1.A(a) shall be used for determining “One (1)-Year Breaks in Service”.

Solely for purposes of determining whether a One (1)-Year Break in Service has occurred in a computation period (and not for purposes of determining whether a regular part-time under twenty (20) hours non-bargaining unit employee has met the one (1)-year service requirement for eligibility in Section 1.1.A(a)), a regular part-time under twenty (20) hours non-bargaining unit employee who is absent from work because of unpaid FMLA leave or for maternity or paternity reasons shall receive credit for the Hours of Service which would otherwise have been credited to such regular part-time under twenty (20) hours non-bargaining unit employee but for such absence, or in any case in which such hours cannot be determined, eight (8) Hours of service per day of such absence. For purposes of this paragraph, an absence from work for maternity or paternity reasons means an absence (1) by reason of the pregnancy of the regular part-time under twenty (20) hours non-bargaining unit employee, (2) by reason of a birth of a child of the regular part-time under twenty (20) hours non-bargaining unit employee, (3) by reason of the placement of a child with the regular part-time under twenty (20) hours nonunion employee in connection with the adoption of such child, or (4) for purposes of caring for such child for a period beginning immediately following such birth or placement. The Hours of Service credited under this paragraph shall be credited (1) in the computation period in which the absence begins if the crediting is necessary to prevent a One (1)-Year Break in Service in that period, or (2) in all other cases, in the following computation period.

(d)Regular Part-time Under Twenty (20) Hours Non-Bargaining Unit Employees are not “Covered Employees” for purposes of Automatic Enrollment.

A regular part-time under twenty (20) hours non-bargaining unit employee shall not be a “covered employee” as defined in Section 1.414(w)-1(e)(3) of the Treasury Regulations, for purposes of the eligible automatic contribution arrangement under Section 2.2.

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Section 1.2        Reemployment

If a Participant terminates employment from the Participating Employers and later returns to employment as an Eligible Employee, the Participant shall immediately recommence active participation in the Plan.

    Section 1.3    Duration of Participation

Once an Eligible Employee becomes a Participant, he or she shall have all rights to active participation (applicable contributions, etc.) as long as he or she receives Compensation from a Participating Employer and continues to be an Eligible Employee. A Participant who terminates employment with the Participating Employers with a vested Account balance shall continue to be a Participant on an inactive basis until his or her entire vested Account balance is distributed in accordance with the terms of the Plan.

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ARTICLE II
CONTRIBUTIONS

There are four types of possible contributions to the Plan: Salary Reduction Contributions, Matching Contributions, Rollover Contributions and Non-Elective Contributions. Salary Reduction Contributions (which include Catch-up Contributions) and Rollover Contributions may be made by all Participants. Matching Contributions are made only for Participants who are first employed by a Participating Employer after April 30, 2011 and before January 1, 2022, or who are deemed to be new Employees after April 30, 2011 and before January 1, 2022, under Section 1.2 of the HEI Retirement Plan. Non-Elective Contributions are made only for Participants who are first employed by a Participating Employer after December 31, 2021, or who are deemed to be new Employees after December 31, 2021, under Section 1.2 of the HEI Retirement Plan..

Section 2.1        Salary Reduction Contributions

Each Participating Employer shall make Salary Reduction Contributions in accordance with this Section 2.1 (affirmative pre-tax elections), Section 2.2 (automatic enrollment), and Section 2.3 (affirmative Roth elections).

(a)Salary Reduction Election.

An Eligible Employee who has met the requirements for participation in Section 1.1(a) or (b), as applicable, may begin making Salary Reduction Contributions by making an affirmative salary reduction election. A salary reduction election is an election by the Participant to forego taxable cash compensation in return for a pre-tax or Roth contribution of equal amount to the Participant’s Account in the Plan. A Participant's affirmative salary reduction election becomes effective as soon as practicable following its completion and submission in accordance with procedures approved by the Administrative Committee, but only with respect to amounts that are not “currently available” to the Participant at the time the election is made. An amount is “currently available” if it has been paid to the Participant or if the Participant is able currently to receive the amount at the Participant’s discretion.

(b)Pre-tax, Regular Salary Reduction Contributions.

A Participant may elect to make pre-tax, Regular Salary Reduction Contributions of up to thirty percent (30%) of the Participant’s Compensation for the period in the Plan Year during which he or she is an active Participant. In addition to this percentage limitation, a Participant’s Regular Salary Reduction Contributions are subject to the limitations in Article III of the Plan.

(c)Catch-up Contributions.

Any Participant who will have attained age fifty (50) before the end of the taxable year (a “catch-up eligible Participant”) is eligible as of the first (1st) day of the Plan Year to make Catch-up Contributions in accordance with, and subject to the limitations in, Section 3.2(b) of the Plan and Section 414(v) of the Code. Catch-up Contributions are not subject to the

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thirty percent (30%)-of-Compensation limit that applies to Regular Salary Reduction Contributions, but total Salary Reduction Contributions (Regular Salary Reduction Contributions plus Catch-up Contributions) may not exceed seventy-five percent (75%) of a Participant’s Compensation.

Catch-up Contributions are not subject to the limits on annual additions, are not counted in the ADP test, and are not counted in determining the minimum allocation under Section 416 of the Code (but Catch-up Contributions made in prior years are counted in determining whether the Plan is top-heavy).

A catch-up eligible Participant may elect to make Catch-up Contributions for the Plan Year regardless of whether his or her Regular Salary Reduction Contributions have yet reached the Plan limitation set forth in Section 2.1(b) or the Code limitations set forth in Sections 3.2 or 3.4. However, if such catch-up eligible Participant’s Regular Salary Reduction Contributions do not reach such limits by the end of the Plan Year, the Catch-up Contributions shall be recharacterized as Regular Salary Reduction Contributions to the extent necessary to meet the requirements of Section 414(v) of the Code.

(d)Amendment or Revocation of a Salary Reduction Election.

A Participant may amend or revoke a salary reduction election for any reason, such changes to take effect prospectively beginning with the first (1st) payroll period in which it is administratively practicable to effect the change. If a Participant voluntarily terminates a salary reduction election, the Participant may resume Salary Reduction Contributions by making and submitting a new election. A Participating Employer or the Administrative Committee may also revoke or amend a salary reduction election to prevent the Participant from exceeding one (1) of the maximum limitations described in Article III or in the event of a conflict between the Participant’s salary reduction election and other payroll deductions authorized by the Participant or required by law. The Administrative Committee may adopt and modify rules and procedures for salary reduction elections. Such rules and procedures will control in the event of any conflict between the rules and procedures and this Section 2.1.

(e)Application of Section 401(a)(17) Limit.

Section 401(a)(17) of the Code limits the amount of Compensation that may be taken into account in determining contributions for a Plan Year, and this limit is reflected in the definition of Compensation in Article XII. The limit applies on an annual basis. However, salary reduction elections are applied on a payroll period basis. In accordance with Section 2.1(d), a Participant may change the salary reduction percentage in effect at any time. Since contributions are limited by dollar amount under Section 402(g) of the Code, the Section 402(g) limit will apply to stop contributions before a Participant is limited by the Plan’s thirty percent (30%) limit on Compensation, as capped by Section 401(a)(17) of the Code.

(f)No Other Benefits Conditioned on Salary Reduction Election.

No other employee benefit, including, but not limited to, benefits under a defined benefit plan, non-elective employer contributions to a defined contribution plan (other than Matching

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Contributions), the availability, cost, or amount of health benefits, vacations or vacation pay, life insurance, dental benefits, legal services plans, loans (including Plan loans), financial planning services, subsidized retirement benefits, stock options, property subject to Code Section 83, or dependent care assistance, shall be directly or indirectly conditioned upon any Participant making a salary reduction election.

(g)Deposit of Salary Reduction Contributions.

The Participating Employers shall deposit Salary Reduction Contributions with the Trustee on the earliest date such contributions can reasonably be segregated from the Participating Employer’s general assets.

(h)No Prefunding of Salary Reduction Contributions.

In accordance with Section 1.401(k)-1(a)(3)(iii) of the Treasury Regulations, the Participating Employers may not make Salary Reduction Contributions prior to the Participant’s salary reduction election and the Participant’s performance of service with respect to which the Salary Reduction Contributions are made. However, this “prefunding” limitation shall not apply to contributions that are made due to bona fide administrative considerations as provided in the Treasury Regulations.

Section 2.2         Eligible Automatic Contribution Arrangement

(a)“Covered Employees”.

There are two categories of Eligible Employees who are “covered employees,” as defined in Section 1.414(w)-1(e)(3) of the Treasury Regulations, in the eligible automatic contribution arrangement (“EACA”) established under this Section 2.2. The first (1st) category of “covered employees” are Eligible Employees who: (i) first (1st) performed one (1) Hour of Service with a Participating Employer after April 30, 2011 and before January 1, 2015, or who are treated as such under Section 1.2 of the HEI Retirement Plan; (ii) have never made an affirmative salary reduction election; and (iii) do not make an affirmative salary reduction election (i.e., an election to contribute any percentage of Compensation as a Salary Reduction Contribution or an election to opt-out of automatic enrollment) during the “Election Period” described in Section 2.2(b). The second (2nd) category of “covered employees” are Eligible Employees who first (1st) perform one (1) Hour of Service with a Participating Employer after December 31, 2014, and who do not make an affirmative salary reduction election (i.e., an election to contribute any percentage of Compensation as a Salary Reduction Contribution or an election to opt-out of automatic enrollment) during the “Election Period” described in Section 2.2(b). “Covered employees” are referred to as “EACA Participants” in this Plan.

(b)Election Period: Automatic Enrollment Date; Default Election.

Every Eligible Employee who is eligible for the EACA shall be given a sixty (60)-day election period to opt-out of automatic enrollment or to make an affirmative salary reduction election. The sixty (60)-day election period begins on the date the “EACA Notice,” described in Section 2.2(e), is provided to the Eligible Employee. If, at the end of the sixty (60)-day election period, the Eligible Employee has not opted out of automatic enrollment or made an

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affirmative salary reduction election, the Eligible Employee shall be deemed to have elected to become an “EACA Participant” and to have made a default salary reduction election to contribute three percent (3%) of his or her Compensation as a pre-tax, Regular Salary Reduction Contribution, and the sixtieth (60th) day of the election period shall be the EACA Participant’s “Automatic Enrollment Date”. The EACA Participant’s default salary reduction election shall become effective as soon as administratively practicable following the EACA Participant’s Automatic Enrollment Date.

(c)Termination of EACA Participant Status.

(i)General Rules.

An EACA Participant’s default salary reduction election will continue until the EACA Participant makes an affirmative election to change (increase, decrease, or stop) the default Salary Reduction Contributions, at which point the Participant will no longer be an EACA Participant. Any change in an EACA Participant’s default salary reduction election will take effect as soon as administratively practicable after the change in accordance with Section 2.1(d) (setting forth the Plan's normal rules for changes in salary reduction elections).

(ii)Rehired EACA Participants.

If an Eligible Employee is an EACA Participant when the Eligible Employee terminates employment with the Participating Employers and the Eligible Employee is subsequently re-employed as an Eligible Employee, the Eligible Employee will again be an EACA Participant and default pre-tax, Regular Salary Reduction Contributions shall commence immediately upon rehire. If an Eligible Employee is not an EACA Participant when the Eligible Employee terminates employment with the Participating Employers (either because the Eligible Employee was never an EACA Participant or because the Eligible Employee’s EACA Participant status had terminated), the Eligible Employee will not be an EACA Participant if the Eligible Employee is re-employed by a Participating Employer and must make an affirmative salary reduction election to commence or re-commence participation in the Plan.

(d)Reasonable Opportunity To Make an Affirmative Election.

An EACA Participant shall have a reasonable opportunity after receipt of the EACA Notice to opt-out of automatic enrollment or to make an affirmative salary reduction election. The rules in Section 2.2(b) are intended to meet this requirement.

(e)Advance Notice Requirement.

At least thirty (30) days, but not more than ninety (90) days, before the beginning of each Plan Year the Plan Administrator shall provide each EACA Participant with a comprehensive notice (the “EACA Notice”) of the EACA Participant’s rights and obligations under the EACA. If an Eligible Employee becomes an EACA Participant after the ninetieth (90th) day before the beginning of the Plan Year and does not receive the EACA Notice for that reason,

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the EACA Notice will be provided no more than ninety (90) days before the Eligible Employee becomes an EACA Participant but not later than the date the Eligible Employee becomes an EACA Participant. The EACA Notice shall (1) describe the EACA Participant’s right to opt-out of automatic enrollment or to make an affirmative salary reduction election; (2) state that a default pre-tax, Regular Salary Reduction Contribution equal to three percent (3%) of the EACA Participant’s Compensation shall be made in the absence of an affirmative election; (3) describe how the default Salary Reduction Contributions will be invested in the absence of affirmative investment instructions from the EACA Participant; and (4) describe the EACA Participant’s right to elect a withdrawal of default contributions in accordance with Section 2.2(g).

(f)Default Investment.

In the absence of investment directions from an EACA Participant, the EACA Participant’s default Salary Reduction Contributions shall be invested in the qualified default investment alternative described in Section 4.3(c).

(g)Elective Withdrawal of Default Salary Reduction Contributions.

(i)Election.

No later than ninety (90) days after an EACA Participant’s Automatic Enrollment Date (which will occur earlier than ninety (90) days after default Salary Reduction Contributions are first (1st) withheld from the EACA Participant’s pay), the EACA Participant may elect to withdraw all of the default Salary Reduction Contributions made to the EACA Participant’s Account, as adjusted for earnings and losses to the date of the withdrawal. An EACA Participant’s election to withdraw default Salary Reduction Contributions shall be effective as soon as administratively practicable after the election but no later than the earlier of (1) the pay date for the second (2nd) payroll period that begins after the date the election is made or (2) the first (1st) pay date that occurs at least thirty (30) days after the election is made.

(ii)Deemed Election To Stop Default Salary Reduction Contributions.

Unless the EACA Participant affirmatively elects otherwise, any withdrawal request under this Section 2.2(g) shall be treated as an affirmative election to stop making Salary Reduction Contributions to the Participant’s Account. Any EACA Participant who withdraws his or her default Salary Reduction Contributions under this Section 2.2(g) shall no longer be an EACA Participant and will have to make an affirmative election to continue or recommence Salary Reduction Contributions.

(iii)No Effect on Section 402(g) Limit or ADP Test.

Any default Salary Reduction Contributions withdrawn under this Section 2.2(g) are not counted towards the dollar limitation on elective deferrals set forth in Section 402(g) of the Code and described in Section 3.2 of the Plan. Furthermore,

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such withdrawn default Salary Reduction Contributions are not taken into account in performing the ADP test described in Section 3.1 of the Plan.

(iv)Effect on Matching Contributions.

Matching Contributions that would otherwise be allocated to an EACA Participant’s Account will not be allocated to the extent the EACA Participant withdraws his or her default Salary Reduction Contributions under this Section 2.2(g), and any Matching Contributions that have already been made on account of default Salary Reduction Contributions that are later withdrawn shall be forfeited.

(h)Preemption of State Wage Laws.

Section 514(e) of ERISA preempts any state wage law (or any other state law) that would directly or indirectly prohibit an automatic contribution arrangement (i.e., the withholding of wages without the Employee’s express written consent).

Section 2.3        Roth Salary Reduction Contributions

A Participant making an affirmative salary reduction election in accordance with Section 2.1(a) may designate all or a portion of the Participant's Salary Reduction Contributions (including Catch-up Contributions) as Roth Salary Reduction Contributions if the following conditions are satisfied:

(a)Irrevocable Election.

The Participant’s designation must be made before the Salary Reduction Contributions are withheld from the Participant's Compensation in accordance with procedures approved by the Administrative Committee. Once Roth Salary Reduction Contributions are withheld from the Participant’s Compensation, the designation is irrevocable. However, the election may be changed with respect to future Salary Reduction Contributions in accordance with Section 2.1(d) (setting forth the Plan’s normal rules for changes in salary reduction elections). To the extent a Participant does not affirmatively designate Salary Reduction Contributions as Roth Salary Reduction Contributions, such contributions shall constitute pre-tax Salary Reduction Contributions. All Salary Reduction Contributions for EACA Participants (i.e., Participants who have been automatically enrolled in the Plan in accordance with Section 2.2) shall constitute pre-tax, Regular Salary Reduction Contributions.

(b)After-Tax Treatment by the Participating Employers.

The Participating Employers shall treat any Roth Salary Reduction Contributions as includible in the Participant's income (i.e., treat as wages subject to applicable income and employment tax withholding) at the time the Participant would have received the contributed amounts in cash but for the salary reduction election.

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(c)Separate Accounting.

In accordance with Section 4.2, the Trustee or an affiliate of the Trustee shall establish and maintain one or more Roth Contribution Subaccounts (by whatever names or designations the Trustee deems appropriate) for each Participant who elects to make Roth Salary Reduction Contributions to the Plan. The Roth Contribution Subaccounts shall include a record of the Participant’s “investment in the contract” (i.e., Roth Salary Reduction Contributions that have not been distributed). Gains, income, losses, and other credits or charges shall be separately allocated on a reasonable and consistent basis among the Roth Contribution Subaccounts and all other Subaccounts. However, no forfeitures shall be allocated to any Roth Contribution Subaccount. The separate accounting requirement described in this paragraph shall be applicable at the first time any Roth Salary Reduction Contribution is made and shall continue until the Roth Contribution Subaccounts are completely distributed.

(d)Coordination with Salary Reduction Contribution Rules.

Except as otherwise provided hereunder, the Participant's Roth Salary Reduction Contributions shall be subject to all Plan requirements applicable to pre-tax Salary Reduction Contributions. For example, except as otherwise provided hereunder, the Roth Salary Reduction Contributions shall constitute Salary Reduction Contributions for purposes of: (i) the affirmative election procedures under Section 2.1(a); (ii) the thirty percent (30%) Plan limit on Regular Salary Reduction Contributions in Section 2.1(b); (iii) the nondiscrimination tests and rules under Section 3.1; (iv) the calendar-year dollar limitation under Section 402(g) of the Code and Section 3.2(a) of the Plan; (v) the Catch-up Contribution provisions in Section 414(v) of the Code and Sections 2.1(c) and 3.2(b) of the Plan; (vi) any allocation of Matching Contributions under the Plan; (vii) the limitations under Section 415(c) of the Code that are described in Section 3.4; (viii) the minimum distribution rules in Section 401(a)(9) of the Code and Section 6.8 of the Plan; (ix) full vesting of Salary Reduction Contributions under Section 5.1(a); and (x) the determination of Top-Heavy Plan status under Article XI.

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Section 2.4         Matching Contributions for Participants First Employed by a Participating Employer After April 30, 2011 and Before January 1, 2022 (or Deemed To Be New Employees After April 30, 2011 and Before January 1, 2022, Under Section 1.2 of the HEI Retirement Plan)

A Participant who is first employed by a Participating Employer after April 30, 2011 and before January 1, 2022, or who is deemed to be a new Employee of a Participating Employer after April 30, 2011 and before January 1, 2022, under Section 1.2 of the HEI Retirement Plan, shall be eligible for the Matching Contributions described in this Section 2.4. Any Participant who was first employed by a Participating Employer prior to May 1, 2011 or after December 31, 2021, and who is not deemed to be a new Employee after April 30, 2011 and before January 1, 2022, under Section 1.2 of the HEI Retirement Plan, is not eligible for the Matching Contributions described in this Section 2.4.

(a)Amount.

The Participating Employers shall match the Salary Reduction Contributions of their eligible Participants on the following basis: a fifty percent (50%) match on the first six percent (6%) of annual Compensation deferred by the Participant (i.e., maximum Matching Contribution of three percent (3%) of the Participant’s annual Compensation). Since Section 12.8 limits the Compensation taken into account in determining contributions to Compensation earned after an Eligible Employee becomes a Participant, in a Participant’s first (1st) year of participation, Compensation earned before the Participant begins participation shall not be counted in the Participant’s annual Compensation for purposes of calculating the Participant’s Matching Contribution.

(b)Matching Contributions on Catch-up Contributions.

Catch-up Contributions are treated as “elective deferrals” under the Code and Treasury Regulations. Accordingly, Catch-up Contributions are eligible for Matching Contributions. However, since Matching Contributions are made only on the first six percent (6%) of Compensation deferred, so long as the interplay of the limitations in Sections 401(a)(17) and 402(g) of the Code make it impossible for Catch-up Contributions to be within the first six percent (6%) of a Participant’s Compensation, no Matching Contributions shall be made on Catch-up Contributions.

(c)Deposit of Matching Contributions; True-up.

The Participating Employers will pay the Matching Contributions to the Trustee no later than the due date, including extensions thereof, for filing the Company’s tax return for the taxable year with respect to which the Matching Contributions are made. If the Participating Employers pay the Matching Contributions to the Trustee prior to the end of the year with respect to which the Matching Contributions are made, the Participating Employers shall true-up the Matching Contributions at or after the end of the year to make sure that each Participant received a Matching Contribution equal to fifty percent (50%) of the first six percent (6%) of annual Compensation deferred by the Participant for the year.

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(d)Application of Section 401(a)(17) Limit.

The dollar limit in effect under Section 401(a)(17) of the Code shall be applied on an as-earned basis. This means that once a Participant has earned Compensation equal to the dollar limit under Section 401(a)(17) for the Plan Year, no further Matching Contributions shall be made for that Participant for the Plan Year.

Section 2.5        Non-Elective Contributions for Participants First Employed by a Participating Employer After December 31, 2021 (or Deemed to Be New Employees After December 31, 2021, Under Section 1.2 of the HEI Retirement Plan)

A Participant who is first employed by a Participating Employer after December 31, 2021, or who is deemed to be a new Employee of a Participating Employer after December 31, 2021, under Section 1.2 of the HEI Retirement Plan, shall be eligible for the Non-Elective Contributions described in this Section 2.5. Any Participant who was first employed by a Participating Employer prior to January 1, 2022, and who is not deemed to be a new Employee after December 31, 2021, under Section 1.2 of the HEI Retirement Plan, is not eligible for the Non-Elective Contributions described in this Section 2.5.

(a)Amount.

Each Plan Year, the Participating Employers shall make a Non-Elective Contribution on behalf of each Participant in an amount equal to ten percent (10%) of the Participant's Compensation for such year. Since Section 12.8 limits the Compensation taken into account in determining contributions to Compensation earned after an Eligible Employee becomes a Participant, in a Participant’s first year of participation the Compensation earned before the Participant begins participation shall not be taken into account in determining the Participant's Compensation for purposes of calculating the Participant’s Non-Elective Contribution.

(b)Timing of Deposit of Non-Elective Contributions

The Participating Employers will pay the Non-Elective Contributions to the Trustee no later than the due date, including extensions thereof, for filing the Company’s tax return for the taxable year with respect to which the Non-Elective Contributions are made. If the Participating Employers pay the Non-Elective Contributions to the Trustee prior to the end of the Plan Year with respect to which the Non-Elective Contributions are made, the Participating Employers shall true-up the Non-Elective Contributions at or after the end of the Plan Year, as may be necessary to ensure that each Participant receives a Non-Elective Contribution equal to fifty percent (10%) of the Participant’s Compensation for such year.

Section 2.6        Return of Contributions

(a)Mistake of Fact.

If a contribution is made because of a mistake of fact, the contribution may be returned within one (1) year after the contribution is made. The amount that may be returned is the amount contributed over the amount that would have been contributed had no mistake of fact

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occurred. Earnings on mistaken Matching Contributions and Non-Elective Contributions may not be returned, but losses attributable thereto reduce the amount returned. Mistaken Regular Salary Reduction and Catch-up Contributions shall be adjusted for earnings or losses.

(b)Loss of Deduction.

If a Matching Contribution or Non-Elective Contribution is not deductible under the Code, such contribution (to the extent the deduction is disallowed) may be returned to the Participating Employer within one (1) year after the disallowance of the deduction. Earnings on nondeductible contributions may not be returned, but losses attributable thereto reduce the amount returned.

Section 2.7        Rollover Contributions

(a)Direct Rollovers.

A Participant or an Eligible Employee (whether or not a Participant) may make a “direct rollover” to the Plan of an “eligible rollover distribution” from: (i) a retirement plan qualified under Section 401(a) of the Code; (ii) an annuity plan described in Section 403(a) of the Code; (iii) an annuity contract described in Section 403(b) of the Code; (iv) an individual retirement account or individual retirement annuity described in Section 408 of the Code; or (v) an eligible Section 457(b) deferred compensation plan established and maintained by a state, political subdivision of a state, or any agency or instrumentality of a state or political subdivision of a state.

A “direct rollover” is a direct payment of an eligible rollover distribution by any reasonable means from the trustee, custodian, or annuity provider of the former plan or arrangement to the Trustee of this Plan. For purposes of this Section 2.7, an “eligible rollover distribution” means a payment of cash which is not one of a series of periodic payments, is not a payment required to be distributed to the Participant under Section 401(a)(9) of the Code, and is not a hardship distribution from another plan.

The Administrative Committee may adopt reasonable standards and procedures for determining whether a proposed rollover is permissible.

(b)Direct Rollovers from Designated Roth Accounts.

A Participant or an Eligible Employee may make a direct rollover from a designated Roth account in another tax-qualified 401(k) plan or 403(b) annuity or governmental 457(b) plan. The Trustee shall separately account for any Roth contributions rolled over to the Plan. Rollover contributions are not permitted from Roth IRAs.

(c)Direct Rollovers of Other After-Tax Amounts.

The Plan may accept direct rollovers of other after-tax amounts from retirement plans qualified under Section 401(a) of the Code or from annuity contracts described in Section 403(b) of the Code. The Trustee shall separately account for the after-tax portion of any direct rollover under this Section 2.7(c).

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(d)Traditional Rollovers.

The Administrative Committee may consider traditional rollovers by Eligible Employees. To protect the tax-qualified status of the Plan, the Administrative Committee may ask the Eligible Employee to provide an opinion of counsel or other evidence to establish that the requirements for a traditional rollover have been satisfied.

Section 2.8        USERRA Rights of Participants Returning from Qualified Military Service

If a Participant returns to employment with a Participating Employer following a leave of absence for Qualified Military Service, the Participant shall be eligible to have his or her military leave of absence counted as employment with the Participating Employer for purposes of Salary Reduction Contributions, Non-Elective Contributions, and Matching Contributions, as applicable. The Administrative Committee has established written procedures to meet the requirements of the Uniformed Services Employment and Reemployment Rights Act of 1994 (“USERRA”). These procedures establish rules permitting reemployed veterans to make up Salary Reduction Contributions upon their return to employment with a Participating Employer and granting makeup Matching Contributions for returning Participants who would have been entitled to Matching Contributions during the military leave of absence. The USERRA procedures are incorporated herein by this reference and may be amended at any time without notice and without further amendment to the Plan.

Section 2.9        Qualified Nonelective Contributions

The Participating Employers may make qualified nonelective contributions if necessary to correct a qualification failure in accordance with the Employee Plans Compliance Resolution System. A “qualified nonelective contribution” is an employer contribution that is one hundred percent (100%) vested when made, that the Participant may not elect to receive in cash, and that is distributable only in accordance with the distribution restrictions applicable to Salary Reduction Contributions, except that qualified nonelective contributions may not be distributed on account of hardship. Qualified nonelective contributions cannot be taken into account in performing the ADP and ACP tests described in Sections 3.1 and 3.3, respectively, for a Plan Year for an NHCE to the extent such contributions exceed the product of that NHCE’s ADP Compensation and the greater of five percent (5%) or two (2) times the Plan’s representative contribution rate. Any qualified nonelective contribution taken into account under an ACP test under Section 1.401(m)-2(a)(6) of the Treasury Regulations (including the determination of the representative contribution rate for purposes of Section 1.401(m)-2(a)(6)(v)(B)) is not permitted to be taken into account under the ADP test (including the determination of the representative contribution rate under Section 1.401(k)-2(a)(6)(iv)(B)). Any qualified nonelective contribution taken into account in an ADP test under Section 1.401(k)-2(a)(6) of the Treasury Regulations (including the determination of the representative contribution rate for purposes of Section 1.401(k)-2(a)(6)(iv)(B)) is not permitted to be taken into account under the ACP test (including the determination of the representative contribution rate for purposes of Section 1.401(m)-2(a)(6)(v)(B)). The Plan’s “representative contribution rate” is the lowest applicable contribution rate of any eligible NHCE among a group of eligible NHCEs that consists of half of all eligible NHCEs for the Plan Year (or, if greater, the lowest applicable contribution rate of any eligible NHCE in the group of all eligible NHCEs for the Plan Year and who is employed by a

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Participating Employer on the last day of the Plan Year). For purposes of the ADP test, the “applicable contribution rate” for an eligible NHCE is the sum of the qualified matching contributions, if any, taken into account in performing the ADP test for the eligible NHCE for the Plan Year and the qualified nonelective contributions made for the eligible NHCE for the Plan Year, divided by the eligible NHCE’s ADP Compensation for the same period. For purposes of the ACP test, the “applicable contribution rate” for an eligible NHCE is the sum of the matching contributions taken into account in performing the ACP test for the eligible NHCE for the Plan Year and the qualified nonelective contributions made for the eligible NHCE for the Plan Year, divided by the eligible NHCE’s ADP Compensation for the same period.

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ARTICLE III
NONDISCRIMINATION RULES; LIMITATIONS ON CONTRIBUTIONS

Section 3.1        Section 401(k) Nondiscrimination Rules

(a)ADP Test.

Regular Salary Reduction Contributions are tested for discrimination under the actual deferral percentage (“ADP”) test of Section 401(k)(3)(A)(ii) of the Code. For purposes of ADP testing, the portion of the Plan that covers nonunion Participants and the portion of the Plan that covers bargaining unit Participants are treated as separate plans and tested separately.

(b)Prior-year Testing Method.

The Plan uses the prior-year ADP testing method, under which the ADP in the current year for the group of Eligible Employees who are HCEs is compared to the ADP in the previous year for the group of Eligible Employees who were NHCEs in the previous year. The comparative percentages must satisfy one of the following tests:

(i)1.25 Test.

The ADP for the current Plan Year for the group of Eligible Employees who are HCEs is not more than the ADP in the previous Plan Year for the group of Eligible Employees who were NHCEs in the previous Plan Year multiplied by 1.25 [HCE ADP ≤ (NHCE ADP x 1.25)], or

(ii)Two Percent (2%) Spread Test.

The excess of the ADP for the current Plan Year for the group of Eligible Employees who are HCEs is not more than two percentage points greater than the ADP in the previous Plan Year for the group of Eligible Employees who were NHCEs in the previous Plan Year, and the ADP for the current Plan Year for the group of Eligible Employees who are HCEs is not more than twice the ADP in the previous Plan Year for the group of Eligible Employees who were NHCEs in the previous Plan Year [HCE ADP < (NHCE ADP + 2%)] and [HCE ADP ≤ (NHCE ADP x 2)].

(c)ADP Rules

(i)Groups.

The ADP for a specified group of Eligible Employees for a Plan Year means the average of the ratios (calculated separately for each Eligible Employee in such group) of (A) the amount of Regular Salary Reduction contributions allocated to the Eligible Employee’s Account as of a date within such Plan Year to (B) such Eligible Employee’s ADP Compensation for such Plan Year. The ADP of an

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Eligible Employee who is eligible to but does not elect to have Salary Reduction Contributions made on his or her behalf for a Plan Year is zero.

(ii)Special Rule for HCEs.

The ADP for any Eligible Employee who is an HCE for the Plan Year and who is eligible to have contributions allocated to his or her account under two or more cash or deferred arrangements described in Section 401(k) of the Code that are maintained by a Participating Employer or Associated Company shall be determined as if such contributions were made under a single arrangement.

(iii)Lookback.

The ADP for the eligible NHCEs is determined using the actual deferral ratios for the Eligible Employees who were NHCEs in the previous Plan Year, regardless of whether those NHCEs are Eligible Employees or NHCEs in the Plan Year for which the ADP test is being calculated.

(iv)Catch-up Contributions.

Catch-up Contributions are not taken into account under the ADP test for any Plan Year.

The provisions of Section 401(k)(3) of the Code and Section 1.401(k)-2 of the Treasury Regulations are incorporated in the Plan by this reference.

(d)Correction of Excess Contributions.

Excess contributions are corrected under a four-step process as follows:

(i)Step 1.

If the Plan does not satisfy either of the ADP tests for a Plan Year, the dollar amount of excess contributions for each affected HCE shall be calculated in a manner consistent with Section 401(k)(8)(B) of the Code and Section 1.401(k)-2(b)(2) of the Treasury Regulations, which states that the amount of excess contributions for an HCE is the amount (if any) by which such HCE’s contributions must be reduced for the HCE’s actual deferral ratio (“ADR”) to equal the highest permitted ADR for the year. To calculate the highest permitted ADR, the ADR of the HCE with the highest ADR is reduced by the amount required to cause that HCE’s ADR to equal the ADR of the HCE with the next highest ADR. If a lesser reduction would enable the arrangement to satisfy the ADP test after reductions, only this lesser reduction would be used. The process described in this Step 1 must be repeated until the arrangement would satisfy the ADP test after reductions. The sum of all reductions for all HCEs is the total amount of excess contributions for the Plan Year.

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(ii)Step 2.

The total amount of excess contributions determined in Step 1 shall be apportioned among the HCEs in accordance with this Step 2. The contributions of the HCE with the highest dollar amount of contributions taken into account under the ADP test shall be reduced by the amount required to cause that HCE’s contributions to equal the dollar amount of the contributions for the HCE with the next highest dollar amount of contributions taken into account under the ADP test. However, if a lesser apportionment to the HCE would enable the Plan to apportion the total amount of excess contributions, only the lesser apportionment would apply. The procedure in this Step 2 must be repeated until the total amount of excess contributions has been apportioned.

(iii)Step 3.

The amount of excess contributions apportioned to an HCE shall be adjusted for any income or loss attributable to such excess contributions, provided that there shall be no adjustment for earnings or losses occurring in the gap period between the end of the Plan Year in which the excess contributions were made and the time when the excess contributions are distributed. The income or loss allocable to the excess contributions shall be calculated by multiplying the income or loss allocable to the HCE’s Salary Reduction Subaccount for the Plan Year in which the excess contributions occurred by a fraction, the numerator of which is the HCE’s excess contributions for the Plan Year and the denominator of which is the balance of the HCE’s Salary Reduction Subaccount as of the beginning of the Plan Year plus the HCE’s Salary Reduction Contributions during the Plan Year.

(iv)Step 4.

Within twelve (12) months after the close of the Plan Year in which the excess contributions occurred, the Plan must distribute to each HCE the excess contributions apportioned to the HCE under Step 2 and the allocable income determined under Step 3. To avoid the ten percent (10%) excise tax under Section 4979 of the Code, the distributions must be made within two and a half (2 1/2) months after the close of the Plan Year in which the excess contributions occurred. The distribution shall be designated as a corrective distribution of excess contributions.

(v)Special Rule for Catch-up Contributions.

If an HCE who would otherwise receive a corrective distribution is eligible to make Catch-up Contributions for the year in which the excess contributions occurred and if the Catch-up Contributions for such HCE are less than the Catch-up Contribution dollar limit in. Section 3.2(b), some or all of the amount that would otherwise be distributed to the HCE shall be recharacterized as a Catch-up Contribution and retained in. such HCE’s Account. The amount to be recharacterized and retained shall be equal to the lesser of (1) the difference

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between the Catch-up Contribution dollar limit for the Plan Year and the HCE’s prior Catch-up Contributions for the Plan Year or (2) the total amount that would otherwise be distributed to the HCE as a corrective distribution.

(vi)Special Rule for Roth Salary Reduction Contributions.

To the extent excess contributions are distributed to an HCE under this Section 3.1(d) for a Plan Year that includes both pre-tax Salary Reduction Contributions and Roth Salary Reduction Contributions, the excess contributions shall be distributed in the following order of priority: (A) first, any pre-tax Salary Reduction Contributions shall be distributed, and (B) second, Roth Salary Reduction Contributions shall be distributed. In accordance with Treasury Regulations, the principal amount of any Roth Salary Reduction Contributions shall not be includible in gross income, but any income allocable to the distribution shall be includible in gross income.

Section 3.2         Maximum Elective Deferrals

(a)Dollar Limit on Salary Reduction Contributions.

No Participant shall be permitted to make Salary Reduction Contributions during any calendar year in excess of the amount of elective deferrals permitted by Section 402(g)(1) of the Code. The limit is set annually by the IRS and is adjusted for cost-of-living increases.

(i)Designation of Excess Elective Deferrals.

The 402(g) limit applies to the Participant and is based not only on Salary Reduction Contributions to this Plan but also on “elective deferrals” to any other qualified retirement plan, including plans of other employers. “Elective deferrals” are contributions made to employer-sponsored, qualified retirement plans pursuant to salary reduction agreements and include 401(k) contributions, 403(b) annuity contributions, and elective contributions to SIMPLE plans. Since neither the Participating Employers nor the Administrative Committee has knowledge of a Participant’s elective deferrals to qualified retirement plans of other employers, it is the Participant’s responsibility to monitor this limit with respect to all elective deferrals. If a Participant’s elective deferrals for a Plan Year are in excess of the 402(g) limit, the Participant must choose which plan to allocate the excess to. If the Participant chooses to allocate some or all of the excess to this Plan, the Participant must so notify the Administrative Committee no later than March 1 of the year following the year in which the excess occurred. The Participant’s notice to the Administrative Committee must (a) be in writing, (b) specify the amount of such excess for the preceding year allocated to the Plan, and (c) be accompanied by the Participant’s written statement to the effect that if such amounts are not distributed, such excess (when added to amounts deferred under other qualified retirement plans or arrangements) would exceed the limit imposed on the Participant by Section 402(g) of the Code for the year in which the contribution occurred. A Participant shall be deemed to have

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provided the foregoing notice to the Administrative Committee if the Participant’s elective deferrals have exceeded the 402(g) limit taking into account only Salary Reduction Contributions to this Plan and elective deferrals to other plans sponsored by the Participating Employers or an Associate Company.

(ii)Distribution of Excess Elective Deferrals.

Any excess elective deferrals allocated to the Plan in accordance with the foregoing paragraph, plus any income and minus any loss allocable thereto through the end of the Plan Year, shall be distributed to the Participant no later than April 15 of the year following the year in which the excess elective deferrals were contributed. The income or loss allocable to such excess elective deferrals shall be calculated by multiplying the income or loss allocable to the Participant’s Salary Reduction Subaccount for the Plan Year by a fraction, the numerator of which is the Participant’s excess elective deferrals for the Plan Year and the denominator of which is the balance of the Participant’s Salary Reduction Subaccount as of the beginning of the Plan Year plus the Participant’s Salary Reduction Contributions during the Plan Year. There shall be no adjustment for earnings or losses occurring in the gap period between the end of the Plan Year in which the excess elective deferrals were made and the time when the excess elective deferrals are distributed.

(iii)Special Rule for Catch-up Contributions.

If a catch-up eligible Participant has made Regular Salary Reduction Contributions in excess of the 402(g) limit but has not made the full amount of Catch-up Contributions permitted under Section 3.2(b), the amount of Regular Salary Reduction Contributions in excess of the 402(g) limit shall be recharacterized as Catch-up Contributions to the extent permitted under Section 3.2(b).

(iv)Special Rule for Roth Salary Reduction Contributions.

To the extent excess elective deferrals are distributed under Section 3.2(a)(ii) for a Plan Year that includes both pre-tax Salary Reduction Contributions and Roth Salary Reduction Contributions, the excess elective deferrals shall be distributed in the following order of priority: (A) first, any pre-tax Salary Reduction Contributions shall be distributed, and (B) second, Roth Salary Reduction Contributions shall be distributed. In accordance with Treasury Regulations, the principal amount of any Roth Salary Reduction Contributions shall not be includible in gross income, but any income allocable to the distribution shall be includible in gross income.

(b)Dollar Limit on Catch-up Contributions.

No catch-up eligible Participant shall be permitted to make Catch-up Contributions during any calendar year in excess of the amount permitted under Section 414(v)(2)(B)(i) of the Code, as adjusted for cost-of-living increases.

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Section 3.3        Section 401(m) Nondiscrimination Rules

(a)ACP Test.

Matching Contributions made on behalf of nonunion Participants are tested for discrimination under the actual contribution percentage (“ACP”) test of Section 401(m)(2) of the Code. (Matching Contributions made on behalf of bargaining unit Participants automatically satisfy the Section 401(m) nondiscrimination requirements.)

(b)Prior-year Testing Method.

The Plan uses the prior-year ACP testing method, under which the ACP in the current year for the group of Eligible Employees who are HCEs is compared to the ACP in the previous year for the group of Eligible Employees who were NHCEs in the previous year. The comparative percentages must satisfy one of the following tests:

(i)1.25 Test.

The ACP for the current Plan Year for the group of Eligible Employees who are HCEs is not more than the ACP in the previous Plan Year for the group of Eligible Employees who were NHCEs in the previous Plan Year multiplied by 1.25 [HCE ACP ≤ (NHCE ACP x 1.25), or

(ii)2% Spread Test.

The excess of the ACP for the current Plan Year for the group of Eligible Employees who are HCEs is not more than two percentage points greater than the ACP in the previous Plan Year for the group of Eligible Employees who were NHCEs in the previous Plan Year, and the ACP for the current Plan Year for the group of Eligible Employees who are HCEs is not more than twice the ACP in the previous Plan Year for the group of Eligible Employees who were NHCEs in the previous Plan Year [HCE ACP ≤ (NHCE ACP + 2%)] and [HCE ACP ≤ (NHCE ACP x 2)].

(c)ACP Rules

(i)Groups.

The ACP for a specified group of Eligible Employees for a Plan Year means the average of the ratios (calculated separately for each Eligible Employee in such group) of (A) the amount of Matching Contributions allocated to the Eligible Employee’s Account as of a date within such Plan Year to (B) such Eligible Employee’s ADP Compensation for such Plan Year.

(ii)Special Rule for the 2011 Plan Year.

For the 2011 Plan Year, which was the first year in which Matching Contributions were made, the ACP for NHCEs was deemed to be three percent (3%).

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(iii)Special Rule for HCEs.

The ACP for any Eligible Employees who is an HCE for the Plan Year and who is eligible for matching contributions or employee contributions under more than one plan maintained by a Participating Employer or Associated Company shall be determined as if such contributions were made under a single arrangement.

(iv)Lookback.

The ACP for the eligible NHCEs is determined using the actual contribution ratios for the Eligible Employees who were NHCEs in the previous Plan Year, regardless of whether those NHCEs are Eligible Employees or NHCEs in the Plan Year for which the ACP test is being calculated.

The provisions of Section 401(m)(2) of the Code and Section 1.401(m)-2 of the Treasury Regulations are incorporated in the Plan by this reference.

(d)Correction of Excess Aggregate Contributions.

Excess aggregate contributions are corrected under a four-step process as follows:

(i)Step 1.

If the Plan does not satisfy either of the ACP tests for a Plan Year, the dollar amount, of excess aggregate contributions for each affected HCE shall be calculated in a manner consistent with Section 401(m)(6) of the Code and Section 1.401(m)-2(b)(2) of the Treasury Regulations, which states that the amount of excess aggregate contributions for an HCE is the amount (if any) by which such HCE’s contributions must be reduced for the HCE’s actual contribution ratio (“ACR”) to equal the highest permitted ACR for the year. To calculate the highest permitted ACR, the ACR of the HCE with the highest ACR is reduced by the amount required to cause that HCE’s ACR to equal the ACR of the HCE with the next highest ACR. If a lesser reduction would enable the arrangement to satisfy the ACP test, only this lesser reduction would be used. The process described in this Step 1 must be repeated until the arrangement would satisfy the ACP test after reductions. The sum of all reductions for all HCEs is the total amount of excess aggregate contributions for the Plan Year.

(ii)Step 2.

The total amount of excess aggregate contributions determined in Step 1 shall be apportioned among the HCEs in accordance with this Step 2. The contributions of the HCE with the highest dollar amount of contributions taken into account under the ACP test shall be reduced by the amount required to cause that HCE’s contributions to equal the dollar amount of the contributions for the HCE with the next highest dollar amount of contributions taken into account under the ACP test. However, if a lesser apportionment to the HCE would enable the Plan to apportion the total amount of excess aggregate contributions, only the lesser

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apportionment would apply The procedure in this Step 2 must be repeated until the total amount of excess aggregate contributions has been apportioned.

(iii)Step 3.

The amount of excess aggregate contributions apportioned to an HCE shall be adjusted for any income or loss attributable to such excess aggregate contributions, provided that there shall be no adjustment for earnings or losses occurring in the gap period between the end of the Plan Year in which the excess aggregate contributions were made and the time when the excess aggregate contributions are distributed. The income or loss allocable to the excess aggregate contributions shall be calculated by multiplying the income or loss allocable to the HCE’s Matching Contribution Subaccount for the Plan Year in which the excess aggregate contributions occurred by a fraction, the numerator of which is the HCE’s excess aggregate contributions for the Plan Year and the denominator of which is the balance of the HCE’s Matching Contribution Subaccount as of the beginning of the Plan Year plus the HCE’s Matching Contributions for the Plan Year.

(iv)Step 4.

Within twelve (12) months after the close of the Plan Year in which the excess aggregate contributions occurred, the Plan must distribute to each HCE the excess aggregate contributions apportioned to the HCE under Step 2 and the allocable income determined under Step 3. To avoid the ten percent (10%) excise tax under Section 4979 of the Code, the distributions must be made within two and a half (2 1/2) months after the close of the Plan Year in which the excess aggregate contributions occurred. The distribution shall be designated as a corrective distribution of excess aggregate contributions.

Section 3.4         Section 415 Limitations

(a)Annual Additions.

For each Plan Year, “Annual Additions” to the Plan (plus “Annual Additions” to any other defined contribution plan that a Participating Employer maintains) on behalf of each Participant may not exceed the lesser of $40,000 (adjusted for cost-of-living increases under Section 415(d) of the Code) or one hundred percent (100%) of the Participant’s 415 Compensation for the Plan Year. “Annual Additions” means the sum credited to a Participant’s Account for a Plan Year of:

•All employer contributions (including Salary Reduction Contributions);

•All Employee contributions (none are currently allowed);

•Forfeitures; and

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•With respect to “Key Employees” only, as defined in Section 11.1(a), amounts contributed to a 401(h) account in a defined benefit plan or to a qualified asset account in a welfare benefit fund to provide postretirement medical benefits to or on behalf of the Key Employee, except that the one hundred percent (100%)-of-compensation limitation on Annual Additions shall not apply to any amounts treated as Annual Additions under this paragraph.

Catch-up Contributions and assets transferred or rolled over from another qualified plan are not Annual Additions. Furthermore, the reinvestment of dividends on Company Stock, described in Sections 4.3(a) and (e), the allocation of a restorative payment, described in Section 1.415(c)-1(b)(2)(ii)(C) of the Treasury Regulations, and the repayment of a Plan loan are not Annual Additions. However, Annual Additions include excess contributions and excess aggregate contributions for a Plan Year that are subsequently distributed to a Participant pursuant to Section 3.1(d) and 3.3(d), as applicable. Annual Additions also include Salary Reduction Contributions that exceed the limits of Section 402(g) of the Code, except to the extent such excess amounts are refunded to the Participant by April 15 of the following Plan Year.

(b)Section 415 Aggregation Rules.

In applying the limitations of Section 415 of the Code, all defined contribution plans (whether or not terminated) of a Participating Employer (or a predecessor employer, as defined in Section 1.415(f)-1(c) of the Treasury Regulations) under which the Participant has received Annual Additions shall be treated as one plan, and the term “Participating Employer” shall include the Company and all corporations that are members of the same controlled group of corporations (as defined in Code Section 414(b) as modified by Code Section 415(h)), all commonly controlled trades or businesses (as defined in Code Section 414(c), as modified, except in the case of a brother-sister group of trades or businesses under common control, by Code Section 415(h)), affiliated service groups (as defined in Code Section 414(m)), and any other entity required to be aggregated with the Company under Code Section 414(o).

(c)Correction of Excess Annual Additions.

The correction methods for excess annual additions in Section 1.415-6(b)(6) of the 1981 Treasury Regulations shall not be effective for limitation years beginning on or after July 1, 2007, except as permitted under the Employee Plans Compliance Resolution System.

Section 3.5         Forfeiture of Matching Contributions

Matching Contributions shall be forfeited if the Salary Reduction Contributions to which the Matching Contributions relate are returned to the Participant because the Salary Reduction Contributions are determined to be excess contributions under Section 3.1 or excess elective deferrals under Section 3.2. Matching Contributions that are forfeited shall be adjusted for income or loss in the same way as the Salary Reduction Contributions that are returned to the Participant. To the extent that the Matching Contributions represent excess aggregate

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contributions that are distributed to the Participant under Section 3.3, the forfeiture shall not occur.

Any Matching Contributions forfeited under this Section 3.5 shall be used to pay administrative expenses of the Plan or to reduce the Participating Employers’ Matching Contributions in accordance with Section 5.2(c).

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ARTICLE IV
ACCOUNTING AND INVESTMENTS

Section 4.1         Assets To Be Held by Trustee

All assets of the Plan shall be held and invested by the Trustee pursuant to the Trust Agreement and the rules set forth in this Article IV.

Section 4.2         Accounting and Expenses

The Trustee or an affiliate of the Trustee shall maintain accurate accounting of each Participant’s interest in the Plan in accordance with the Trust Agreement or separate record keeping agreement.

(a)Subaccounts.

Although the total interest of a Participant in the Plan is reflected in or expressed as his or her Account, the Trustee may maintain Subaccounts to reflect different sources of contributions to a Participant’s Account. For example, all Salary Reduction Contributions and any other 401(k) monies must be separately accounted for to ensure that the distribution restrictions under Section 401(k) are complied with. As of January 1, 2022, the Trustee maintains the following Subaccounts with respect to Participant Accounts:

•Salary Reduction	•Participant Voluntary
•Rollover	•HEI Diversified Plan ("HEIDI")
•ER Matching Contribution	•AmeriMatch
•Employer ASB	•Employer Supplemental
•Non-Elective Contribution

The Subaccounts may be changed at any time by agreement between the Company or the PIC and the Trustee.

(b)Valuation of Accounts.

The Account and Subaccounts of each Participant shall be valued at the end of each day that the New York Stock Exchange is open (each, a “valuation date”). All distributions, withdrawals, and Plan loans shall be based on the value of a Participant’s Account as of the last valuation date.

(c)Fees and Expenses.

Generally, there are three kinds of expenses associated with investments in the HEIRS Plan: investment expenses associated with the investment options, administrative expenses, and individual expenses. These are generally described as follows:

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(i)Investment Expenses.

The investment options have investment fees and expenses associated with them. The fees and expenses associated with the mutual funds offered under the Plan may include, but are not limited to, investment management fees, marketing and distribution fees (12b-1 fees), shareholder servicing fees, recordkeeping fees, and. fees for other operating expenses. The annual percentage of a mutual fund’s assets paid out in expenses is expressed as an “expense ratio”. Since the mutual funds are buying and selling securities, there are also transaction costs, including, but not limited to, brokerage commissions that are reflected in the price paid or received by the mutual fund for the various securities purchased or sold.

Investment expenses associated with an investment in “Company Stock,” as defined in Section 4.3(a), may include, but are not limited to, brokerage commissions when Company Stock is purchased or sold on the open market.

(ii)Administrative Expenses.

Administrative expenses may include, but are not limited to, trustee, legal, accounting, actuarial, recordkeeping, and investment consulting fees. Each Participant may be assessed a recordkeeping fee by the Trustee with respect to his or her Account. Administrative fees specifically associated with an investment in Company Stock may include, but are not limited to, a basic fee for administering Company Stock as an investment under the Plan and fees associated with administering the dividend pass-through program. The mutual funds may pay fees to the Trustee to offset recordkeeping and other administrative expenses. The mutual fund investments may also generate credits which may be used to offset administrative expenses to the extent permitted under ERISA. Credits generated in excess of administrative expenses may be allocated as income to Participant accounts on a pro rata or other reasonable basis.

(iii)Individual Expenses.

Individual expenses are expenses triggered by Participant or Beneficiary action. These fees may include, but are not limited to, loan set-up and quarterly or annual servicing fees, fees connected with distributions and withdrawals, and fees to qualify and administer domestic relations orders. As described in Section 4.3(b) below, certain trading practices may trigger individual redemption fees or penalties. Generally, individual expenses are charged to the individual accounts of the Participants and Beneficiaries who have initiated the action that triggered the expense.

All costs and expenses of the Plan and any taxes assessed against the Plan may be paid from the Plan. The fees and expenses paid from the Plan shall be allocated among Accounts as determined by the Administrative Committee, which shall have the authority, in its discretion, to cause fees and expenses that are properly allocable to particular, individual Accounts to be charged directly to such Accounts and to cause fees and expenses that are not so allocable to be allocated among all Accounts in a reasonable

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manner determined by the Administrative Committee. The Administrative Committee shall maintain and make available, or ensure that the Trustee maintains and makes available, a current fee schedule for routine fees and expenses that the Administrative Committee has determined to be directly chargeable to the Accounts of particular Participants and Beneficiaries; provided, however, that the Administrative Committee may cause specific expenses to be allocated directly to one or more particular Accounts if the Administrative Committee determines that such allocation is reasonable and appropriate under applicable law and administrative guidance, even if such expenses are not listed on the fee schedule.

The Participating Employers may, but are not required to, pay the general administrative expenses of the Plan. In accordance with applicable prohibited transaction exemptions under ERISA, the Participating Employers may make unsecured, interest-free loans or advances to the Plan to pay the ordinary administrative expenses of the Plan.

Section 4.3         Investment of Accounts

(a)Broad Range of Investments.

The Plan offers a broad range of investment funds, including, but not limited to, mutual funds managed by an affiliate of the Trustee and other companies and common stock of the Company (“Company Stock”). The PIC may change the investment funds offered at any time. A prospectus describing the Plan and the investment risks associated with an investment in the Plan is available to Participants. Appendix A to such prospectus describes the investment funds offered under the Plan. Prospectuses are also available for the mutual fund options.

(b)Participant Direction.

Each Participant is responsible for investing all of his or her Account. A Participant exercises his or her investment responsibility by choosing from among the investment funds offered. Participants are responsible for educating themselves regarding the investment funds available to them. Initial investment choices and subsequent changes are made directly with the Trustee via the telephone or Internet. The PIC is authorized to establish additional rules to regulate or restrict investment elections. The Trustee and the mutual funds may impose their own rules and restrictions with respect to investments, including imposing redemption fees and penalties to restrict certain trading practices. Investment elections and exchanges under the Plan are subject to all such rules, restrictions, fees, and penalties.

(c)Qualified Default Investment Alternative.

If a Participant does not choose an investment option for any portion of the Participant’s Account, the Participant shall be deemed to have chosen the age appropriate target-date Fidelity Freedom Index Fund — Class W (“Target-Date Fund”), or such other investment fund as the PIC may direct, as the investment option applicable to the non-directed portion of the Participant’s Account. It is intended that the Target-Date Funds shall meet the requirements to be a “qualified default investment alternative,” as defined in U.S. Department of Labor (“DOL”) Regulations implementing Section 404(c)(5) of ERISA.

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(d)Section 404(c) Plan.

The Plan is intended to constitute a plan described in Section 404(c) of ERISA and the DOL Regulations thereunder. Under Section 404(c) of ERISA, fiduciaries of the Plan are relieved of liability for any losses that are the direct and necessary result of a Participant’s or Beneficiary’s exercise of control over investments in the Participant’s Account. This means that each Participant bears the risks and rewards of the Participant’s own investment decisions. Investment losses may occur based on. those decisions. Neither the Participating Employers nor their officers and directors, the PIC, the Investment Committee, the Administrative Committee, the Trustee, nor any of their representatives insure or otherwise guarantee the performance of any investment fund offered under the Plan.

(e)Company Stock

Participants and Beneficiaries may make limited investments in Company Stock as described in this Section 4.3(e) and in an amendment to the Trust Agreement.

(i)ESOP Status.

The portion of the Plan that is invested in Company Stock is an “employee stock ownership plan” (“ESOP”), as defined in Section 4975(e)(7) of the Code.

(ii)Dividend Pass-Through

Dividends paid on Company Stock shall be passed through to Participants and Beneficiaries in accordance with the Trust Agreement. Each Participant and Beneficiary who has an investment in Company Stock through the Plan may elect to have any dividends paid on Company Stock either (A) paid to the Participant or Beneficiary in cash, or (B) reinvested in Company Stock in the Plan. If a Participant or Beneficiary does not affirmatively elect to receive a dividend in cash, the Participant or Beneficiary shall be deemed to have elected reinvestment of such dividend in Company Stock in the Plan. Any payment of cash dividends to a Participant or Beneficiary shall be accounted for as if the Participant or Beneficiary receiving the dividends was a direct owner of the shares of Company Stock, and the payment shall not be treated as a Plan distribution for purposes of Article VI. In accordance with Section 404(k)(7) of the Code, dividends reinvested in Company Stock in the Plan shall be fully vested.

(iii)Real-Time Trading.

Trading in Company Stock through the Plan shall be done in accordance with the Trust Agreement, which generally provides for real-time trading of Participant or Beneficiary initiated exchanges, with batch activity for other transactions (e.g., purchases of Company Stock for Participant contributions allocated to Company Stock and sales of Company Stock to facilitate distributions and loans).

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(iv)Voting of Shares.

In accordance with the terms of the Trust Agreement, each Participant shall have the right to direct the Trustee as to the manner in which the Trustee is to vote that number of shares of Company Stock credited to the Participant’s or Beneficiary’s Account. Participant and Beneficiary ownership of Company Stock and voting by Participants and Beneficiaries with respect to Company Stock shall be kept confidential. The Trust Agreement sets forth the responsibilities of the Company and the Trustee with respect to notification to Participants and Beneficiaries of annual or special meetings, the means of communicating directions, and the voting of shares for which no direction is received by the Trustee. The Trust Agreement, as it may be amended, shall be followed by the Trustee in performing its responsibilities with respect to common stock of the Company held by the Plan.

(v)Tender Offers.

In the event of a tender offer or other situation that involves the potential for undue influence, tabulation of Participant votes shall be controlled by the Trustee in accordance with the terms of the Trust Agreement.

(vi)Section 16 Insiders.

With respect to a Participant who is subject to the provisions of Section 16 of the Securities Exchange Act of 1934 (an “Affected Participant”), the provisions of the Plan and all transactions hereunder are intended and shall be construed and applied so as to comply with all applicable requirements and conditions for exemption under Rule 16b-3 or any successor rule. In this regard, an Affected Participant’s investment election directing the investment, disposition, or reinvestment of the Participant’s Account in the Company Stock shall be structured to meet the requirements for a “discretionary transaction” under Title 17, Section 240.16b-3(f) of the Code of Federal Regulations. Specifically, the Affected Participant shall be allowed to make such investment election with respect to the acquisition or disposition of Company Stock only if such election is made on or after the date that is six (6) months following the date of the most recent investment election for an “opposite way” transaction under any employee benefit plan sponsored by a Participating Employer or Associated Company. For this purpose, an “opposite way” transaction means a previous acquisition if the current transaction is a disposition, and vice versa. However, an acquisition or disposition of Company Stock resulting from an election to receive, or defer the receipt of, Company stock or cash in connection with the death, Disability, Retirement, or termination of service of the Participant falls outside the meaning of a “discretionary transaction” under Rule 16b-3(f), and shall not be subject to, or considered in applying, the above six (6)-month election restriction.

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(vii)Change in Shares.

If the outstanding shares of common stock of the Company are decreased or exchanged for a different number or kind of shares or other securities, or if additional shares or new or different shares or other securities are distributed with respect to such shares of Company Stock or other securities through merger, consolidation, sale of all or substantially all the assets of the Company, recapitalization, reclassification, stock dividend, stock split, reverse stock split, or other distribution with respect to such shares of Company Stock or other securities, an appropriate and proportionate adjustment may be made to the maximum number and kind of shares or other securities that are subject to an effective registration statement filed with the Securities Exchange Commission pursuant to the Securities Act of 1933, as amended. Any adjustment under this paragraph shall be subject to the requirements of applicable federal and state securities laws and regulations.

(viii)Purchase and Sale of Shares.

All purchases of Company Stock by the Trustee shall be made at a price that does not exceed the fair market value of such Company Stock as of the date of purchase. All sales of Company Stock shall be at a price that is not less than the fair market value of such Company Stock as of the date of sale. In accordance with the Trust Agreement, purchases and sales of Company Stock may be made directly with the Company or on the open market. Any purchase or sale of Company Stock shall be made in conformance with Section 408(e) of ERISA, to the extent applicable.

(ix)Diversification.

Subject to Section 4.3(e)(iv) and applicable trading restrictions imposed by the PIC, the Trustee, or an investment fund, Participants are free to diversify the investments of their Accounts at all times.

(x)Limitations on Investments in the Company Stock.

There are two (2) limitations on the amount a Participant may invest in the Company Stock. First; a Participant may not direct more than twenty percent (20%) of any contribution to the Company Stock. Second, Participants and Beneficiaries are prohibited from making transfers or exchanges from other investment alternatives into the Company Stock if the transfer or exchange would cause the Participant’s or Beneficiary’s investment in the Company Stock to exceed twenty percent (20%) of the Participant’s or Beneficiary’s total Account balance. At any time, the PIC may further restrict investments in the Company Stock or eliminate the Company Stock or any other form of investment in. Company stock as an investment alternative under the Plan.

The restrictions imposed by this paragraph have not been applied to Participants and Beneficiaries who directed investment exchanges/transfers using the Trustee's

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auto-rebalance feature. Investment exchanges/transfers made in violation of these restrictions from October 17, 2008 through June 8, 2018 are grandfathered. This means that Participants and Beneficiaries who were able to make exchanges/transfers in excess of what is permitted by these restrictions will not be required to reduce their holdings in the Company Stock Fund. Effective June 8, 2018, the restrictions are re-imposed on all investment exchanges/transfers.

(xi)Satisfaction of Code Section 401(a)(35) Requirements.

Since the Plan holds publicly traded employer securities, it is an “applicable defined contribution plan,” as defined in Section 401(a)(35)(E) of the Code, and it is subject to the diversification requirements set forth in Section 401(a)(35) of the Code. Every Participant (including every Beneficiary and alternate payee who has an Account in the Plan with respect to which the Beneficiary or alternate payee is entitled to exercise the rights of a Participant) has the right to divest any investment in the Company Stock attributable to elective deferrals (as described in Section 402(g)(3)(A) of the Code), employee contributions (if any), rollover contributions, and employer nonelective contributions. There is no vesting service requirement with respect to this right to diversification for any type of contribution. Amounts divested from the Company Stock may be invested in any other investment option offered under the Plan, which shall consist of at least three (3) investment options, other than employer securities, each of which is diversified and has materially different risk and return characteristics. Periodic reasonable divestment and reinvestment opportunities shall be provided at least quarterly. Except as provided in Sections 1.401(a)(35)-1(e)(2) and (3) of the Treasury Regulations, restrictions (either direct or indirect) or conditions will not be imposed on the investment of publicly traded securities if such restrictions or conditions are not imposed on the investment of other Plan assets.

Section 4.4         General Investment Powers of the PIC

(a)General.

The PIC may authorize or direct investments in any investment permitted under ERISA and agreed to by the Trustee. The PIC may remove the authority given to Participants to direct the investments in their own Accounts, in which case the PIC or another fiduciary will be responsible for the investments in Participant Accounts.

(b)Investment Managers.

The PIC may contract with one or more investment managers for the management of all or a portion of the Plan’s assets in accordance with the requirements of ERISA. An investment manager must be registered as an investment adviser under the Investment Advisers Act of 1940 or otherwise meet the requirements of Section 3(38)(B) of ERISA, and an investment manager must acknowledge in writing that the investment manager is a fiduciary of the Plan. The PIC may remove or replace an investment manager, as the PIC deems appropriate, in accordance with the applicable investment management contract.

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(c)Company Stock and Bank Deposits.

Subject to the limitations in Sections 407 and 408 of ERISA and to any limitations or restrictions that the PIC may impose, up to one hundred percent (100%) of the assets of the Plan may be invested in common stock of the Company.

(d)Common and Collective Trust Funds.

A transaction may be made between the Plan (including a trust or insurance contract forming a part thereof) and (i) a common or collective trust fund or pooled investment fund maintained by a party in interest (as such term is defined in ERISA) that is a bank or trust company supervised by a state or federal agency or (ii) a pooled investment fund of an insurance company qualified to do business in a state, if (A) the transaction is a sale or purchase of an interest in such fund, and (B) the bank, trust company, or insurance company receives not more than reasonable compensation.

(e)81-100 Trusts.

Assets of the Plan may be invested in a group trust qualifying for exemption from tax under Section 501(a) of the Code in accordance with Revenue Ruling 81-100, as modified by Revenue Ruling 2004-67, Revenue Ruling 2011-1, and subsequent Revenue Rulings (an “81-100 Trust”). To the extent any assets of the Plan are invested in an 81-100 Trust, the provisions of the trust agreement governing the 81-100 Trust, as amended from time to time, and the trust thereby created, are hereby adopted as part of this Plan and the trust hereunder with respect to Plan assets invested therein.

Section 4.5         Plan Loans to Active Participants

A Plan loan program is available to Participants who are actively employed by a Participating Employer. Participants who are no longer actively employed by a Participating Employer may access their Accounts through distributions in accordance with the provisions of Article VI. The loan program is administered by the Trustee in accordance with procedures approved by the Administrative Committee. The loan procedures are incorporated herein by this reference and May be amended at any time without notice and without further amendment to the Plan. If there is any conflict between the loan procedures and this Section 4.5, the loan procedures shall control.

(a)Loan Sources.

Plan loans may be taken only from the following Subaccounts: Salary Reduction, Roth Basic, Employee Pre-Tax Catch-Up, Roth Catch-Up, Rollover, After-Tax Rollover, Roth Rollover, Roth In-Plan Conversion, Dividend – Fully Vested, AmeriMatch, Participant Voluntary, Rollover, and Employer ASB.

(b)Application Procedures.

A Participant wishing to obtain a loan may initiate the process with the Trustee by telephone or Internet. The Participant has thirty (30) days after initiating the loan to complete the loan

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application process. If the process is not completed within thirty (30) days, the Participant must reinitiate the process. The loan application includes a promissory note and security agreement.

(c)Maximum Loan Amount.

The maximum amount which may be borrowed by a Participant is the lesser of:

(i)Fifty Percent (50%) of the Participant’s vested Account balance, or

(ii)$50,000, reduced by the excess (if any) of:

(A)The highest outstanding balance of loans from the Plan during the one (1)-year period ending on the day before the date on which the loan is made, minus

(B)The outstanding balance of loans from the Plan on the date the loan is made.

A Participant's Roth Contribution Subaccounts and Roth In-Plan Conversion Subaccount (defined in Section 6.11.A) will be included in determining a Participant's maximum loan amount and are available sources for loans.

(d)Minimum Loan Amount.

Loans will not be permitted for less than $1,000.

(e)Repayment Terms.

Loans must be repaid within five (5) years, unless the Participant establishes that the loan proceeds are to be used to buy the Participant’s principal residence, in which case the Administrative Committee may agree to a repayment period of up to fifteen years. The principal residence exception to the five (5)-year repayment rule does not apply to loans for the improvement of a Participant’s principal residence. A Participant seeking a loan must agree to have the loan repaid by payroll deduction. If a Participant has terminated employment, or is on a leave of absence other than for Qualified Military Service and is not receiving sufficient Compensation to cover the loan payments, the Participant must make loan payments directly to the Trustee. Interest shall be paid as it accrues, with level amortization.

(f)Purposes for Which Loans May Be Granted.

A Participant may have up to two loans outstanding without restriction on the use of the loan proceeds, provided the maximum loan amount is not exceeded. Under no circumstances shall the Administrative Committee or the Trustee administer the loan program in a manner that is more favorable to Participants who are HCEs than to other Participants.

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(g)Interest Rates.

The interest rate charged for Plan loans during any calendar month shall be two percentage points above the Federal Reserve prime rate of interest as of the last working day of the month preceding the month in which the loan is made. The Administrative Committee has the authority, in its discretion, to revise the interest rate charged on Plan loans, in which event the interest rate so determined by the Administrative Committee shall apply to Plan loans made thereafter in lieu of the interest rate set forth herein.

(h)Collateral.

The loan shall be secured by fifty percent (50%) of the Participant’s vested Account balance at the time the loan is approved.

(i)Repayment Upon Distribution.

If a Participant or Beneficiary applies for or otherwise becomes entitled to an immediate distribution in accordance with Article VI of the Plan upon the Participant’s severance from employment, Retirement, Disability, or death (including the automatic distribution of a small Account balance without the Participant’s consent), the unpaid balance of any outstanding loan shall be due and payable in full immediately prior to such distribution. If repayment is not made in full prior to the distribution, the Participant’s Account shall be reduced or offset by the unpaid balance when the distribution is made. The offset amount will be part of the taxable distribution to the Participant or Beneficiary.

(j)Default.

Default will occur if the Participant fails to make a payment within ninety (90) days of when the payment was due. If there is a default, the following will occur:

•The principal amount of the loan plus interest accrued through the date of default will be a deemed distribution, subject to all applicable taxes. The Trustee will issue Internal Revenue Service Form 1099-R to the Participant, reflecting the deemed distribution.

•Although the default will be a deemed distribution, the Trustee will not reduce the Participant’s Account until a distributable event occurs under the terms of the Plan.

•The Participant will not be able to take another Plan loan until the Participant repays the balance of the defaulted loan (with interest).

(k)Leaves of Absence.

Generally, repayments must continue in a timely manner during an authorized leave of absence. However, the repayment of any Plan loan may be suspended while the Participant is on leave for Qualified Military Service, and, if requested by the Participant, the interest rate on the loan while the Participant is on leave for Qualified Military

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Service may not exceed six percent (6%). The USERRA. procedures adopted by the Administrative Committee contain rules with respect to suspension of loan payments.

(l)Self-Directed Investment.

As with all other Plan investments, a Plan loan is a self-directed investment. In accordance with Section 4.2(c), the reasonable expenses of a loan may be charged against the Participant’s Account. Interest and principal paid on a loan will be credited solely to the Participant’s Account, and any loss suffered by reason of default or otherwise will be borne solely by the Participant’s Account.

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ARTICLE V
VESTING AND FORFEITURES

    Section 5.1    Vesting

Vesting determines the portion of the Participant’s Account that the Participant is entitled to receive when a distributable event occurs, such as Retirement or other severance from employment. Any portion of a Participant’s Account that is not vested upon severance from employment shall be forfeited in accordance with the rules in Section 5.2.

(a)Immediate Vesting in All Subaccounts Other than Matching Contribution Sub accounts

Each Participant is always one hundred percent (100%) vested in all the Participant’s Subaccounts other than any Matching Contribution and Non-Elective Contribution Subaccounts.

(b)Vesting in Matching Contribution Subaccounts

(i)Termination of Employment Prior to Attainment of Normal Retirement Age.

Matching Contributions and Non-Elective Contributions, and their respective earnings are not immediately vested when made. Rather, for a Participant who terminates employment with the Participating Employers prior to the attainment of Normal Retirement Age, vesting in the Participant’s Matching Contribution and Non-Elective Contributions Subaccounts, if any, are determined under the following schedule:

Years of Vesting Service	Vested Percentage
Less than 2 Years	0%
2 Years	20%
3 Years	40%
4 Years	60%
5 Years	80%
6 or more Years	100%

(ii)Attainment of Normal Retirement Age.

If a Participant reaches Normal Retirement Age while employed by a Participating Employer or Associated Company, the Participant shall be one hundred percent (100%) vested in his or her total Account, including any Matching Contribution or Non-Elective Contribution Subaccount, regardless of the Participant’s Years of Vesting Service.

(c)Calculation of Years of Vesting. Service.

Years of Vesting Service are calculated using the elapsed time method, which is based on periods of employment.

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(i)General Rule.

Vesting service is granted for the period of time beginning on the date a Participant first (1st) performs one (1) Hour of Service for a Participating Employer or Associated Company and ending on the date the Participant severs from service with all Participating Employers and Associated Companies. A Participant “severs from service” on the earlier of (i) the date the Participant quits, Retires, is discharged, or dies, or (ii) the first anniversary of the first (1st) day of absence for any other reason (e.g., Disability, vacation, or leave of absence).

(ii)Reemployment.

If a former Participant is reemployed by a Participating Employer or Associated Company, vesting service shall be granted for the period of time beginning on the date such Participant is reemployed and ending on the date such Participant subsequently severs from service with all the Participating Employers and Associated Companies. If such Participant is reemployed within the twelve (12)-consecutive month period following the date on which the Participant severs from service, vesting service shall also be granted for the interim period.

(iii)Maternity and Paternity Absences.

If a Participant is absent from work for any period (a) by reason of pregnancy, the birth of a child, or the placement of a child in connection with the Participant’s adoption of the child or (b) for purposes of caring for such child for a period beginning immediately following such birth or adoption, the Participant shall be credited with additional vesting service equal to the lesser of such period or twelve (12) months. The severance from service date for a Participant who is absent from work beyond the first anniversary of the first (1st) day of maternity or paternity absence shall be the second anniversary of the first (1st) day of such absence. The period between the first (1st) and second (2nd) anniversaries shall not be regarded as a period of service or a period of severance.

(iv)Other Leaves of Absence.

With respect to leaves of absence other than maternity or paternity; vesting service shall be granted for:

(A)Military Leave.

The period of time spent on leave for Qualified Military Service. Generally, if a Participant on leave for Qualified Military Service does not return to covered employment within five (5) years after the completion of the Qualified Military Service, no additional vesting credit shall be granted for the period of the Qualified Military Service, However, if a Participant dies while performing Qualified Military Service, the survivors of the Participant are entitled to any additional benefits (other than benefit accruals relating to the period of Qualified Military Service) provided

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under the Plan had the Participant resumed and then terminated employment on account of death. This means that the deceased Participant’s Qualified Military Service will be credited as vesting service.

(B)Authorized Personal Leave.

Personal leave of absence authorized by a Participating Employer that is not in excess of one (1) year. In determining leaves of absence, a Participating Employer must act in a nondiscriminatory manner.

(C)Curtailment of Work.

A period of absence because of curtailment of work, not to exceed six (6) months, provided the Participant returns to employment within two (2) weeks after notification by a Participating Employer that work is available.

(v)Break-in-Service Rules

(A)One (1)-Year Break-in-Service.

Following a One (1)-Year Break in Service, a Participant’s Years of Vesting Service prior to the break will not be taken into account in determining the Participant’s vested interest in Matching Contributions and Non-Elective Contributions made after the break until such Participant has again completed one (1) Year of Vesting Service.

(B)Five (5)-Year Break-in-Service.

If a Participant incurs five (5) consecutive One (1)-Year Breaks in Service, vesting service credited subsequent to such One (1)-Year Breaks in Service shall be disregarded for purposes of determining the vesting percentage in Matching Contributions and Non-Elective Contributions made before such One (1)-Year Breaks in Service.

(d)Employment with Associated Companies.

Employment by an Associated Company shall be treated as employment by a Participating Employer for purposes of determining a Participant’s vesting service.

Section 5.2        Forfeitures

(a)Forfeiture of Matching Contributions or Non-Elective Contributions.

If a Participant terminates employment with the Participating Employers without being one hundred percent (100%) vested in his or her Matching Contribution or Non-Elective Contribution Subaccounts, the nonvested portion of the Participant’s Matching Contribution or Non-Elective Contribution Subaccounts shall be forfeited at the time the vested portion of

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the Participant’s Account is distributed or, if earlier, at the end of the period in which the Participant has incurred five (5) consecutive One (1)-Year Breaks in Service. A Participant with a zero percent (0%) vested interest in Matching Contributions or Non-Elective Contribution and the earnings thereon shall be deemed to have received a distribution of the vested portion of the Participant’s Matching Contribution or Non-Elective Contribution Subaccounts upon termination of employment, causing an immediate forfeiture of any Matching Contributions or Non-Elective Contributions and the earnings thereon credited to such Participant’s Account.

(b)Restoration of Forfeited Matching Contribution or Non-Elective Contribution Subaccounts.

Any forfeiture from a Matching Contribution or Non-Elective Contribution Subaccounts may be restored if the Participant is reemployed by a Participating Employer before the Participant incurs five (5) consecutive One (1)-Year Breaks in Service and the Participant repays the full amount of any distribution made to the Participant from the Participant’s Matching Contribution or Non-Elective Contribution Subaccounts after the Participant terminated employment. The Participant shall have five (5) years from the date of reemployment to make the necessary repayment. If the Participant makes the repayment, the exact amount forfeited shall be restored to the Participant’s Matching Contribution or Non-Elective Contribution Subaccounts, without adjustment for interest or any earnings or losses for the interim period. If the forfeiture occurred because the Participant had a zero percent (0%) vested interest in his or her Matching Contribution or Non-Elective Contribution Subaccounts, the restoration shall occur when the Participant has completed one (1) Year of Vesting Service upon return to employment with the Participating Employers. Any forfeited amounts that must be restored shall be restored first (1st) from current forfeitures from Matching Contribution or Non-Elective Contribution Subaccounts or second (2nd) from an additional contribution by the Participant’s Participating Employer.

(c)Use of Forfeitures To Pay Plan Expenses and Reduce Employer Contributions.

Forfeited Matching Contribution and Non-Elective Contribution Subaccounts that are not used to restore amounts previously forfeited under Section 5.2(b) shall be used first to pay administrative expenses in accordance with Section 4.2(c) and as Permitted under Section 404(a) of ERISA. To the extent forfeitures exceed the amount required to pay administrative expenses, the forfeitures shall be used to reduce the Participating Employers’ Matching Contributions and Non-Elective Contributions for the Plan Year in which the forfeiture occurred. If the forfeitures for a Plan Year exceed the Matching Contributions and Non-Elective Contributions for such Plan Year, the excess shall be held in a suspense account and used to reduce Matching Contributions and Non-Elective Contributions in succeeding years.

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ARTICLE VI
PAYMENT OF VESTED BENEFITS

Section 6.1         Severance from Employment

A Participant may apply for and receive a distribution of the Participant’s vested Account balance (determined as of the most recent valuation date preceding the distribution and reduced for any outstanding Plan loan) as soon as administratively feasible following the Participant’s severance from employment.

Section 6.2         Small Account Balances

If a Participant’s vested Account balance is $1,000 or less (determined without regard to source), the Participant’s vested Account balance shall be distributed to the Participant in a single sum as soon as administratively practicable following the Participant’s severance from employment. No consent of the Participant or Participant’s spouse is required for this involuntary cashout to be made. If a Participant’s vested Account balance is more than $1,000 but less than or equal to $5,000 and if the Participant does not elect to have the Participant’s Account balance rolled over in a direct rollover or distributed to the Participant, the Participant’s Account balance shall automatically be rolled over into an individual retirement account designated by the Administrative Committee. If a Participant’s vested Account balance exceeds $5,000 (disregarding any amounts attributable to Rollover Contributions), no distribution may be made to the Participant before the Participant reaches Normal Retirement Age without the consent of the Participant.

Section 6.3         Statutory Commencement Date

Benefits must commence no later than the sixtieth (60th) day after the close of the Plan Year in which the latest of the following occurs:

(a)The Participant reaches Normal Retirement Age;

(b)The Participant reaches the tenth anniversary of the year in which the Participant commenced participation in the Plan; or

(c)The Participant severs employment.

Notwithstanding the foregoing, subject to Section 6.8, a Participant must make a claim for benefits and complete the proper distribution processes before benefits will commence under this Section 6.3.

Section 6.4         Forms of Benefit Following Severance from Employment

The forms of benefit available to Participants following severance from employment are:

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(a)A single sum (also known as a lump sum) payable as soon as administratively feasible following completion of all applicable distribution forms;

(b)An installment option with respect to HEISOP Sub accounts only, as described in Section 6.5;

(c)Periodic payments of required minimum distributions only, as described in Section 6.6; and

(d)A partial withdrawal of the Participant’s vested Account balance (reduced by any outstanding loan balance) as elected by the Participant. A Participant may elect a partial withdrawal no more than once in any Plan Year.

All distributions shall be in cash, except that a Participant’s investment in Company Stock shall be distributed to the Participant in whole shares of Company Stock. However, a Participant may elect to receive cash in lieu of Company Stock (and shall be deemed to have made such an election with respect to any automatic distribution of $5,000 or less, in accordance with Section 6.2, unless the Participant affirmatively elects to receive the distribution in the form of Company Stock before the automatic distribution is made). No fractional shares shall be issued; the value of any fractional share of stock shall be paid in cash.

Materials explaining the available forms of benefit and the benefit election procedures will be provided to Participants upon termination of employment, and a Participant may make a benefit election on the Trustee’s website or by contacting the Trustee by telephone. The materials shall describe the Participant’s right to defer distribution until the Participant’s Normal Retirement Date and the consequences of failing to defer the distribution. Distribution materials shall be provided to the Participant no less than thirty (30) days and no more than one hundred eighty (180) days before the distribution commences; provided, however, that the distribution may commence less than thirty (30) days after the distribution materials are provided to the Participant if the materials clearly inform the Participant that the Participant has the right to a period of at least thirty (30) days after receiving the materials to consider the decision of whether or not to elect a distribution (and, if applicable, a particular distribution option) and, after receiving the materials, the Participant affirmatively elects a distribution.

Section 6.5         Installment Option for HEISOP Subaccounts

Unless the Participant elects otherwise, the portion of the Participant’s HEISOP Subaccounts, if any, invested in the Company Stock shall be distributed in substantially equal periodic payments (not less frequently than annually) over a period not longer than the greater of:

(a)Five (5) years, or

(b)In the case of a Participant with investments in the Company Stock in excess of $1,230,000, five (5) years plus one (1) additional year (but no more than five (5) additional years) for each $245,000 or fraction thereof by which such balance exceeds $1,230,000. The $1,230,000 and $245,000 amounts are subject to increase with the cost of living after 2022 in accordance with Section 409(o)(2) of the Code.

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Section 6.6         Periodic Payments of Minimum Distributions

A Participant may request that his or her vested Account balance be distributed in the form of periodic payments of required minimum distributions only, commencing on. the Participant’s required beginning date and continuing until the Participant’s Account has been fully distributed to the Participant in accordance with this Section 6.6 or to the Participant’s Beneficiary in accordance with Section 6.7, and determined and paid in accordance with Section 6.8. A Participant who has elected to receive periodic payments of required minimum distributions may elect to receive a single-sum distribution of his or her remaining vested Account balance (reduced by any outstanding loan balance) at any time. “Required beginning date” is defined in Section 6.8(h)(v).

Section 6.7         Death Benefits

If a Participant dies prior to distribution of the Participant’s total vested Account balance, such Participant’s designated Beneficiary shall be entitled to receive the Participant’s remaining vested Account balance (reduced by any outstanding loans) as a death benefit. Death benefits may be paid as soon as administratively feasible following the Participant’s death and must be made by the end of the year which contains the fifth anniversary of the Participant’s death. Death benefits shall be paid in a single sum distribution, except that (a) to the extent, if any, that required minimum distributions are required to be made to the Beneficiary between the date of the Participant’s death and the time at which the remaining Account balance is required to be distributed pursuant to the preceding sentence (or, if earlier, the date the Beneficiary elects to receive a single sum distribution), such required minimum distributions shall be made in accordance with Section 6.8; and (b) subject to Section 6.8, the Beneficiary may elect (or, if distributions to the Participant previously commenced, may continue to receive) installment payments with respect to HEISOP Subaccounts only, as described in Section 6.5.

A Participant’s Beneficiary shall be the person or legal entity designated by the Participant in accordance with procedures approved by the Administrative Committee, provided that a married Participant’s spouse shall automatically be his or her Beneficiary unless the spouse has consented to an alternate Beneficiary. The spouse’s signature on the consent form must be notarized or witnessed by an authorized Plan representative. Spousal consent shall not be required if it is established to the satisfaction of the Administrative Committee that such consent may not be obtained because there is no spouse, because the spouse cannot be located, or because of such other circumstances as the Treasury Regulations may prescribe.

Subject to the rights of a married Participant’s spouse, a Participant may revoke or change designation of the Participant’s Beneficiary at any time in accordance with procedures approved by the Administrative Committee. Whenever a Participant designates a new Beneficiary, all former Beneficiary designations by such Participant shall be revoked automatically. If, upon the death of a Participant, there is no valid Beneficiary designation on file with the Administrative Committee or third-party record keeper or the Beneficiary has predeceased the Participant, the Beneficiary of the Participant’s vested Account balance shall be, in order of priority:

(a)The Participant’s surviving spouse, if any;

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(b)The estate of the deceased Participant.

Facts as shown by the records of the Plan at the time of the Participant’s death shall be conclusive as to the identity of the proper Beneficiary. If a Participant and the Participant’s spouse divorce, any designation of the spouse as Beneficiary shall automatically become null and void. The former spouse shall be treated as the Beneficiary under this Plan only if after the divorce the Participant expressly redesignates the former spouse as the Participant’s Beneficiary.

Section 6.8        Required Minimum Distributions

The provisions of this Section 6.8 shall apply for purposes of determining required minimum distributions.

(a)Precedence.

The requirements of this Section 6.8 shall take precedence over any inconsistent provisions of the Plan, provided that this Section 6.8 shall not be read to create a form of distribution that is not otherwise available under this Article VI.

(b)Requirements of Treasury Regulations Incorporated.

All distributions required under this Section 6.8 shall be determined and made in accordance with the Treasury Regulations under Section 401(a)(9) of the Code, which are incorporated herein by this reference.

(c)Time and Manner of Distribution

(i)Required Beginning Date.

The Participant’s entire interest must be distributed, or begin to be distributed, no later than the Participant’s required beginning date.

(ii)Death of Participant Before Distributions Begin.

If the Participant dies before distributions begin, the Participant’s entire interest will be distributed to the Participant’s Beneficiary by December 31 of the calendar year containing the fifth anniversary of the Participant’s death.

(d)Forms of Distribution.

Distributions shall be made in accordance with Sections 6.8(e) and (f).

(e)Required Minimum Distributions During Participant’s Lifetime

(i)Amount of Required Minimum Distribution for Each Distribution Calendar Year.

During the Participant’s lifetime, the minimum amount distributed for each distribution calendar year shall be the lesser of:

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(A)The quotient obtained by dividing the Participant’s Account balance by the distribution period in the Uniform Lifetime Table set forth in Section 1.401(a)(9)-9, Q&A-2, of the Treasury Regulations, using the Participant’s age as of the Participant’s birthday in the distribution calendar year; or

(B)If the Participant’s sole designated Beneficiary for the distribution calendar year is the Participant’s spouse, the quotient obtained by dividing the Participant’s Account balance by the number in the Joint and Last Survivor Table set forth in Section 1.401(a)(9)-9, Q&A-3, of the Treasury Regulations, using the Participant’s and spouse’s attained ages as of the Participant’s and spouse’s birthdays in the distribution calendar year.

(ii)Lifetime Required Minimum Distributions Continue Through Year of Participant’s Death.

Required minimum distributions shall be determined under this Section 6.8(e) beginning with the first distribution calendar year and up to and including the distribution calendar year that includes the Participant’s date of death.

(f)Required Minimum Distributions After Participant’s Death

(i)Death On or After the Date Distributions Begin

(A)Participant Survived by Designated Beneficiary.

If the Participant dies on or after the date distributions begin and there is a designated Beneficiary, the minimum amount that must be distributed for each distribution calendar year after the year of the Participant’s death is the quotient obtained by dividing the Participant’s Account balance by the longer of the remaining life expectancy of the Participant or the remaining life expectancy of the Participant’s designated Beneficiary, determined as follows:

(1)The Participant’s remaining life expectancy is calculated using the age of the Participant in the year of death, reduced by one for each subsequent year.

(2)If the Participant’s surviving spouse is the Participant’s sole designated Beneficiary, the remaining life expectancy of the surviving spouse is calculated for each distribution calendar year after the year of the Participant’s death using the surviving spouse’s age as of the spouse’s birthday in that year. For distribution calendar years after the year of the surviving spouse’s death, the remaining life expectancy of the surviving spouse is calculated using the age of the surviving spouse as of the spouse’s birthday in the calendar year of the

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spouse’s death, reduced by one for each subsequent calendar year.

(3)If the Participant’s surviving spouse is not the Participant’s sole designated Beneficiary, the designated Beneficiary’s remaining life expectancy is calculated using the age of the Beneficiary in the year following the year of the Participant’s death, reduced by one for each subsequent year.

(B)No Designated Beneficiary.

If the Participant dies on or after the date distributions begin and there is no designated Beneficiary as of September 30 of the year after the year of the Participant’s death, the minimum amount that shall be distributed for each distribution calendar year after the year of the Participant’s death is the quotient obtained by dividing the Participant’s Account balance by the Participant’s remaining life expectancy calculated using the age of the Participant in the year of death, reduced by one for each subsequent year.

(ii)Death Before Date Distributions Begin

(A)General Rule.

If the Participant dies before the date distributions begin, the minimum amount that shall be distributed for each distribution calendar year after the year of the Participant’s death is the quotient obtained by dividing the Participant’s Account balance by the remaining life expectancy of the Participant’s designated Beneficiary, determined as provided in Section 6.8(f)(i).

(B)No Designated Beneficiary.

If the Participant dies before the date distributions begin and there is no designated Beneficiary as of September 30 of the year following the year of the Participant’s death, distribution of the Participant’s entire interest shall be completed by December 31 of the calendar year containing the fifth anniversary of the Participant’s death.

(C)Death of Surviving Spouse Before Distributions to Surviving Spouse Are Required to Begin.

If the Participant dies before the date distributions begin, the Participant’s surviving spouse is the Participant’s sole designated Beneficiary, and the surviving spouse dies before distributions are required to begin to the surviving spouse under Section 6.8(c)(ii), this Section 6.8(f)(ii) shall apply as if the surviving spouse were the Participant.

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(g)Full Distribution Required by End of Fifth Year After Death.

This Section 6.8 establishes the minimum amount that must be distributed for each distribution calendar year after the year of the Participant’s death, but it shall not be read to permit any Beneficiary to retain an Account in the Plan after the date on which distribution is required under Section 6.7.

(h)Definitions.

The following definitions supplement the definitions in other parts of the Plan, in particular Article XII.

(i)Designated Beneficiary.

The “designated Beneficiary” is the individual who is designated as the Beneficiary in accordance with Section 6.7 of the Plan and is the designated Beneficiary under Section 401(a)(9) of the Code and Section 1.401(a)(9)-4 of the Treasury Regulations. Section 1.401(a)(9)-4, Q&A-5 permits the designation of a trust as Beneficiary provided the requirements of the cited Section are met. Under Section 6.7 of the Plan, spousal consent is required for a married Participant to designate a trust or any other person or entity other than the Participant’s surviving spouse as Beneficiary.

(ii)Distribution Calendar Year.

A “distribution calendar year” is a calendar year for which a minimum distribution is required. For distributions beginning before the Participant’s death, the first distribution calendar year is the calendar year immediately preceding the calendar year that contains the Participant’s required beginning date. For distributions beginning after the Participant’s death, the first distribution calendar year is the calendar year in which distributions are required to begin under Section 6.8(c)(ii). The required minimum distribution for the Participant’s first distribution calendar year shall be made on or before the Participant’s required beginning date. The required minimum distribution for other distribution calendar years, including the required minimum distribution for the distribution calendar year in which the Participant’s required beginning date occurs, shall be made on or before December 31 of that distribution calendar year.

(iii)Life Expectancy.

“Life expectancy” means life expectancy as computed by use of the Single Life Table in Section 1.401(a)(9)-9, Q&A-1, of the Treasury Regulations.

(iv)Participant’s Account Balance.

A “Participant’s Account balance” is the total balance of a Participant’s Account as of the last valuation date in the calendar year immediately preceding the distribution calendar year (the “valuation calendar year”) increased by the amount

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of any contributions made and allocated or forfeitures allocated to the Participant’s Account as of dates in the valuation calendar year after the valuation date and decreased by distributions made in the valuation calendar year after the valuation date. The Account balance for the valuation calendar year includes any amounts rolled over or transferred to the Plan either in the valuation calendar year or in the distribution calendar year if distributed or transferred in the valuation calendar year.

(v)Required Beginning Date.

“Required beginning date” means the following:

(A)Five Percent (5%) Owners.

The “required beginning date” for a Participant who was a five percent (5%) owner at any time during the Plan Year (calendar year) in which the Participant attains age seventy-two (72) shall be April 1st of the calendar year following the calendar year in which the Participant attains age seventy-two (72). In the case of a Participant who becomes a five percent (5%) owner during any subsequent Plan Year, the required beginning date shall be the April 1st of the calendar year following the calendar year in which such subsequent Plan Year ends. Once distributions begin to a five percent (5%) owner because they are required to begin under this Section 6.8, they must continue even if the Participant ceases to be a five percent (5%) owner in a subsequent calendar year.

(B)Other Participants.

The “required beginning date” for a Participant who is not a five percent (5%) owner shall be April 1st of the calendar year following the later of the calendar year in which the Participant attains age seventy-two (72) or the calendar year in which the Participant Retires. Every Participant other than a five percent (5%) owner who reaches age seventy-two (72) while actively employed by a Participating Employer may elect (1) to commence receiving benefits on April 1st following the calendar year in which the Participant attains age seventy-two (72) or (2) to defer the commencement of benefits to a date no later than April 1st following the calendar year in which the Participant Retires.

(C)Five Percent (5%) Owner.

A “five percent (5%) owner” is any person who owns (or is considered to own. under the attribution rules in Section 318 of the Code) more than five percent (5%) of the outstanding stock of the Company or stock possessing more than five percent (5%) of the total combined voting power of the Company.

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(vi)Suspension of Required Minimum Distributions for 2009.

Notwithstanding the foregoing provisions of this Section 6.8, a Participant or Beneficiary who would have been required to receive required minimum distributions for 2009 but for the enactment of Section 401(a)(9)(H) of the Code (“2009 RMDs”), and who would have satisfied that requirement by receiving distributions that are (A) equal to the 2009 RMDs or (B) one or more payments in a series of substantially equal distributions (that include the 2009 RMDs) made at least annually and expected to last for the life (or life expectancy) of the Participant, the joint lives (or joint life expectancy) of the Participant and the Participant’s designated Beneficiary, or for a period of at least 10 years (“Extended 2009 RMDs”), will not receive those distributions for 2009 unless the Participant or Beneficiary chooses to receive such distributions. Participants and Beneficiaries described in the preceding sentence will be given the opportunity to elect to receive the distributions described in the preceding sentence. In addition, notwithstanding Section 6.11 of the Plan, and solely for purposes of applying the direct rollover provisions of the Plan, 2009 RMDs and Extended 2009 RMDs will be treated as eligible rollover distributions.

Section 6.9        In-Service Withdrawals

(a)Withdrawals from Participant Voluntary, Voluntary HEISOP, After-Tax Rollover, Roth Rollover, Roth In-Plan Conversion, Dividend – Fully Vested, and IRA Subaccounts.

A Participant may at any time request (in accordance with procedures approved by the Administrative Committee) a withdrawal from the following Subaccounts: Participant Voluntary, Voluntary HEISOP, After-Tax Rollover, Roth Rollover, Roth In-Plan Conversion, Dividend – Fully Vested, and IRA. Any withdrawal will be processed as soon as administratively practicable after the request is made.

(b)Withdrawals for Participants Who Have Reached Age Fifty-Nine and a Half (59 1/2).

A Participant who has attained age fifty-nine and a half (59 1/2) may at any time request (in accordance with procedures approved by the Administrative Committee) a withdrawal of all or any part of the Participant’s vested Account balance (reduced by any outstanding loan balance), except that in-service withdrawals are not permitted from Matching Contribution or Non-Elective Contribution Subaccounts. Only one such withdrawal shall be permitted for any Plan Year. Any withdrawal will be processed as soon as administratively practicable after the request is made.

(c)Hardship Withdrawals

(i)Available Sources.

Hardship withdrawals may be made from the Participant’s vested interest in the following Subaccounts only: Salary Reduction, Participant Voluntary, AmeriShare, Rollover, After-Tax Rollover, Roth Basic, Employee Pre-Tax Catch-

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up, Roth Catch-Up, AmeriMatch, Employer ASB, Employer BIA, HEI Diversified Plan, Voluntary HEISOP, and Employer HEISOP.

(ii)Procedures.

To qualify for a hardship withdrawal, a Participant must demonstrate (in accordance with procedures approved by the Administrative Committee) that the Participant has an “immediate and heavy financial need” and that the distribution is necessary to satisfy the immediate and heavy financial need.

(iii)Immediate and Heavy Financial Need.

A Participant shall be deemed to have an immediate and heavy financial need in connection with:

(A)Burial or funeral expenses for the Participant’s deceased parent, spouse, child, dependent (as defined in Section 152 of the Code without regard to subsection 152(d)(1)(B)), or designated Beneficiary.

(B)Expenses for (or necessary to obtain) medical care that would be deductible under Section 213(d) of the Code, determined without regard to the limitations in Section 213(a) of the Code (relating to the applicable percentage of adjusted gross income and the recipients of the medical care) provided that, if the recipient of the medical care is not listed in Section 213(a) of the Code, the recipient is a primary Beneficiary under the Plan.

(C)Costs directly related to the purchase of the Participant’s principal residence (excluding mortgage payments).

(D)Payment of tuition, related educational fees, and room and board expenses for up to the next twelve (12) months of post-secondary education for the Participant or the Participant’s spouse, child, dependent (as defined in Code Section 152 without regard to Section 152(b)(1), (b)(2), and (d)(1)(B)), or for a primary Beneficiary under the Plan.

(E)Payments necessary to prevent the eviction of the Participant from the Participant’s principal residence or foreclosure on the mortgage of the Participant’s principal residence.

(F)Expenses for the repair of damage to the Participant’s principal residence that would qualify for the casualty deduction under Section 165 of the Code (determined without regard to Section 165(h)(5) and whether the loss exceeds ten percent (10%) of adjusted gross income).

(G)Expenses and losses (including loss of income) incurred by the Participant on account of a disaster declared by the Federal Emergency Management Agency (“FEMA”) under the Robert T. Stafford Disaster Relief and

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Emergency Assistance Act, Public Law 100-707, provided that the Participant’s principal residence or principal place of employment at the time of the disaster was located in an area designated by FEMA for individual assistance with respect to the disaster.

A “primary Beneficiary under the Plan” is an individual who is named as a Beneficiary under the Plan and has an unconditional right, upon the death of the Participant, to all or a portion of the Participant’s Account balance under the Plan.

(iv)Withdrawal May Not Exceed Amount of Need.

The amount of any hardship withdrawal may not exceed the amount necessary to relieve the immediate and heavy financial need. The withdrawal may include the amount necessary to pay any federal, state, or local taxes or penalties reasonably anticipated to result from the withdrawal.

(v)No Alternative Means Reasonably Available.

A distribution shall not be treated as necessary to satisfy an immediate and heavy financial need of a Participant unless each of the following requirements is satisfied.

(A)The Participant has obtained all other currently available distributions (including distributions of ESOP dividends under Section 404(k) of the Code, but not hardship distributions) under the Plan and all other plans of deferred compensation, whether qualified or nonqualified, maintained by a Participating Employer;

(B)The Participant has provided to the Plan Administrator a representation in writing (including by using an electronic medium as defined in Treasury Regulations Section 1.401(a)-21(e)(3)), or in such other form as may be prescribed by the Commissioner of Internal Revenue, that he or she has insufficient cash or other liquid assets reasonably available to satisfy the need; and

(C)The Plan Administrator does not have actual knowledge that is contrary to the Participant’s representation.

Section 6.10     Qualified Domestic Relations Orders

(a)General.

Through a Qualified Domestic Relations Order (“QDRO”), a Participant’s spouse, child, or other tax dependent (each, an “alternate payee”) may obtain rights to the Participant’s benefits. A QDRO is a domestic relations order which assigns to an alternate payee or recognizes an alternate payee’s right to receive all or a portion of the benefits payable with respect to a Participant under the Plan. A domestic relations order is not a QDRO and shall

53

not be honored by the Administrative Committee if it requires the Plan to provide any form of benefit or other option of any kind not otherwise available under the Plan or requires the Plan to pay benefits in excess of the Participant’s vested Account balance. The one exception to this rule is that, in accordance with a domestic relations order that the Administrative Committee or a court of competent jurisdiction determines to be a QDRO, the Administrative Committee may direct that a single-sum distribution be made to the alternate payee as soon as practicable notwithstanding age, employment status, or any other factor that might prevent the Participant from receiving a distribution from his or her Account at the same time.

(b)DRO Requirements.

To be a QDRO, a domestic relations order must clearly specify (a) the name and last known mailing address of the Participant (unless otherwise known by the Administrative Committee) and the name and mailing address of the alternate payee, (b) the amount or percentage of the Participant’s benefits to be paid by the Plan to each alternate payee or the manner in which such amount is to be determined, and (c) the form in which the benefit is to be paid. The domestic relations order must specifically designate the Plan as the Plan from which the benefits are to be paid. Finally, a domestic relations order cannot require the payment of benefits to an. alternate payee that are required to be paid to another alternate payee under a previous QDRO.

(c)Procedures.

The Administrative Committee has established procedures for determining whether a domestic relations order is a QDRO and for notifying the Participant and the alternate payee(s) of the receipt of the domestic relations order and of the steps that will be taken to determine whether the order is a QDRO. The procedures are incorporated herein by this reference and may be amended at any time without notice and without further amendment to the Plan.

(d)Separate Accounting.

If the Administrative Committee determines that a domestic relations order is a QDRO, the Administrative Committee will honor the QDRO. If the QDRO does not direct an immediate distribution as permitted by this Section 6.10, the Administrative Committee will direct the Trustee to establish a separate Account in the Plan for the alternate payee, and the alternate payee shall have all rights afforded under the Plan to Beneficiaries. Primarily, this means the alternate payee will be able to direct the investment of his or her Account in accordance with the rules in Article IV, but the alternate payee will not be able to borrow from his or her Account.

Section 6.11     Eligible Rollover Distributions

A “Distributee” who is entitled to a distribution may elect, in accordance with procedures approved by the Administrative Committee, to have any portion of an “Eligible Rollover Distribution” paid directly in a “Direct Rollover” to an “Eligible Retirement Plan”.

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(a)Definitions.

For purposes of this Section 6.11, the following definitions apply:

(i)“Eligible Rollover Distribution” means any distribution of all or any portion of a Participant’s Account, except that an Eligible Rollover Distribution shall not include:

(A)Any distribution that is one of a series of substantially equal periodic payments made no less frequently than annually for the life (or life expectancy) of the Distributee or the joint lives (or joint life expectancies) of the Distributee and the Distributee’s beneficiary, or for a specified period of ten years or more;

(B)Any distribution to the extent such distribution is required under Section 401(a)(9) of the Code;

(C)Any hardship withdrawal; and

(D)Any distributions during a calendar year that are reasonably expected to total less than $200.

A portion of a distribution shall not fail to be an Eligible Rollover Distribution merely because the portion consists of after-tax employee contributions that are not includible in gross income. However, such portion may be transferred only to an individual retirement account or annuity described in Section 408(a) or (b) of the Code or to a qualified trust (defined contribution or defined benefit) or 403(b) annuity contract, provided the qualified trust or annuity contract agrees to separately account for amounts so transferred (and the earnings thereon), including separately accounting for the portion of such distribution that is includible in gross income and the portion that is not so includible.

(ii)“Eligible Retirement Plan” means any of the following accounts or plans to the extent it accepts the Distributee’s Eligible Rollover Distribution:

(A)A qualified retirement plan described in Code Section 401(a);

(B)An individual retirement account described in Code Section 408(a);

(C)An individual retirement annuity described in Code Section 408(b) (other than an. endowment contract);

(D)An annuity plan described in Code Section 403(a);

(E)An annuity contract described in Code Section 403(b); or

(F)An eligible deferred compensation plan under Code Section 457(b) that is maintained by a state, a political subdivision of a state, or any agency or

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instrumentality of a state or political subdivision of a state, and that agrees to separately account for amounts transferred into such plan from this Plan.

(iii)A “Distributee” includes a Participant, the surviving spouse of a deceased Participant, and the current or former spouse of a Participant who is an alternate payee under a QDRO that has been approved by the Administrative Committee. “Distributee” also includes a non-spouse Beneficiary of a deceased Participant. However, a non-spouse Beneficiary may make a direct rollover only to an individual retirement account described in section 408(a) of the Code or an individual retirement annuity described in section 408(b) of the Code (including a Roth IRA) that is established on behalf of the non-spouse Beneficiary and that will be treated as an inherited IRA pursuant to the provisions of section 402(c)(11) of the Code.

(iv)A “Direct Rollover” is a direct payment of an Eligible Rollover Distribution by any reasonable means from the Trustee of this Plan to the trustee, custodian, or annuity provider of the Eligible Retirement Plan specified by the Distributee.

(v)A Distributee may do a Direct Rollover to a Roth IRA if the Distributee meets the requirements that apply to rollovers from a traditional IRA to a Roth IRA.

(b)Notice.

Prior to a distribution to a Distributee, the Plan Administrator or third party service provider shall provide the Distributee a notice describing the Distributee’s right to have lump-sum distributions rolled over in a Direct Rollover to an Eligible Retirement Plan and describing certain tax consequences that will follow if a Direct Rollover is not made (the “402(f) Notice”). The Plan Administrator or third party service provider shall issue the 402(f) Notice at least thirty (30) days but no more than one hundred eighty (180) days prior to the date a distribution is made. However, such Eligible Rollover Distribution may commence less than thirty (30) days after the notice is given provided that the 402(f) Notice clearly informs the Distributee that the Distributee has the right to a period of at least thirty (30) days after receiving the notice to consider the decision of whether or not to elect a Direct Rollover and the Distributee, after receiving the notice, affirmatively elects a distribution.

(c)Income Tax Withholding.

Any taxable amount that is an Eligible Rollover Distribution but that the Distributee chooses not to have directly rolled over is subject to twenty percent (20%) income tax withholding. This includes distributions that the Distributee intends to roll over in a traditional sixty (60)-day rollover transaction.

(d)Special Rules for Direct Rollovers from Roth Contribution Subaccounts.

For purposes of applying this Section 6.11 to Roth Contribution Subaccounts, the following special rules shall apply:

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(i)The $200 threshold for Eligible Rollover Distributions in Section 6.11(a)(i)(D) shall be applied separately to a Participant's Roth Contribution Subaccounts and to the remainder of a Participant's Account.

(ii)A Direct Rollover from a Roth Contribution Subaccount may be made only to a Roth IRA (a Roth individual retirement account or Roth individual retirement annuity) or a designated Roth account in (A) a qualified retirement plan described in Code Section 401(a), (B) an annuity contract described in Code Section 403(b), or (C) an eligible deferred compensation plan under Code Section 457(b) that is maintained by a state, a political subdivision of a state, or any agency or instrumentality of a state or political subdivision of a state, that will accept the Direct Rollover.

(iii)The Plan Administrator shall provide a 402(f) Notice that describes rollover rights with respect to the Participant's Roth Contribution Subaccount.

Section 6.11.A        Roth In-Plan Conversions

After a Participant has had a distributable event (e.g., attainment of age fifty-nine and a half (59 1/2) or severance from employment), the Participant may make a direct rollover of the vested portion of any Subaccount (other than a Roth Contribution Subaccount) to a separate account established by the Trustee (a “Roth In-Plan Conversion Subaccount”). The direct rollover will be subject to income tax at the time of rollover to the same extent as a direct rollover outside of the Plan to a Roth IRA. A Roth in-Plan conversion is permitted only for active and terminated, vested Participants and only with respect to an amount that would be an Eligible Rollover Distribution, as defined in Section 6.11(a)(i) above, if it were distributed or rolled over outside of the Plan. Surviving spouses, other Beneficiaries, and alternate payees may not make Roth in-Plan conversions. If a Participant has an outstanding Plan loan, the loan balance is not eligible for Roth in-Plan conversion. Before a Participant makes a Roth in-Plan conversion, the Plan Administrator shall provide the Participant with a 402(f) Notice that describes the tax effects of a Roth in-Plan conversion. An election to make a Roth in-Plan conversion is irrevocable once the direct rollover has been made. Roth In-Plan Conversion Subaccounts are subject to the same distribution and withdrawal rules and restrictions as Roth Contribution Subaccounts.

Section 6.12     Special Rules for Participants Called to Military Service

(a)HEART Act Requirement (Effective January 1, 2009).

A Participant who is performing Qualified Military Service while on active duty for a period of more than thirty (30) days shall be treated as having been severed from employment. This permits a Participant to take a distribution from his or her vested Account balance.

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(b)Pension Protection Act Requirements as Extended by the HEART Act (Effective January 1, 2010)

(i)Permissible Withdrawals of Salary Reduction Contributions.

If a Participant is (by reason of being a member of a reserve component (as defined in Section 101 of Title 37 of the United States Code) ordered or called to active duty for a period in excess of one hundred and seventy-nine (179) days or for an indefinite period, the Participant may request a withdrawal from the Participant’s Salary Reduction and Employee Pre-Tax Catch-up Subaccounts during the period beginning on the date of the order or call to active duty and ending at the close of the active duty period.

(ii)Relief from Early Distribution Penalty Tax.

Any withdrawal under Section 6.12(b)(i) is exempt from the early distribution penalty tax under Section 72(t) of the Code in accordance with Section 72(t)(2)(G). (A distribution under Section 6.12(a) qualifies for this relief only if the distribution meets the requirements of Section 6.12(b)(i).)

(iii)Repayment Possibility.

Any Participant who receives a withdrawal under Section 6.12(b)(i) may, at any time during the two (2)-year period beginning on the day after the end of the active duty period, make one or more contributions to an individual retirement plan of such Participant in an aggregate amount not to exceed the amount of such distribution. The dollar limitations otherwise applicable to contributions to individual retirement plans shall not apply to any contributions made pursuant to the preceding sentence. No deductions shall be allowed for any contributions made to an individual retirement plan pursuant to this paragraph.

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ARTICLE VII
ADMINISTRATION

Section 7.1         PIC, Administrative Committee, and Investment Committee

(a)PIC.

The PIC has plenary authority to oversee the administration of the Plan and the investment options offered under the Plan. At its discretion, the Compensation Committee may appoint, remove, and replace members of the PIC.

(b)Administrative Committee.

The PIC has established the Administrative Committee and authorized it to oversee the day-to-day administration of the Plan. The Administrative Committee is authorized, in its discretion, to: (i) interpret and construe the provisions of the Plan; (ii) resolve any ambiguities and reconcile any inconsistencies in the provisions of the Plan; and (iii) monitor the performance of third-party administrators, including the administrative performance of the Trustee. Subject to the Claims Procedures in Article VIII, the Administrative Committee shall determine, in its discretion, all questions with respect to any individual’s rights under the Plan, including, but not limited to, eligibility for participation and eligibility for and the amount of benefits payable from the Plan. The Administrative Committee is specifically authorized to recover the overpayment of any benefits from the Plan and to institute legal proceedings, if necessary, to recover an overpayment.

(c)Investment Committee.

The PIC has established the Investment Committee and authorized it to oversee the day-to-day financial affairs of the Plan. The Investment Committee is authorized to: (i) monitor the investment options offered under the Plan and the investment policy statement for the Plan; (ii) monitor the financial performance and reporting of the Trustee; (iii) maintain or cause to be maintained proper financial records for the Plan; and (iv) file or cause to be filed all reports and other filings required by the United States Securities and Exchange Commission with respect to the Plan.

(d)Rules and Procedures.

The PIC, Administrative Committee, and Investment Committee may promulgate and publish such rules and procedures as each deems appropriate for its own actions and for the operation, administration, and investments of the Plan. A member of the PIC, Administrative Committee, or Investment Committee shall not have the right to vote on any matter relating solely to his or her own interests in the Plan, but may vote on matters affecting a class or group of Participants of which the member is a part.

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(e)Consents and Elections.

All consents, elections, applications, designations, and other submissions required or permitted under the Plan must be made in accordance with procedures approved by the Administrative Committee, and shall be valid only if properly completed, executed, and returned to the Administrative Committee or a third party service provider appointed by the Company, the PIC, or the Administrative Committee.

(f)Delegation of Authority.

The PIC, Administrative Committee, and Investment Committee may delegate any of their powers and duties to any person or group of persons, for example, to one or more officers or employees of the Company or another Participating Employer.

(g)Professional Assistance.

The PIC, Administrative Committee, and Investment Committee may employ attorneys, actuaries, accountants, investment consultants, and other service providers, as appropriate, to give counsel to or otherwise assist them in performing their duties hereunder. The fees and expenses of such persons may be paid in accordance with Section 4.2(e).

(h)General.

The PIC, Administrative Committee, and Investment Committee shall have all other powers granted to them in other sections of this document or their governing charters. At its discretion, the PIC may remove or replace the members of the Administrative Committee and Investment Committee and may revoke, amend, or enlarge the authority of the Administrative Committee and Investment Committee. The decisions of the PIC, Administrative Committee, and Investment Committee on any matters within their jurisdiction shall be binding and conclusive upon the Participating Employers and upon each Participant, Beneficiary, and other interested party.

Section 7.2         Plan Administrator

The Company shall be the Plan “Administrator,” as defined in Section 3(16)(A) of ERISA.

(a)Reporting and Disclosure.

The Company shall be responsible for filing with governmental authorities and disclosing to Participants and their Beneficiaries all returns, reports, and other materials required under ERISA or the Code.

(b)Legal Process,

The Company shall be the Plan’s agent for the service of legal process.

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Section 7.3         Trust Agreement

The Company has entered into a Trust Agreement with the Trustee for the investment and custody of Plan assets. The Trust Agreement is a master trust agreement for the custody and investment of assets for this Plan and the American Savings Bank 401(k) Plan, with separate accounting for the two plans. The trust established under the Trust Agreement is part of this Plan, and any rights or benefits accruing to any person under this Plan shall be subject to all of the relevant terms of the Trust Agreement. In addition to the powers of the Trustee set forth in the Trust Agreement, the Trustee shall have any powers, express or implied, granted to it under the Plan. In the event of any conflict between the provisions of the Trust Agreement and the provisions of the Plan, the provisions of the Plan shall control, except in matters concerning the duties and responsibilities of the Trustee, in which case the Trust Agreement shall control. The fees and expenses of the Trustee shall be paid in accordance with the Trust Agreement and Section 4.2(c) hereunder.

Section 7.4         Bonding

Subject to the exceptions in Section 412 of ERISA and applicable U.S. Department of Labor guidance, every person who handles funds or other property of the Plan shall be bonded.

Section 7.5        Indemnification

Except as required by ERISA, the Plan’s fiduciaries shall not be liable for any mistake of judgment or other action taken in good faith. No fiduciary shall be personally liable by virtue of any contract, agreement, bond, or other instrument made or executed by himself or herself or any other fiduciary on behalf of the Plan.

The Participating Employers shall indemnify, defend, and hold harmless the members of the PIC, Administrative Committee, and Investment Committee and employees of the Participating Employers acting on their behalf with respect to the Plan from and against any and all claims, losses, damages, expenses, and liabilities arising, directly or indirectly, from their responsibilities in connection with the Plan, except where any such liability is judicially determined to be the result of willful misconduct. The Participating Employers may purchase fiduciary liability insurance against this risk.

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ARTICLE VIII
CLAIMS PROCEDURES

Section 8.1        Claims for Benefits

If a Participant or Beneficiary or any other person (each, a “claimant”) believes he or she is entitled to a benefit from the Plan or wishes to clarify his or her rights under the Plan, such claimant may file a written claim for benefits with the Administrative Committee. The Administrative Committee shall consider such written claim and respond to the claimant within ninety (90) days after receiving the claim unless special circumstances require an extension of time. The Administrative Committee may extend the response period by up to ninety (90) additional days by notifying the claimant in writing, prior to the end of the initial ninety (90)-day period, that additional time is required. The notice of extension must set forth the special circumstances and the date by which the Administrative Committee expects to render its decision. If the Administrative Committee denies the claim, in whole or in part, the Administrative Committee shall provide the claimant with written notice of the denial and of the claimant’s right to an appeal. The notice shall set forth, in a manner calculated to be understood by the claimant:

•The specific reason or reasons for the denial;

•A reference to the specific Plan provisions on which the denial is based;

•A description of additional material or information, if any, which the claimant might provide to perfect the claim and an explanation of why it is needed;

•An explanation of the Plan’s appeal procedure in Section 8.2 and the time limits applicable to an appeal; and

•A statement of the claimant’s right to bring a civil action under Section 502(a) of ERISA following an adverse benefit determination on appeal.

Section 8.2         Appeal

Within ninety (90) days after receiving notice that a claim has been denied, the claimant may file a written appeal with the PIC. The claimant may provide written testimony and written documentation in support of the claimant’s appeal. Upon written request from the claimant, the PIC shall provide free of charge to such claimant reasonable access to and copies of all documents, records, and other information relevant (as defined in applicable ERISA regulations) to the particular claim. The PIC shall undertake a full and fair review of the appeal, taking into account all testimony, documents, records, and other information submitted by the claimant, without regard to whether such information was submitted or considered in the initial benefit determination. The PIC may hold a hearing and may require the claimant to provide additional information or testimony as the PIC, in its sole discretion, deems useful or appropriate to its consideration of the claim. The PIC shall render its final decision within sixty (60) days of receipt of the appeal unless special circumstances require an extension of time. The PIC may

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extend the appeal period by up to sixty (60) additional days by notifying the claimant in writing, prior to the end of the initial sixty (60)-day period, that additional time is required. The notice of extension must set forth the special circumstances and the date by which the PIC expects to render its final decision. If the PIC’s final decision is a denial of the claim, the PIC shall provide written notice of the denial, which notice shall set forth, in a manner calculated to be understood by the claimant:

•The specific reason or reasons for the denial;

•A reference to the specific Plan provisions on which the denial is based;

•A statement that the claimant is entitled to receive, upon written request and free of charge, reasonable access to and copies of all documents, records and other information relevant (as defined in applicable ERISA regulations) to the claimant’s claim; and

•A statement of the claimant’s right to bring a civil action under Section 502(a) of ERISA.

Section 8.3         Other Remedies

If the Administrative Committee or PIC fails to respond to a claimant within the time limits set forth in this Article VIII, the claimant may consider the claim denied. A claimant must comply with these procedures and exhaust all possibilities contained herein before filing a civil action under Section 502(a) of ERISA or otherwise seeking relief in any other forum. If a claimant seeks relief in another forum, the evidence presented will be strictly limited to the evidence timely presented in the administrative claims process. In addition, the claimant must commence an action in another forum within one hundred and eighty (180) days after the PIC’s final decision on appeal under Section 8.2.

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ARTICLE IX
AMENDMENT, TERMINATION, AND MERGER

Section 9.1         Amendment

(a)General Rule.

The Company reserves the right to amend the Plan in whole or in part at any time and for any reason and to give such amendment retroactive effect to the extent permitted by applicable law. The PIC may approve any amendment to the Plan necessary to comply with the Code or ERISA or that does not have a substantial impact on the cost or design of the Plan. All other amendments must be approved by the Board of Directors of the Company or a committee of the Board or one or more officers of the Company or a Participating Employer to whom the Board has delegated amendment authority.

(b)Nondiscrimination.

The timing of an amendment must not have the effect of discriminating significantly in favor of HCEs.

(c)Anti-cutback Rule.

No amendment may reduce the accrued benefit of any Participant, except to the extent permitted under Sections 1.411(d)-3 and 1.411(d)-4 of the Treasury Regulations.

(d)Vesting Schedule.

If an amendment is made to the vesting schedule, every Participant who is actively employed and who has at least three (3) Years of Vesting Service must be permitted to elect, within a reasonable period of time after the adoption of the amendment, to have his or her vesting percentage determined under the Plan without regard to the amendment.

Section 9.2         Termination or Discontinuance

The Company reserves the right to terminate the Plan at any time and for any reason, and each Participating Employer reserves the right to terminate its own participation in the Plan or discontinue contributions to the Plan at any time and for any reason. If the Plan is terminated (in full or in part) or if there is a complete discontinuance of contributions under the Plan, the rights of affected Participants (i.e. current employees and terminated employees who have not forfeited the non-vested portion of their Account as of the date of termination) to benefits accrued to the date of such termination or complete discontinuance, to the extent funded as of such date, shall be fully vested and nonforfeitable.

Section 9.3         Merger or Spinoff

The Plan may be merged or consolidated with or its assets and liabilities may be transferred to another qualified plan and trust only if the benefits that would be received by a Participant in the

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event of a termination of the transferee plan immediately after such transfer, merger, or consolidation are at least equal to the benefits the Participant would have received if the Plan had terminated immediately before the transfer, merger, or consolidation, and only if such transfer, merger, or consolidation does not otherwise result in the elimination of any accrued benefit. The Plan may be split into two or more plans by way of a spinoff if, after the spinoff: (a) the sum of the account balances for each of the participants in the resulting plans equals the Account balance of the Participant in this Plan before the spinoff, and (b) the assets in each of the plans immediately after the spinoff equals the sum of the account balances for all participants in that plan.

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ARTICLE X
MISCELLANEOUS

Section 10.1    No Right to Employment

Nothing contained in the Plan gives any Participant or Employee the right to be retained in the service of a Participating Employer or interferes with the right of a Participating Employer to discharge any Employee at any time.

Section 10.2     Inalienability

No Participant, Beneficiary, alternate payee, or any other person having or claiming to have any right or interest of any kind in the Plan shall have any right to sell, assign, transfer, convey, hypothecate, anticipate, or otherwise dispose of such interest. No interest in the Plan shall be subject to any liabilities or obligations of any Participant or Beneficiary or to any bankruptcy proceedings, claims of creditors, attachment, garnishment, execution, levy, or other legal or equitable process against a Participant, Beneficiary, alternate payee, or any other person having or claiming to have any interest under this Plan, or such person’s property. The prior sentence shall not apply to the creation, assignment, or recognition of any benefit payable with respect to a Participant pursuant to a qualified domestic relations order, or to the enforcement of a judgment, settlement, or order described in Section 401(a)(13)(C) of Code, or to any other exception provided under Section 401(a)(13) of the Code or the Treasury Regulations thereunder.

Section 10.3     Facility of Payment

If any Participant, Beneficiary, or Alternate Payee eligible to receive payments under the Plan is, in the opinion of the Administrative Committee, legally, physically, or mentally incapable of personally receiving and receipting for any payment under the Plan, the Administrative Committee may direct that such payments, or any portion thereof, be made to any person(s) or institution who have custody of such payee, or are providing necessities of life (including, without limitation, food, shelter, clothing, and medical or custodial care) to such payee, to the extent deemed appropriate by the Administrative Committee. Such payments shall constitute a full discharge of the liability of the Plan to the extent thereof. The Administrative Committee may withhold all other amounts due to such payee until a claim for such amounts is duly made by a duly appointed guardian or other legal representative of such payee.

Section 10.4     Construction of Plan

(a)Headings.

The headings of Articles and Sections are included herein solely for the convenience of reference, and if there is any conflict between such headings and the text of this Plan, the text shall control.

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(b)Controlling Law.

To the extent not preempted by ERISA or other federal law, the Plan shall be governed and construed according to the laws of the State of Hawaii.

Section 10.5     Benefits Payable From Trust

All benefits payable under the Plan shall be paid solely from the trust, and the Participating Employers assume no liability or responsibility therefore.

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ARTICLE XI
TOP-HEAVY RULES

Section 11.1     Determination of Top-Heavy Status

For purposes of this Article XI, the following terms shall have the meanings set forth below:

(a)“Key Employee”.

In determining whether the Plan is top-heavy, “Key Employee” means any Employee or former Employee (including any deceased Employee) who at any time during the Plan Year that includes the Determination Date was:

(i)An officer of a Participating Employer having annual 415 Compensation greater than $200,000 (as adjusted after 2022 under Section 416(i)(1) of the Code); provided however, no more than the lesser of (A) fifty (50) Employees or (B) the greater of three Employees or ten percent (10%) of all Employees shall be regarded as officers,

(ii)A five percent (5%) owner of the Company, or

(iii)A one percent (1%) owner of the Company having annual 415 Compensation of more than $150,000.

The determination of who is a Key Employee shall be made in accordance with Section 416(i)(1) of the Code and the regulations and other guidance of general applicability issued thereunder.

A “non-Key Employee” is any Employee who is not a Key Employee.

(b)“Top-heavy Plan”:

The Plan is top-heavy if any of the following conditions exists:

(i)If the Top-Heavy Ratio for the Plan exceeds sixty percent (60%) and the Plan is not part of any required aggregation group or permissive aggregation group of plans.

(ii)If the Plan is part of a required aggregation group of plans but not part of a permissive aggregation group and the Top-Heavy Ratio for the group of plans exceeds sixty percent (60%).

(iii)If the Plan is part of a required aggregation group and part of a permissive aggregation group of plans and the Top-Heavy Ratio for the permissive aggregation group exceeds sixty percent (60%).

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(c)“Top-Heavy Ratio”.

(i)If a Participating Employer maintains one or more defined contribution plans (including any simplified employee pension plan) and the Participating Employer has not maintained any defined benefit plan that during the five (5)-year period ending on the Determination Date has or had accrued benefits, the Top-Heavy Ratio for the Plan alone or for the required or permissive aggregation group as appropriate is a fraction, the numerator of which is the sum of the account balances of all Key Employees as of the Determination Date (including any part of any account balance distributed in the one (1)-year period ending on the Determination Date) (five (5)-year period ending on the Determination Date in the case of a distribution made for a reason other than severance from employment, death, or disability), and the denominator of which is the sum of all account balances (including any part of any account balance distributed in the 1-year period ending on the Determination Date) (five (5)-year period ending on the Determination Date in the case of a distribution made for a reason other than severance from employment, death, or disability), both computed in accordance with Section 416 of the Code and the regulations thereunder. Both the numerator and denominator of the Top-Heavy Ratio shall be increased to reflect any contribution not actually made as of the Determination Date but which is required to be taken into account on that date under Section 416 of the Code and the regulations thereunder.

(ii)If a Participating Employer maintains one or more defined contribution
plans (including any simplified employee pension plan) and the Participating Employer maintains or has maintained one or more defined benefit plans that during the five (5)-year period ending on the Determination Date has or has had any accrued benefits, the Top-Heavy Ratio for any required or permissive aggregation group as appropriate is a fraction, the numerator of which is the sum of account balances under the aggregated defined contribution plan or plans for all Key Employees, determined in accordance with Section 11.1(c)(i) above, and the present value of accrued benefits under the aggregated defined benefit plan or plans for all Key Employees as of the Determination Date, and the denominator of which is the sum of account balances under the aggregated defined contribution plans for all Participants, determined in accordance with Section 11.1(c)(i) above, and the present value of accrued benefits under the defined benefit plans for all Participants as of the Determination Date, all as determined in accordance with Section 416 of the Code and the regulations thereunder. The accrued benefits under a defined benefit plan in both the numerator and denominator of the Top-Heavy Ratio are increased for any distribution of an. accrued benefit made in the one (1)-year period ending on the Determination Date (five (5)-year period ending on the Determination Date in the case of a distribution made for a reason other than severance from employment, death, or disability).

(iii)For purposes of subparagraphs (i) and (ii) above, the value of account balances and the present value of accrued benefits shall be determined as of the most

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recent Valuation Date that falls within or ends with the twelve (12)-month period ending on the Determination Date, except as provided in Section 416 of the Code and the regulations thereunder for the first and second plan years of a defined benefit plan. The account balances and accrued benefits of a Participant (i) who is not a Key Employee but who was a Key Employee in. a prior year or (ii) who has not been credited with at least one (1) Hour of Service with any employer maintaining the Plan at any time during the one (1)-year period ending on the Determination Date shall be disregarded. The calculation of the Top-Heavy Ratio, and the extent to which distributions, rollovers, and transfers are taken into account shall be made in accordance with Section 416 of the Code and the regulations thereunder. Deductible employee contributions shall not be taken into account for purposes of computing the Top-Heavy Ratio. When aggregating plans, the value of account balances and accrued benefits shall be calculated with reference to the Determination Dates that fall within the same calendar year.

(iv)The accrued benefit of a Participant other than a Key Employee shall be determined under (A) the method, if any, that uniformly applies for accrual purposes under all defined benefit plans maintained by the Participating Employer, or (B) if there is no such method, as if such benefit accrued not more rapidly than the slowest accrual rate permitted under the fractional rule of Section 411(b)(1)(C) of the Code.

(d)“Permissive aggregation group” means the required aggregation group of plans plus any other plan or plans of the Participating Employer that, when considered as a group with the required aggregation group, would continue to satisfy the requirements of Sections 401(a)(4) and 410 of the Code.

(e)“Required aggregation group” means (i) each qualified plan of the Participating Employer in which at least one Key Employee participates or participated at any time during the Plan Year containing the Determination Date or any of the four preceding Plan Years (regardless of whether the plan has terminated), and (ii) any other qualified plan of the Participating Employer that enables a plan described in (i) to meet the requirements of Sections 401(a)(4) or 410 of the Code. For this purpose, “Participating Employer” shall include all employers aggregated under Section 414(b), (c), or (m) with a Participating Employer.

(f)“Determination Date”. For any Plan Year subsequent to the first Plan Year, the Determination Date means the last day of the preceding Plan Year. For the first Plan Year, the Determination Date means the last day of that year.

(g)“Valuation Date” means the Determination Date as of which account balances or accrued benefits are valued for purposes of calculating the Top-Heavy Ratio.

Section 11.2    Special Top-Heavy Rules

(a)If the Plan is or becomes top-heavy in any Plan Year, the provisions of this Article XI shall supersede any conflicting provisions in the Plan.

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(i)Except as otherwise provided in subparagraph (iv) below, the Participating Employer contributions and forfeitures allocated on behalf of any Participant who is not a Key Employee shall be not be less than the lesser of (A) three percent (3%) of such Participant’s 415 Compensation or (B) in the case where the Participating Employer has no defined benefit plan that designates the Plan to satisfy Section 401 of the Code, the largest percentage of Participating Employer contributions and forfeitures, as a percentage of the first $305,000 (as adjusted after 2022 under Section 401(a)(17) of the Code) of the Key Employee’s 415 Compensation, allocated on behalf of any Key Employee for that year. The minimum allocation shall be determined without regard to any Social Security contribution. This minimum allocation shall be made even though, under other Plan provisions, the Participant would not otherwise be entitled to receive an allocation, or would have received a lesser allocation because of the Participant’s failure to (A) complete one thousand (1,000) Hours of Service (or any equivalent provided in the Plan), (B) make mandatory employee contributions to the Plan, or (C) earn compensation in excess of a stated amount.

(ii)If a Participant is covered by both this Plan and a defined benefit plan, the minimum benefit required by Section 416 of the Code shall be provided by the defined benefit plan, provided that such benefit shall be offset by the benefits, if any, provided by this Plan.

(iii)The minimum allocation required (to the extent required to be nonforfeitable under Section 416(b)) may not be forfeited under Section 411(a)(3)(B) or 411(a)(3)(D) of the Code.

(iv)The provision in (i) above shall not apply to any Participant who was not employed by a Participating Employer on the last day of the Plan. Year.

(b)The vesting schedule for Matching Contribution and Non-Elective Contribution Subaccounts meets the requirements for top-heavy vesting schedules in Section 416(b) of the Code, and shall apply in all years, whether or not the Plan is top-heavy.

(c)The minimum benefit requirements in this Section 11.2 shall not apply with respect to any Employee included in a unit of employees covered by a collective bargaining agreement if there is evidence the retirement benefits were the subject of good faith bargaining between Employee representatives and the Participating Employer. For this purpose, the term “Employee representatives” does not include any organization more than half of whose members are Employees who are owners, officers, or executives of the Participating Employer.

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ARTICLE XII
DEFINITIONS

Wherever used in this document, the following capitalized terms have the indicated meanings unless the context clearly implies otherwise:

Section 12.1     “Account” means the separate account maintained for each Participant which represents such Participant’s total proportionate interest in the Plan and Trust Fund as of any valuation date. A Participant’s Account may include one or more Subaccounts, as described in Section 4.2(a). A Participant’s Account balance is the Participant’s accrued benefit.

Section 12.2     “Administrative Committee” means the Hawaiian Electric Industries, Inc. Retirement Plans Administrative Committee appointed by the PIC to oversee the day-to-day administration of the Plan. See Section 7.1(b).

Section 12.3     “Associated Company” means (i) a corporation that is not a Participating Employer, but is a member of the same controlled group of corporations (within the meaning of Section 1563(a) of the Code, determined without regard to Sections 1563(a)(4) and (e)(3)(C) of the Code) as a Participating Employer, (ii) a trade or business, whether or not incorporated, that is not a Participating Employer, but is under common control (within the meaning of Section 414(c) of the Code) with a Participating Employer; or (iii) a member, other than a Participating Employer, of an affiliated service group (within the meaning of Section 414(m) of the Code) that includes a Participating Employer.

Section 12.4     “Beneficiary” means the person or entity to whom all or a portion of a deceased Participant’s Account is payable as a death benefit in accordance with Section 6.7 of the Plan.

Section 12.5     “Catch-up Contribution” means a pre-tax or Roth Salary Reduction Contribution made on behalf of a catch-up eligible Participant that is in excess of an otherwise applicable Plan limit. An otherwise applicable Plan limit is a limit in the Plan that applies to Salary Reduction Contributions without regard to Catch-up Contributions, such as the limit on annual additions in Section 415(e) of the Code, the dollar limitation under Section 402(g) of the Code, or the limit imposed by the actual deferral percentage test in Section 401(k)(3) of the Code.

Section 12.6     “Code” means the Internal Revenue Code of 1986, as amended.

Section 12.7     “Company” means Hawaiian Electric Industries, Inc., or any successor thereto.

Section 12.8     “Compensation” has different meanings for different purposes. “Compensation” is used to calculate Salary Reduction Contributions, Non-Elective Contributions, and Matching Contributions. “ADP Compensation” and “415 Compensation” are used for ADP testing and 415 testing, respectively, and other specific purposes under the Plan.

“Compensation” means the Employee’s Box 1, W-2 earnings from the Employee’s Participating Employer for the Plan Year, modified (i) to exclude discretionary bonuses, fringe benefits, FlexCredits, reimbursements, moving expenses and other expense allowances, and special executive compensation; and (ii) to include elective contributions made by a Participating

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Employer to this Plan, a cafeteria plan (other than FlexCredits), or a transportation spending plan that are excluded from the taxable income of the Employee under Sections 402(e)(3), 125, or 132(f) of the Code. Special executive compensation is noncash compensation and nonqualified deferred compensation available only to a select group of management Employees. Compensation earned prior to an Eligible Employee becoming a Participant shall not be counted in determining contributions to the Plan.

“ADP Compensation” means the Employee’s Box 1, W-2 earnings for the Plan Year, without modification.

“415 Compensation” means the Employee’s Box 1, W-2 earnings for the Plan Year, modified to include elective contributions made by a Participating Employer to this Plan, a cafeteria plan, or a transportation spending plan that are excluded from the taxable income of the Employee under Sections 402(e)(3), 125, or 132(f) of the Code.

“Compensation,” “ADP Compensation,” and “415 Compensation” generally do not include amounts paid after severance from employment. However, “Compensation,” “ADP Compensation,” and “415 Compensation” shall include amounts paid by the later of two and a half (2 1/2) months after the Participant’s severance from employment or the end of the calendar year that includes the date of the Participant’s severance from employment, if the amounts would have been included in the applicable definition of compensation if paid prior to severance from employment and if:

(a)The payment is regular compensation for services during the Participant’s regular working hours, or compensation for services outside the Participant’s regular working hours (such as overtime or shift differential), commissions, bonuses, or similar payments, and, absent the severance from employment, the payments would have been paid to the Participant while the Participant continued in employment with the Participating Employer; or

(b)The payment is for unused accrued bona fide sick, vacation, or other leave that the Participant would have been able to use if employment had continued.

“415 Compensation” shall also include amounts paid by the later of two and a half (2 1/2) months after the Participant’s severance from employment or the end of the calendar year that includes the date of the Participant’s severance from employment, if the payment is received by the Participant pursuant to an unfunded, nonqualified deferred compensation plan and would have been paid at the same time if employment continued, but only to the extent includible in gross income.

Back pay, within the meaning of Section 1.415(c)-2(g)(8) of the Treasury Regulations, shall be treated as 415 Compensation for the limitation year (calendar year) to which the back pay relates to the extent the back pay represents wages and compensation that would otherwise be included as 415 Compensation under this definition.

“Compensation,” “ADP Compensation,” and “415 Compensation” shall be limited to $305,000 annually, as automatically adjusted after 2022 for increases in the cost of living in accordance with Sections 401(a)(17)(B) and 415(d) of the Code.

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For purposes of this Section 12.8, “elective contributions” under Section 125 of the Code shall include any amount that is not available to an Employee in cash in lieu of group health coverage under a Section 125 arrangement because the Employee is not able to certify in accordance with the Hawaii Prepaid Healthcare Act that he or she has other health coverage. An amount shall be treated as an elective contribution under the foregoing sentence only if the Participating Employer does not request or collect information regarding the Employee’s other health coverage as part of the enrollment process for the health plan except as necessary to comply with the Hawaii Prepaid Healthcare Act.

A Participant receiving a differential wage payment (as defined in Section 3401(h)(2) of the Code) shall be treated as an Employee of the Participating Employer making the payment, and the payment will be treated as wages for purposes of Section 3401 of the Code. Furthermore, the differential wage payment shall be treated as ADP Compensation and 415 Compensation for purposes of the Plan. For purposes of this paragraph, “differential wage payment” is defined by reference to Section 3401(h)(2) of the Code and generally means a payment made by a Participating Employer to a Participant who is on active military duty for a period of more than thirty (30) days, which represents all or a portion of the wages the Participant would have received from the Participant’s Participating Employer if the Participant were performing services for the Participating Employer.

Section 12.9     “Compensation Committee” means the Compensation Committee of the Board of Directors of the Company.

Section 12.10     “Disability” means a disability as defined in the then existing long-term disability plan maintained by the Participant’s Participating Employer, regardless of whether the Participant is covered under that plan.

Section 12.11     “Early Retirement Age” means age fifty-five (55).

Section 12.12     “Eligible Employee” means any Employee, other than a Leased Employee or an Employee employed on a “contract basis”. An Employee is employed on a “contract basis” if the Employee is hired under written contract for a specific task or assignment.

Section 12.13     “Employee” means a common law employee of a Participating Employer who is treated as such on the payroll records of a Participating Employer. “Employee” includes Leased Employees, except that a Leased Employee shall not be treated as an Employee if (1) the leasing organization covers the Leased Employee under a money purchase pension plan that provides a nonintegrated employer contribution of at least ten percent (10%) of compensation, full and immediate vesting, and immediate participation for all employees it leases, and (2) Leased Employees do not constitute more than twenty percent (20%) of the Participating Employer’s workforce.

A person who performs services for a Participating Employer as an independent contractor is not an Employee and is not eligible to participate in the Plan. An independent contractor is a person who performs services as an independent businessperson, as determined in accordance with the Code and ERISA. A person shall not be treated as an Employee for purposes of the Plan during any period in which such person is classified as an independent contractor by a Participating

74

Employer, even if the person is later determined to have been a common-law employee during such period.

Section 12.14     “ERISA” means the Employee Retirement Income Security Act of 1974, as amended.

Section 12.15     “HEI Retirement Plan” means the Retirement Plan for Employees of Hawaiian Electric Industries, Inc. and Participating Subsidiaries, as amended.

Section 12.16     “Highly Compensated Employee” or “HCE” means—

(a)Any Employee who, during the Plan Year being tested or the immediately preceding year, owns or owned, directly or by attribution, more than five percent (5%) of the outstanding stock of the Company or more than five percent (5%) of the voting control of the Company; or

(b)Any Employee who for the preceding year had 415 Compensation from a Participating Employer in excess of $135,000, as adjusted after 2022 for increases in the cost of living in accordance with Section 415(d) of the Code.

A “non-Highly Compensated Employee” or “NHCE” is any Employee who is not an HCE for the year.

Section 12.17     “Hour of Service” means the following hours as determined from the payroll or other reliable records of a Participating Employer:

(a)Each hour during the Plan Year for which an Employee is paid or entitled to payment by a Participating Employer for the performance of duties. These hours are credited to the Plan Year in which they are performed.

(b)Each hour for which an Employee is paid or entitled to payment by a Participating Employer for periods during which the Employee performs no duties because of vacation, holiday, illness, incapacity (including short-term disability), layoff, jury duty, military duty, or other approved leave of absence, except that Hours of Service shall not be counted where such payment is made or is due under a plan maintained solely for the purpose of complying with applicable worker’s compensation, unemployment, or disability insurance laws, or solely to reimburse an Employee for medical or medically related expenses. To which Plan Year these hours are credited depends on the calculation of the payment. If the payment is calculated based on units of time, such as payment for two weeks’ vacation, the hours shall be credited to the Plan Year during which the time occurred (the Employee took the vacation). If the payment is based on an event rather than a period of time, such as a single sum payment made because of layoff or disability, the hours shall be credited to the first Plan Year or allocated reasonably and consistently between the first Plan Year and the second Plan. Year during which the event took place.

(c)Each hour for which back pay, irrespective of mitigation of damages, is either awarded or agreed to by a Participating Employer. The same Hours of Service shall not be credited both under subparagraph (a) or (b), as the case may be, and this subparagraph (c). These hours will

75

be credited to the Plan Year to which the award or agreement pertains and not to the Plan Year in which the award, agreement, or payment is made.

(d)The Hour of Service rules stated in Department of Labor Regulations §2530.200b-2 are incorporated herein by reference, and any questions on the crediting of Hours of Service shall be resolved by reference to such regulations.

Section 12.18     “Investment Committee” means the Hawaiian Electric Industries, Inc. Retirement Plans Investment Committee appointed by the PIC to oversee the day-to-day financial affairs of the Plan. See Section 7.1(c).

Section 12.19     “Leased Employee” means a person who is not a common law employee of a Participating Employer or an Associated Company but who performs services for such under an agreement with a third party that treats the person as the third party’s employee for payroll and withholding purposes, if (1) such person has performed the services for a Participating Employer or an Associated Company on a substantially full-time basis for a period of one (1) year, and (2) a Participating Employer or an Associated Company exercises primary direction or control over the performance of services by the person.

Section 12.20     “Matching Contributions” means the matching contributions made by the Participating Employers pursuant to Section 2.4.

Section 12.21    “Non-Elective Contributions” means the Non-Elective Contributions made by the Participating Employers pursuant to Section 2.5.

Section 12.22     “Normal Retirement Age” means age sixty-five (65).

Section 12.23     “One (1)-Year Break in Service” means severance from the employment of the Participating Employers and Associated Companies for a twelve (12)-consecutive month period.

Section 12.24     “Participant” means any Eligible Employee who has met the requirements for participation, as applicable, in Article I.

Section 12.25     “Participating Employer” means the Company and any entity affiliated with the Company whose participation in the Plan has been approved by the Company and by such entity’s board of directors. As of January 1, 2022, the Participating Employers are: Hawaiian Electric Industries, Inc.; Hawaiian Electric Company, Inc.; Maui Electric Company, Limited; Hawaii Electric Light Company, Inc.; and Pacific Current, LLC.

Section 12.26     “PIC” means the Hawaiian Electric Industries, Inc. Pension Investment Committee.

Section 12.27     “Plan” means the Hawaiian Electric Industries Retirement Savings Plan, as described in this instrument, including all amendments hereto.

Section 12.28     “Plan Year” means the calendar year.

76

Section 12.29     “Qualified Military Service” means any service in the Armed Forces (Army, Air Force, Navy, Marine Corps, or Coast Guard), the Army National Guard and the Air National Guard when engaged in active duty for training, inactive duty training, or full-time National Guard duty, the commissioned corps of the Public Health Service, and any other category of persons designated by the President in time of war or national emergency.

Section 12.30    “Qualified Roth Distribution” means a distribution from a Roth Subaccount that is made after the Participant attains age fifty-nine and a half (59 1/2) (or because of the death or Disability of the Participant) and after the five (5)-taxable-year period (i.e., five (5) consecutive calendar years) beginning January 1st of the first (1st) year in which the Participant made a designated Roth Salary Reduction Contribution or a Roth in-Plan conversion.

Section 12.31     “Regular Salary Reduction Contribution” include both pre-tax and Roth Salary Reduction Contributions

Section 12.32     “Retire” or “Retirement” refers to a Participant’s termination of employment after reaching Early Retirement Age.

Section 12.33     “Rollover Contributions” means contributions made by Eligible Employees pursuant to Section 2.7.

Section 12.34     “Salary Reduction Contributions” means a Participant’s affirmative elective contributions and default elective contributions described in Sections 2.1, 2.2 and 2.3.

Section 12.35     “Trust Agreement” means the agreement between the Company and the Trustee establishing a trust for the custody and investment of Plan assets.

Section 12.36     “Trust Fund” means all cash and property held by the Trustee pursuant to the Trust Agreement.

Section 12.37     “Trustee” means Fidelity Management Trust Company, a Massachusetts trust company, or any successor appointed by the Company or the PIC.

Section 12.38     “Year of Vesting Service” is determined under Article V.

77

ARTICLE XIII
EXECUTION

This restatement is executed effective October 6, 2022.

HAWAIIAN ELECTRIC INDUSTRIES,

By: /s/ Kurt K. Murao         

Kurt K. Murao

Executive Vice President, General Counsel, Chief Administrative Officer and Corporate Secretary

78

EX-31.1

HEI Exhibit 31.1

CERTIFICATION

I, Scott W. H. Seu, certify that:

1. I have reviewed this report on Form 10-Q for the quarter ended March 31, 2023 of Hawaiian Electric Industries, Inc. (“registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)   Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)   Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)   Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)   Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)   All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)   Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 9, 2023
	/s/ Scott W. H. Seu
	Scott W. H. Seu
	President and Chief Executive Officer

EX-31.2

HEI Exhibit 31.2

CERTIFICATION

I, Paul K. Ito, certify that:

1. I have reviewed this report on Form 10-Q for the quarter ended March 31, 2023 of Hawaiian Electric Industries, Inc. (“registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)   Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)   Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)   Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)  Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)   All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)   Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 9, 2023
	/s/ Paul K. Ito
	Paul K. Ito
	Executive Vice President, Chief Financial Officer
	and Treasurer

EX-31.3

Hawaiian Electric Exhibit 31.3

CERTIFICATION

I, Shelee M. T. Kimura, certify that:

1. I have reviewed this report on Form 10-Q for the quarter ended March 31, 2023 of Hawaiian Electric Company, Inc. (“registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)   Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)   Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)   Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)   Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)   All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)   Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 9, 2023
	/s/ Shelee M. T. Kimura
	Shelee M. T. Kimura
	President and Chief Executive Officer

EX-31.4

Hawaiian Electric Exhibit 31.4

CERTIFICATION

I, Tayne S. Y. Sekimura, certify that:

1.I have reviewed this report on Form 10-Q for the quarter ended March 31, 2023 of Hawaiian Electric Company, Inc. (“registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)   Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)   Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)   Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)   Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)   All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)   Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 9, 2023
	/s/ Tayne S. Y. Sekimura
	Tayne S. Y. Sekimura
	Senior Vice President, Chief Financial Officer and Treasurer

EX-32.1

HEI Exhibit 32.1

Hawaiian Electric Industries, Inc.

Certification Pursuant to

18 U.S.C. Section 1350

In connection with the Quarterly Report of Hawaiian Electric Industries, Inc. (HEI) on Form 10-Q for the quarter ended March 31, 2023, as filed with the Securities and Exchange Commission (the Report), each of Scott W. H. Seu and Paul K. Ito, Chief Executive Officer and Chief Financial Officer, respectively, of HEI, certify, pursuant to 18 U.S.C. Section 1350, that to the best of his knowledge:

(1)   The Report complies with the requirements of section 13(a) of the Securities Exchange Act of 1934, as amended; and

(2)   The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of HEI and its subsidiaries as of, and for, the periods presented in this report.

Date: May 9, 2023

/s/ Scott W. H. Seu

Scott W. H. Seu

President and Chief Executive Officer

/s/ Paul K. Ito

Paul K. Ito

Executive Vice President, Chief Financial Officer

     and Treasurer

A signed original of this written statement has been provided to HEI and will be retained by HEI and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Hawaiian Electric Exhibit 32.2

Hawaiian Electric Company, Inc.

Certification Pursuant to

18 U.S.C. Section 1350

In connection with the Quarterly Report of Hawaiian Electric Company, Inc. (Hawaiian Electric) on Form 10-Q for the quarter ended March 31, 2023, as filed with the Securities and Exchange Commission (the Hawaiian Electric Report), each of Shelee M. T. Kimura and Tayne S. Y. Sekimura, Chief Executive Officer and Chief Financial Officer, respectively, of Hawaiian Electric, certify, pursuant to 18 U.S.C. Section 1350, that to the best of her knowledge:

(1)   The Hawaiian Electric Report complies with the requirements of section 13(a) of the Securities Exchange Act of 1934, as amended; and

(2)   The Hawaiian Electric information contained in the Hawaiian Electric Report fairly presents, in all material respects, the financial condition and results of operations of Hawaiian Electric and its subsidiaries as of, and for, the periods presented in this report. 

Date: May 9, 2023

/s/ Shelee M. T. Kimura

Shelee M. T. Kimura

President and Chief Executive Officer

/s/ Tayne S. Y. Sekimura

Tayne S. Y. Sekimura

Senior Vice President, Chief Financial Officer and Treasurer

A signed original of this written statement has been provided to Hawaiian Electric and will be retained by Hawaiian Electric and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Cover Page - shares	3 Months Ended
	Mar. 31, 2023	Apr. 18, 2023
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2023
Document Transition Report	false
Entity Registrant Name	HAWAIIAN ELECTRIC INDUSTRIES, INC.
Entity File Number	1-8503
Entity Tax Identification Number	99-0208097
Entity Incorporation, State or Country Code	HI
Entity Address, Address Line One	1001 Bishop Street
Entity Address, Address Line Two	Suite 2900
Entity Address, City or Town	Honolulu
Entity Address, State or Province	HI
Entity Address, Postal Zip Code	96813
City Area Code	808
Local Phone Number	543-5662
Title of 12(b) Security	Common Stock, Without Par Value
Trading Symbol(s)	HE
Name of each exchange on which registered	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		109,572,075
Entity Central Index Key	0000354707
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q1
Hawaiian Electric Company, Inc. and Subsidiaries
Entity Information [Line Items]
Document Type	10-Q
Entity Registrant Name	HAWAIIAN ELECTRIC COMPANY, INC.
Entity File Number	1-4955
Entity Tax Identification Number	99-0040500
Entity Incorporation, State or Country Code	HI
Entity Address, Address Line One	1099 Alakea Street
Entity Address, Address Line Two	Suite 2200
Entity Address, City or Town	Honolulu
Entity Address, State or Province	HI
Entity Address, Postal Zip Code	96813
City Area Code	808
Local Phone Number	543-7771
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		17,854,278
Entity Central Index Key	0000046207
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q1

XML

Condensed Consolidated Statements of Income (unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Revenues
Revenues	$ 928,237	$ 785,068
Expenses
Total expenses	834,719	685,792
Operating income (loss)
Total operating income	93,518	99,276
Retirement defined benefits credit—other than service costs	1,152	1,243
Interest expense, net—other than on deposit liabilities and other bank borrowings	(28,798)	(24,349)
Allowance for borrowed funds used during construction	1,131	778
Allowance for equity funds used during construction	3,301	2,409
Gain on sales of equity-method investment	0	8,123
Income before income taxes	70,304	87,480
Income taxes	15,110	17,840
Net income attributable to Hawaiian Electric	55,194	69,640
Preferred stock dividends of subsidiaries	473	473
Net income for common stock	$ 54,721	$ 69,167
Basic earnings per common share (in dollars per share)	$ 0.50	$ 0.63
Diluted earnings per common share (in dollars per share)	$ 0.50	$ 0.63
Weighted-average number of common shares outstanding (in shares)	109,514	109,361
Net effect of potentially dilutive shares (in shares)	311	273
Weighted-average shares assuming dilution (in shares)	109,825	109,634
Electric utility
Revenues
Revenues	$ 830,361	$ 708,792
Expenses
Total expenses	754,486	635,197
Operating income (loss)
Total operating income	75,875	73,595
Income before income taxes	61,108	59,446
Income taxes	13,600	12,538
Net income attributable to Hawaiian Electric	47,508	46,908
Preferred stock dividends of subsidiaries	499	499
Net income for common stock	47,009	46,409
Bank
Revenues
Revenues	93,857	75,115
Expenses
Total expenses	70,337	45,085
Operating income (loss)
Total operating income	23,520	30,030
Income before income taxes	23,707	30,215
Income taxes	5,145	6,345
Net income attributable to Hawaiian Electric	18,562	23,870
Preferred stock dividends of subsidiaries	0	0
Net income for common stock	18,562	23,870
Other
Revenues
Revenues	4,019	1,161
Expenses
Total expenses	9,896	5,510
Operating income (loss)
Total operating income	(5,877)	(4,349)
Income before income taxes	(14,511)	(2,181)
Income taxes	(3,635)	(1,043)
Net income attributable to Hawaiian Electric	(10,876)	(1,138)
Preferred stock dividends of subsidiaries	(26)	(26)
Net income for common stock	$ (10,850)	$ (1,112)

XML

Condensed Consolidated Statements of Comprehensive Income (unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Statement of Comprehensive Income [Abstract]
Net income for common stock	$ 54,721	$ 69,167
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 $6,079 and $(44,079), respectively	16,605	(120,407)
Amortization of unrealized holding losses on held-to-maturity securities, net of taxes of $1,346 and nil, respectively	3,677	0
Derivatives qualifying as cash flow hedges:
Unrealized interest rate hedging gains arising during the period, net of taxes of $65 and $1,046, respectively	186	3,017
Reclassification adjustment to net income, net of taxes of $(17) and $19, respectively	(48)	55
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost, net of taxes of $(122) and $1,562, respectively	(357)	4,501
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $147 and $(1,500), respectively	425	(4,325)
Other comprehensive income (loss), net of taxes	20,488	(117,159)
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	$ 75,209	$ (47,992)

XML

Condensed Consolidated Statements of Comprehensive Income (unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net unrealized gains (losses) on available-for-sale investment securities:
Net unrealized gains (losses) on available-for-sale investment securities arising during the period, tax	$ 6,079	$ (44,079)
Amortization of unrealized holding losses on held-to-maturity securities, net of taxes	1,346	0
Derivatives qualifying as cash flow hedges:
Unrealized interest rate hedging arising during the period, tax	65	1,046
Reclassification adjustment for net unrealized losses included in net income, tax	(17)	19
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, tax	(122)	1,562
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, tax	$ 147	$ (1,500)

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Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Assets
Cash and cash equivalents	$ 315,334	$ 199,877
Restricted cash	4,216	5,050
Accounts receivable and unbilled revenues, net	435,158	511,903
Available-for-sale investment securities, at fair value	1,419,755	1,429,667
Held-to-maturity investment securities, at amortized cost	1,238,185	1,251,747
Stock in Federal Home Loan Bank, at cost	10,000	26,560
Loans held for investment, net	5,988,058	5,906,690
Loans held for sale, at lower of cost or fair value	660	824
Property, plant and equipment, net of accumulated depreciation	5,778,571	5,687,003
Operating lease right-of-use assets	110,920	115,684
Regulatory assets	247,902	242,513
Other	812,836	824,536
Goodwill	82,190	82,190
Total assets	16,443,785	16,284,244
Liabilities
Accounts payable	237,822	251,460
Interest and dividends payable	41,382	21,333
Deposit liabilities	8,230,601	8,169,696
Short-term borrowings—other than bank	148,802	172,568
Other bank borrowings	680,690	695,120
Long-term debt, net—other than bank	2,480,948	2,384,980
Deferred income taxes	273,081	262,462
Operating lease liabilities	121,323	126,604
Finance lease liabilities	88,024	48,709
Regulatory liabilities	1,069,551	1,055,650
Defined benefit pension and other postretirement benefit plans liability	71,394	71,813
Other	727,919	787,057
Total liabilities	14,171,537	14,047,452
Preferred stock of subsidiaries - not subject to mandatory redemption	34,293	34,293
Commitments and contingencies (Notes 3 and 4)
Shareholders’ equity
Preferred stock, no par value, authorized 10,000,000 shares; issued: none	0	0
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding: 109,572,075 shares and 109,470,795 shares at March 31, 2023 and December 31, 2022, respectively	1,692,390	1,692,697
Retained earnings	861,105	845,830
Accumulated other comprehensive loss, net of tax benefits	(315,540)	(336,028)
Total shareholders’ equity	2,237,955	2,202,499
Total liabilities and shareholders’ equity	$ 16,443,785	$ 16,284,244

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Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Assets
Property, plant and equipment, accumulated depreciation	$ 3,241,748	$ 3,192,545
Shareholders’ equity
Preferred stock, no par value (in dollars per share)	$ 0	$ 0
Preferred stock, authorized shares (in shares)	10,000,000	10,000,000
Preferred stock, issued shares (in shares)	0	0
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock, authorized shares (in shares)	200,000,000	200,000,000
Common stock, shares issued (in shares)	109,572,075	109,470,795
Common stock, shares outstanding (in shares)	109,572,075	109,470,795

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Condensed Consolidated Statements of Changes in Shareholders' Equity - USD ($) $ in Thousands	Total	Common stock	Retained earnings	Accumulated other comprehensive income (loss)
Beginning balance (in shares) at Dec. 31, 2021		109,312,000
Beginning balance at Dec. 31, 2021	$ 2,390,884	$ 1,685,496	$ 757,921	$ (52,533)
Increase (decrease) in stockholders' equity
Net income for common stock	69,167		69,167
Other comprehensive (loss) income, net of tax benefits	(117,159)			(117,159)
Share-based expenses and other, net (in shares)		119,000
Share-based expenses and other, net	(949)	$ (949)
Common stock dividends	(38,301)		(38,301)
Ending balance (in shares) at Mar. 31, 2022		109,431,000
Ending balance at Mar. 31, 2022	$ 2,303,642	$ 1,684,547	788,787	(169,692)
Beginning balance (in shares) at Dec. 31, 2022	109,470,795	109,471,000
Beginning balance at Dec. 31, 2022	$ 2,202,499	$ 1,692,697	845,830	(336,028)
Increase (decrease) in stockholders' equity
Net income for common stock	54,721		54,721
Other comprehensive (loss) income, net of tax benefits	20,488			20,488
Share-based expenses and other, net (in shares)		101,000
Share-based expenses and other, net	(307)	$ (307)
Common stock dividends	$ (39,446)		(39,446)
Ending balance (in shares) at Mar. 31, 2023	109,572,075	109,572,000
Ending balance at Mar. 31, 2023	$ 2,237,955	$ 1,692,390	$ 861,105	$ (315,540)

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Condensed Consolidated Statements of Changes in Shareholders' Equity (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Statement of Stockholders' Equity [Abstract]
Common stock dividends (in dollars per share)	$ 0.36	$ 0.35

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Condensed Consolidated Statements of Cash Flows (unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Cash flows from operating activities
Net income	$ 55,194	$ 69,640
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation of property, plant and equipment	66,508	62,990
Other amortization	10,362	9,425
Provision for credit losses	1,175	(3,263)
Loans originated, held for sale	(5,450)	(73,931)
Proceeds from sale of loans, held for sale	5,662	75,629
Gain on sales of investment securities, net and equity-method investment	0	(8,123)
Gain on sale of loans, net	(130)	(1,077)
Deferred income taxes	(1,076)	(5,255)
Share-based compensation expense	2,031	2,117
Allowance for equity funds used during construction	(3,301)	(2,409)
Other	(988)	(2,552)
Changes in assets and liabilities
Decrease in accounts receivable and unbilled revenues, net	82,423	4,454
Decrease (increase) in fuel oil stock	33,429	(35,333)
Decrease (increase) in regulatory assets	(8,898)	(5,089)
Increase in regulatory liabilities	11,551	5,520
Increase in accounts, interest and dividends payable	24,748	71,490
Change in prepaid and accrued income taxes, tax credits and utility revenue taxes	(47,305)	(14,928)
Decrease in defined benefit pension and other postretirement benefit plans liability	(1,950)	(1,309)
Change in other assets and liabilities	(43,033)	(55,411)
Net cash provided by operating activities	180,952	92,585
Cash flows from investing activities
Available-for-sale investment securities purchased	0	(291,168)
Principal repayments on available-for-sale investment securities	32,484	104,654
Proceeds from repayments or maturities of held-to-maturity investment securities	17,938	4,547
Purchase of stock from Federal Home Loan Bank	(35,960)	0
Redemption of stock from Federal Home Loan Bank	52,520	0
Net decrease (increase) in loans held for investment	(68,871)	28,076
Purchase of loans held for investment	(13,012)	0
Capital expenditures	(124,297)	(79,163)
Contributions to low income housing investments	(418)	0
Other	2,148	5,340
Net cash used in investing activities	(137,468)	(227,714)
Cash flows from financing activities
Net increase in deposit liabilities	60,905	117,060
Net increase (decrease) in short-term borrowings with original maturities of three months or less	(88,666)	17,493
Net increase (decrease) in other bank borrowings with original maturities of three months or less	(564,430)	49,080
Proceeds from issuance of short-term debt	65,000	0
Proceeds from issuance of other bank borrowings	550,000	0
Proceeds from issuance of long-term debt	150,000	7,312
Repayment of long-term debt	(53,878)	(13,446)
Withheld shares for employee taxes on vested share-based compensation	(2,338)	(3,065)
Common stock dividends	(39,446)	(38,301)
Preferred stock dividends of subsidiaries	(473)	(473)
Other	(5,535)	(4,377)
Net cash provided by financing activities	71,139	131,283
Net increase (decrease) in cash, cash equivalents and restricted cash	114,623	(3,846)
Cash, cash equivalents and restricted cash, beginning of period	204,927	311,462
Cash, cash equivalents and restricted cash, end of period	319,550	307,616
Less: Restricted cash	(4,216)	(5,912)
Cash and cash equivalents, end of period	$ 315,334	$ 301,704

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Condensed Consolidated Statements of Income (unaudited) - HECO - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Revenues
Revenues	$ 928,237	$ 785,068
Expenses
Total expenses	834,719	685,792
Total operating income	93,518	99,276
Allowance for equity funds used during construction	3,301	2,409
Retirement defined benefits credit—other than service costs	1,152	1,243
Allowance for borrowed funds used during construction	1,131	778
Income before income taxes	70,304	87,480
Income taxes	15,110	17,840
Net income attributable to Hawaiian Electric	55,194	69,640
Preferred stock dividends of Hawaiian Electric	473	473
Net income for common stock	54,721	69,167
Hawaiian Electric Company, Inc. and Subsidiaries
Revenues
Revenues	830,361	708,792
Expenses
Fuel oil	334,097	221,286
Purchased power	152,761	163,533
Other operation and maintenance	128,316	125,257
Depreciation	60,927	58,471
Taxes, other than income taxes	78,385	66,650
Total expenses	754,486	635,197
Total operating income	75,875	73,595
Allowance for equity funds used during construction	3,301	2,409
Retirement defined benefits credit—other than service costs	1,047	990
Interest expense and other charges, net	(20,246)	(18,326)
Allowance for borrowed funds used during construction	1,131	778
Income before income taxes	61,108	59,446
Income taxes	13,600	12,538
Net income	47,508	46,908
Preferred stock dividends of subsidiaries	229	229
Net income attributable to Hawaiian Electric	47,279	46,679
Preferred stock dividends of Hawaiian Electric	270	270
Net income for common stock	$ 47,009	$ 46,409

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Condensed Consolidated Statements of Comprehensive Income (unaudited) - HECO - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net income for common stock	$ 54,721	$ 69,167
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost, net of taxes of $(163) and $1,518, respectively	(357)	4,501
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $147 and $(1,500), respectively	425	(4,325)
Other comprehensive income (loss), net of taxes	20,488	(117,159)
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	75,209	(47,992)
Hawaiian Electric Company, Inc. and Subsidiaries
Net income for common stock	47,009	46,409
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost, net of taxes of $(163) and $1,518, respectively	(470)	4,376
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $147 and $(1,500), respectively	425	(4,325)
Other comprehensive income (loss), net of taxes	(45)	51
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	$ 46,964	$ 46,460

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Condensed Consolidated Statements of Comprehensive Income (unaudited) - HECO (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, tax	$ (122)	$ 1,562
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, tax	147	(1,500)
Hawaiian Electric Company, Inc. and Subsidiaries
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, tax	(163)	1,518
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, tax	$ 147	$ (1,500)

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Condensed Consolidated Balance Sheets (unaudited) - HECO - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Utility property, plant and equipment
Total property, plant and equipment, net	$ 5,778,571	$ 5,687,003
Current assets
Cash and cash equivalents	315,334	199,877
Other long-term assets
Operating lease right-of-use assets	110,920	115,684
Total assets	16,443,785	16,284,244
Capitalization
Retained earnings	861,105	845,830
Accumulated other comprehensive income, net of taxes-retirement benefit plans	(315,540)	(336,028)
Total shareholders’ equity	2,237,955	2,202,499
Cumulative preferred stock — not subject to mandatory redemption	34,293	34,293
Commitments and contingencies (Notes 3 and 4)
Current liabilities
Interest and dividends payable	41,382	21,333
Deferred credits and other liabilities
Deferred income taxes	273,081	262,462
Total liabilities and shareholders’ equity	16,443,785	16,284,244
Hawaiian Electric Company, Inc. and Subsidiaries
Utility property, plant and equipment
Land	52,060	52,060
Plant and equipment	8,042,892	7,979,510
Financing lease right-of-use assets	88,297	48,371
Less accumulated depreciation	(3,133,811)	(3,086,499)
Construction in progress	315,862	275,353
Utility property, plant and equipment, net	5,365,300	5,268,795
Nonutility property, plant and equipment, less accumulated depreciation	6,945	6,945
Total property, plant and equipment, net	5,372,245	5,275,740
Current assets
Cash and cash equivalents	116,022	39,242
Customer accounts receivable, net	235,305	288,338
Accrued unbilled revenues, net	160,532	183,280
Other accounts receivable, net	11,427	13,567
Fuel oil stock, at average cost	157,583	191,530
Materials and supplies, at average cost	84,093	79,568
Prepayments and other	43,909	33,482
Regulatory assets	64,973	52,273
Total current assets	873,844	881,280
Other long-term assets
Operating lease right-of-use assets	84,930	89,318
Regulatory assets	182,929	190,240
Other	160,515	160,889
Total other long-term assets	428,374	440,447
Total assets	6,674,463	6,597,467
Capitalization
Common stock ($6 2/3 par value, authorized 50,000,000 shares; outstanding 17,854,278 shares at March 31, 2023 and December 31, 2022)	119,048	119,048
Premium on capital stock	810,955	810,955
Retained earnings	1,426,065	1,411,306
Accumulated other comprehensive income, net of taxes-retirement benefit plans	2,816	2,861
Total shareholders’ equity	2,358,884	2,344,170
Cumulative preferred stock — not subject to mandatory redemption	34,293	34,293
Long-term debt, net	1,734,347	1,584,854
Total capitalization	4,127,524	3,963,317
Commitments and contingencies (Notes 3 and 4)
Current liabilities
Current portion of operating lease liabilities	18,414	19,095
Current portion of long-term debt, net	99,973	99,962
Short-term borrowings from non-affiliates	0	87,967
Accounts payable	191,769	202,492
Interest and dividends payable	29,367	17,176
Taxes accrued, including revenue taxes	246,914	289,902
Regulatory liabilities	25,234	31,475
Other	86,580	85,596
Total current liabilities	698,251	833,665
Deferred credits and other liabilities
Operating lease liabilities	74,633	78,715
Finance lease liabilities	84,341	46,048
Deferred income taxes	384,953	384,430
Regulatory liabilities	1,044,317	1,024,175
Unamortized tax credits	93,445	95,300
Defined benefit pension and other postretirement benefit plans liability	49,388	49,748
Other	117,611	122,069
Total deferred credits and other liabilities	1,848,688	1,800,485
Total liabilities and shareholders’ equity	$ 6,674,463	$ 6,597,467

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Condensed Consolidated Balance Sheets (unaudited) - HECO (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Shareholders’ equity
Common stock, authorized shares (in shares)	200,000,000	200,000,000
Common stock, shares outstanding (in shares)	109,572,075	109,470,795
Hawaiian Electric Company, Inc. and Subsidiaries
Utility property, plant and equipment
Accumulated depreciation on other property, plant and equipment	$ 64	$ 63
Shareholders’ equity
Common stock, par value (in dollars per share)	$ 6.67	$ 6.67
Common stock, authorized shares (in shares)	50,000,000	50,000,000
Common stock, shares outstanding (in shares)	17,854,278	17,854,278

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Condensed Consolidated Statements of Changes in Shareholders' Equity (unaudited) - HECO - USD ($) $ in Thousands	Total	Hawaiian Electric Company, Inc. and Subsidiaries	Common stock	Common stock Hawaiian Electric Company, Inc. and Subsidiaries	Premium on capital stock Hawaiian Electric Company, Inc. and Subsidiaries	Retained earnings	Retained earnings Hawaiian Electric Company, Inc. and Subsidiaries	Accumulated other comprehensive income (loss)	Accumulated other comprehensive income (loss) Hawaiian Electric Company, Inc. and Subsidiaries
Beginning balance (in shares) at Dec. 31, 2021			109,312,000	17,753,000
Beginning balance at Dec. 31, 2021	$ 2,390,884	$ 2,261,899	$ 1,685,496	$ 118,376	$ 798,526	$ 757,921	$ 1,348,277	$ (52,533)	$ (3,280)
Increase (decrease) in stockholders' equity
Net income for common stock	69,167	46,409				69,167	46,409
Other comprehensive (loss) income, net of tax benefits	(117,159)	51						(117,159)	51
Common stock dividends	(38,301)	(31,475)				(38,301)	(31,475)
Ending balance (in shares) at Mar. 31, 2022			109,431,000	17,753,000
Ending balance at Mar. 31, 2022	$ 2,303,642	2,276,884	$ 1,684,547	$ 118,376	798,526	788,787	1,363,211	(169,692)	(3,229)
Beginning balance (in shares) at Dec. 31, 2022	109,470,795		109,471,000	17,854,000
Beginning balance at Dec. 31, 2022	$ 2,202,499	2,344,170	$ 1,692,697	$ 119,048	810,955	845,830	1,411,306	(336,028)	2,861
Increase (decrease) in stockholders' equity
Net income for common stock	54,721	47,009				54,721	47,009
Other comprehensive (loss) income, net of tax benefits	20,488	(45)						20,488	(45)
Common stock dividends	$ (39,446)	(32,250)				(39,446)	(32,250)
Ending balance (in shares) at Mar. 31, 2023	109,572,075		109,572,000	17,854,000
Ending balance at Mar. 31, 2023	$ 2,237,955	$ 2,358,884	$ 1,692,390	$ 119,048	$ 810,955	$ 861,105	$ 1,426,065	$ (315,540)	$ 2,816

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Condensed Consolidated Statements of Cash Flows (unaudited) - HECO - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation of property, plant and equipment	$ 66,508	$ 62,990
Other amortization	10,362	9,425
Deferred income taxes	(1,076)	(5,255)
Allowance for equity funds used during construction	(3,301)	(2,409)
Other	(988)	(2,552)
Changes in assets and liabilities
Decrease (increase) in fuel oil stock	33,429	(35,333)
Decrease (increase) in regulatory assets	(8,898)	(5,089)
Increase in regulatory liabilities	11,551	5,520
Change in prepaid and accrued income taxes, tax credits and utility revenue taxes	(47,305)	(14,928)
Decrease in defined benefit pension and other postretirement benefit plans liability	(1,950)	(1,309)
Change in other assets and liabilities	(43,033)	(55,411)
Net cash provided by operating activities	180,952	92,585
Cash flows from investing activities
Capital expenditures	(124,297)	(79,163)
Other	2,148	5,340
Net cash used in investing activities	(137,468)	(227,714)
Cash flows from financing activities
Common stock dividends	(39,446)	(38,301)
Proceeds from issuance of long-term debt	150,000	7,312
Net increase (decrease) in other bank borrowings with original maturities of three months or less	(564,430)	49,080
Other	(5,535)	(4,377)
Net cash provided by financing activities	71,139	131,283
Net increase (decrease) in cash, cash equivalents and restricted cash	114,623	(3,846)
Cash, cash equivalents and restricted cash, beginning of period	204,927	311,462
Cash, cash equivalents and restricted cash, end of period	319,550	307,616
Less: Restricted cash	(4,216)	(5,912)
Cash and cash equivalents, end of period	315,334	301,704
Hawaiian Electric Company, Inc. and Subsidiaries
Cash flows from operating activities
Net income	47,508	46,908
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation of property, plant and equipment	60,927	58,471
Other amortization	6,530	6,355
Deferred income taxes	(3,659)	(6,021)
State refundable credit	(2,874)	(2,759)
Bad debt expense	1,539	1,619
Allowance for equity funds used during construction	(3,301)	(2,409)
Other	350	(2)
Changes in assets and liabilities
Decrease in accounts receivable	60,939	16,236
Decrease (increase) in accrued unbilled revenues	22,659	(10,825)
Decrease (increase) in fuel oil stock	33,947	(35,294)
Increase in materials and supplies	(4,525)	(829)
Decrease (increase) in regulatory assets	(8,898)	(5,089)
Increase in regulatory liabilities	11,551	5,520
Increase in accounts payable	6,588	29,624
Change in prepaid and accrued income taxes, tax credits and utility revenue taxes	(45,392)	(16,080)
Decrease in defined benefit pension and other postretirement benefit plans liability	(1,837)	(1,206)
Change in other assets and liabilities	(12,697)	(7,444)
Net cash provided by operating activities	169,355	76,775
Cash flows from investing activities
Capital expenditures	(122,139)	(76,358)
Other	1,545	1,494
Net cash used in investing activities	(120,594)	(74,864)
Cash flows from financing activities
Common stock dividends	(32,250)	(31,475)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(499)	(499)
Proceeds from issuance of long-term debt	150,000	0
Net increase (decrease) in other bank borrowings with original maturities of three months or less	(87,967)	6,000
Payments of obligations under finance leases	(575)	0
Other	(690)	0
Net cash provided by financing activities	28,019	(25,974)
Net increase (decrease) in cash, cash equivalents and restricted cash	76,780	(24,063)
Cash, cash equivalents and restricted cash, beginning of period	39,242	55,258
Cash, cash equivalents and restricted cash, end of period	116,022	31,195
Less: Restricted cash	0	(2,140)
Cash and cash equivalents, end of period	$ 116,022	$ 29,055

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Basis of presentation	3 Months Ended
	Mar. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of presentation	Basis of presentationThe 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, 2022.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 March 31, 2023 and December 31, 2022 and the results of their operations and cash flows for the three months ended March 31, 2023 and 2022. All such adjustments are of a normal recurring nature, unless otherwise disclosed below or in other referenced material. Results of operations for interim periods are not necessarily indicative of results for the full year.Recent accounting pronouncements.Credit Losses. In March 2022, Financial Accounting Standards Board issued Accounting Standards Update (ASU) No. 2022-02, “Financial Instruments-Credit Losses (Topic 326): Troubled Debt Restructurings and Vintage Disclosures,” which eliminates the accounting guidance for Troubled Debt Restructurings (TDRs) by creditors in Subtopic 310-40, Receivables-Troubled Debt Restructurings by Creditors, while enhancing disclosure requirements for certain loan refinancings and restructurings by creditors when a borrower is experiencing financial difficulty. Specifically, rather than applying the recognition and measurement guidance for TDRs, an entity must apply the loan refinancing and restructuring guidance in paragraphs 310-20-35-9 through 35-11 to determine whether a modification results in a new loan or a continuation of an existing loan. The amendments in this update also require that an entity disclose current-period gross write-offs by year of origination for financing receivables and net investments in leases within the scope of Subtopic 326-20, “Financial Instruments-Credit Losses-Measured at Amortized Cost.” Gross write-off information must be included in the vintage disclosures required for public business entities in accordance with paragraph 325-20-50-6, which requires that an entity disclose the amortized cost basis of financing receivables by credit-quality indicator and class of financing receivable by year of origination. The amendments in this update are effective for fiscal years beginning after December 15, 2022, including interim periods within those fiscal years. ASB updated the accounting for certain loan refinancings and restructurings, and included the required disclosures in the Notes herein

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Segment financial information

3 Months Ended

Mar. 31, 2023

Segment Reporting [Abstract]

Segment financial information

Segment financial information

(in thousands)	Electric utility		Bank		Other		Total
Three months ended March 31, 2023
Revenues	$	830,361	$	93,857	$	4,019	$	928,237
Income (loss) before income taxes	$	61,108	$	23,707	$	(14,511)	$	70,304
Income taxes (benefit)	13,600		5,145		(3,635)		15,110
Net income (loss)	47,508		18,562		(10,876)		55,194
Preferred stock dividends of subsidiaries	499		—		(26)		473
Net income (loss) for common stock	$	47,009	$	18,562	$	(10,850)	$	54,721
Total assets (at March 31, 2023)	$	6,674,463	$	9,610,070	$	159,252	$	16,443,785
Three months ended March 31, 2022
Revenues from external customers and other sources	$	708,788	$	75,115	$	1,165	$	785,068
Intersegment revenues (eliminations)	4		—		(4)		—
Revenues	$	708,792	$	75,115	$	1,161	$	785,068
Income (loss) before income taxes	$	59,446	$	30,215	$	(2,181)	$	87,480
Income taxes (benefit)	12,538		6,345		(1,043)		17,840
Net income (loss)	46,908		23,870		(1,138)		69,640
Preferred stock dividends of subsidiaries	499		—		(26)		473
Net income (loss) for common stock	$	46,409	$	23,870	$	(1,112)	$	69,167
Total assets (at December 31, 2022)	$	6,597,467	$	9,545,970	$	140,807	$	16,284,244

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.

XML

Electric utility segment

3 Months Ended

Mar. 31, 2023

Electric Utility Subsidiary [Abstract]

Electric utility segment

Electric utility segment

Unconsolidated variable interest entities.

Power purchase agreements.  As of March 31, 2023, the Utilities had four power purchase agreements (PPAs) for firm capacity 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) and Hamakua Energy by reason of the provisions of the PPA that the Utilities have with the two IPPs. However, management has concluded that the Utilities are not the primary beneficiary of Kalaeloa and Hamakua Energy because the Utilities do not have the power to direct the activities that most significantly impact the two 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 and Hamakua Energy in its condensed consolidated financial statements. However, 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 legal, regulatory and environmental 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. The Utilities record loss contingencies when the outcome of such proceedings is probable and when the amount of the loss is reasonably estimable. The Utilities also evaluate, on a continuous basis, whether developments in such proceedings could cause these assessments or estimates to change. Assessment regarding future events is required when evaluating whether a loss is probable or reasonably possible, and as to whether such loss or a range of such loss is estimable. Management is often unable to estimate a reasonably possible loss, or a range of loss, particularly in cases in which: (i) the damages sought are indeterminate or the basis for the damages claimed is not clear; (ii) proceedings are in early stages; (iii) discovery is not complete; (iv) the matters involve novel or unsettled legal theories; (v) significant facts are in dispute; (vi) a large number of parties are represented (including circumstances in which it is uncertain how liability, if any, would be shared among multiple defendants); (vii) a lower court or administrative agency’s decision or ruling has been appealed; and/or (vii) a wide range of potential outcomes exist. In such cases, there may be considerable uncertainty regarding the timing or ultimate resolution, including any possible loss, fine, penalty, or business impact.

Power purchase agreements.  Purchases from all IPPs were as follows:

	Three months ended March 31
(in millions)	2023		2022
Kalaeloa	$	67	$	60
AES Hawaii 1	—		27
HPOWER	18		19
Hamakua Energy	20		16
Puna Geothermal Venture	8		10
Wind IPPs	24		18
Solar IPPs	14		13
Other IPPs 2	2		1
Total IPPs	$	153	$	164

1 The term of the PPA with AES Hawaii expired on September 1, 2022 and the AES Hawaii coal plant ceased operations.

2 Includes 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. 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. The Amended and Restated PPA was approved by the PUC on November 23, 2022. The new pricing provisions in the Amended and Restated PPA took effect on January 1, 2023.

Stage 1 Renewable PPAs. In February 2018, the Utilities issued their Stage 1 renewable request for proposals and have procured eight renewable PPAs with a total of 274.5 MW capacity. The total annual payments to be made by the Utilities under the eight renewable PPAs are estimated at $64.5 million. The Utilities have received PUC approvals to recover the total projected annual payments under the eight renewable PPAs through the purchased power adjustment clause (PPAC) to the extent such costs are not included in base rates. As of March 31, 2023, the Utilities have accounted for the battery portion of two PPAs that were placed in service during 2022 and first quarter of 2023 as finance leases and recorded lease liabilities with corresponding right-of-use assets of $88 million. On April 21, 2023, the AES Waikoloa Solar project with a capacity of 30 MW, including 120 MWh of batteries, was placed into commercial operation on Hawaii Island, and the battery portion of the PPA will be recorded as a finance lease during the second quarter of 2023. The timing of the Utilities’ recognition of the expense conforms to ratemaking treatment for the Utilities’ recovery of the cost of electricity and is included in purchased power for the interest and amortization of financing leases related to PPAs. Any material differences between expense recognition and timing of payments is deferred as a regulatory asset or liability in order to match what is being recovered for ratemaking purposes.

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. On May 23, 2022, the PUC issued a decision and order denying the amended and restated PPA, based on, among other things, findings that: (1) the project will result in significant greenhouse gas (GHG) emissions, (2) Hu Honua’s proposed carbon commitment to sequester more GHG emissions than produced by the project are speculative and unsupported, (3) the amended and restated PPA is likely to result in high costs to customers through its relatively high cost of electricity and through potential displacement of other, lower cost, renewable resources, and (4) based on the foregoing, approving the amended and restated PPA is not prudent or in the public interest. On June 2, 2022, Hawaii Electric Light and Hu Honua filed their separate motions for reconsideration, which were denied by the PUC on June 24, 2022. On June 29, 2022, Hu Honua filed its notice of appeal to the Hawaii Supreme Court of the PUC’s May 23, 2022 decision and order denying the amended and restated PPA, and the PUC’s June 24, 2022 order denying Hawaii Electric Light and Hu Honua’s motions for reconsideration. Opening briefs were filed with the Supreme Court on October 5, 2022. Answering briefs were filed on December 5, 2022, and reply briefs were filed on December 28, 2022. The Supreme Court heard oral arguments on January 31, 2023. On March 13, 2023, the Hawaii Supreme Court affirmed the PUC’s decision denying the amended and restated PPA between Hu Honua and Hawaii Electric Light and entered its judgment on appeal on April 12, 2023.

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 a 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 a minimum of $246 million ERP/EAM project-related benefit to be delivered to customers over the system’s 12-year service life.

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 other operation and maintenance (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 March 31, 2023, the Utilities’ regulatory liability was $11.0 million ($3.7 million for Hawaiian Electric, $2.9 million for Hawaii Electric Light and $4.4 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.

At the PUC’s direction, the Utilities have been filing Annual Enterprise System Benefits (AESB) report on the achieved benefits savings. The most recent AESB report was filed on February 14, 2023 for the period January 1 through December 31, 2022.

Waena Switchyard/Synchronous Condenser Project. In October 2020, to support efforts to increase renewable energy generation and reduce fossil fuel consumption by deactivating current generating units, Maui Electric filed a PUC application to construct a switchyard, which includes the extension of two 69 kV transmission lines and the relocation of another 69 kV transmission line; and the conversion of two generating units to synchronous condensers at Kahului Power Plant in central Maui. In November 2021, the PUC approved Maui Electric’s request to commit funds estimated at $38.8 million for the project, and to recover capital expenditures for the project under Exceptional Project Recovery Mechanism (EPRM) not to exceed $38.8 million, which shall be further reduced to reflect the total project cost exclusive of overhead costs not directly attributable to the project. The Waena Switchyard project is expected to be placed in service in the third quarter of 2023, while the conversion of the two generating units will be performed after the retirement of Kahului Power Plant Units 3 and 4.

In approving the project, the PUC recognized that the project will facilitate the ability to accommodate increased renewable energy, as contemplated under the EPRM guidelines. As of March 31, 2023, $17.1 million has been incurred for the project.

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 and left the property in 1987. The federal Environmental Protection Agency (EPA) has since identified environmental impacts in the subsurface soil at the Site. In cooperation with the Department of Health of State of Hawaii 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 $2.6 million as of March 31, 2023, representing the probable and reasonably estimable undiscounted cost for remediation of the Site and the adjacent parcel based on presently available information; however, final costs of remediation will depend on the cleanup approach implemented.

Additionally, on November 24, 2021, the current landowners of the Site, Misaki’s, Inc., filed a lawsuit against Hawaiian Electric (as alleged successor in interest to Molokai Electric, the prior owner of the Site) in the Circuit Court of the Second Circuit of the State of Hawaii (removed to the U.S. District Court for the District of Hawaii). The complaint, which was subsequently amended to include Maui Electric, alleges that Hawaiian Electric is responsible for remediation of the Site based on the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (CERCLA), and the Hawaii Environmental Response Law under Hawaii Revised Statutes Chapter 128D, as well as being liable on contractual claims related to a short leaseback period during the transition of ownership from Molokai Electric. The amended complaint was dismissed and a new complaint may be filed subject to the parties attempt to enter into settlement negotiations, but the Utilities

intend to vigorously defend the action if necessary. At this time, the Utilities are unable to determine the ultimate outcome of the lawsuit or the amount of any possible loss. As of March 31, 2023, the reserve balance recorded by the Utilities to address the lawsuit was not material.

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 under CERCLA 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 March 31, 2023, the reserve account balance recorded by Hawaiian Electric to address the PCB contamination was $9.9 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. Decoupling delinks the utility’s revenues from the utility’s sales, removing the disincentive to promote energy efficiency and accept more renewable energy. Decoupling continues under the PBR Framework.

Performance-based regulation framework. On December 23, 2020, the PUC issued a decision and order (PBR D&O) establishing the PBR Framework to govern the Utilities. The PBR Framework incorporates an annual revenue adjustment (ARA) and a suite of new regulatory mechanisms in addition to previously established regulatory mechanisms. Under the PBR Framework, the decoupling mechanism (i.e., the Revenue Balancing Account (RBA)) established by the previous regulatory framework will continue. The existing cost recovery mechanisms will continue as currently implemented (e.g., the Energy Cost Recovery Clause, PPAC, Demand Side Management surcharge, Renewable Energy Infrastructure Program, Demand Response Adjustment Clause, Pension and Other Post-Employment Benefits (OPEB) tracking mechanisms). In addition to annual revenues provided by the ARA, the Utilities may seek relief for extraordinary projects or programs through the Exceptional Project Recovery Mechanism (EPRM) (formerly known as the Major Project Interim Recovery adjustment mechanism) and earn financial rewards for exemplary performance as provided through a portfolio of Performance Incentive Mechanisms (PIMs) and Shared Savings Mechanisms (SSMs). The PBR Framework incorporates a variety of additional performance mechanisms, including Scorecards, Reported Metrics, and an expedited Pilot Process. The PBR Framework also contains a number of safeguards, including a symmetric Earnings Sharing Mechanism (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 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 PBR Framework became fully effective on June 1, 2021.

On June 17, 2022, the PUC issued a decision and order (June 2022 D&O) establishing additional PIMs under the PBR Framework for the Utilities. The June 2022 D&O approved two new PIMs, a new SSM, and extended the timeframe for an existing PIM. Of the new PIMs, only one is penalty-only. Specifically, the PUC approved (1) a new (penalty-only) generation-caused interruption reliability PIM, (2) a new (penalty/reward) interconnection requirements study (IRS) PIM, (3) a new (reward-only) Collective Shared Savings Mechanism (CSSM), and (4) a modification and extension of the existing interim (reward-only) Grid Services PIM. On November 23, 2022, the PUC approved the Utilities’ proposed tariffs to implement the aforementioned PIMs with an effective date of January 1, 2023.

In addition, the June 2022 D&O instructed the Utilities to prepare and submit: a detailed fossil fuel retirement report (FF Retirement Report) outlining necessary steps to safely and reliably retire certain existing fossil fuel power plants during the first multi-year rate period (MRP); and a functional integration plan (FIP) for distributed energy resources (DER) to increase transparency into the Utilities’ plans and progress for utilizing cost-effective grid services from DERs and ensure that the necessary functionalities and requisite technologies are in place to do so. The PUC also instructed the PBR Working Group to continue its ongoing collaborative efforts to consider other potential new incentive mechanisms and to address other issues raised during the proceeding. On March 30, 2023, the PUC held a PBR Working Group coordination meeting to initiate subgroups on the priority topics of a long-term DER Grid Services PIM, modification to/evaluation of existing PIMs, and a comprehensive PBR Framework review to be addressed in the near term.

In accordance with the June 2022 D&O, the Utilities filed their FIP and FF Retirement Report with the PUC on September 30, 2022 and April 17, 2023, respectively.

Revenue adjustment mechanism. Prior to the implementation of the PBR Framework, the revenue adjustment mechanism (RAM) was a major component of the previously established regulatory framework. The RAM was 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). Under the PBR Framework, the ARA mechanism replaced the RAM, and became effective on June 1, 2021. RAM revenue adjustments approved by the PUC in 2020 will continue to be included in the RBA provision’s target revenue and RBA rate adjustment unless modified with PUC approval.

Annual revenue adjustment mechanism. The PBR Framework established a five-year MRP 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% of adjusted revenue requirements compounded annually and a flow through of the “pre-PBR” savings commitment from the management audit recommendations developed in a prior docket at a rate of $6.6 million per year from 2021 to 2025. The implementation of the ARA occurred on June 1, 2021.

Earnings sharing mechanism. The PBR Framework established 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.

Exceptional project recovery mechanism. Prior to the implementation of the PBR Framework, the PUC established the Major Project Interim Recovery (MPIR) adjustment mechanism and MPIR Guidelines. The MPIR mechanism provides the opportunity to recover revenues for net costs of approved eligible projects placed in service between general rate cases. In establishing the PBR Framework, the MPIR Guidelines were terminated and replaced with the EPRM Guidelines. Although the MPIR Guidelines were terminated and replaced by the EPRM Guidelines, the MPIR mechanism will continue within the PBR Framework to provide recovery of project costs previously approved for recovery under the MPIR. The established EPRM Guidelines 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. Deferred and O&M expense projects are also eligible for EPRM recovery under the EPRM Guidelines. EPRM recoverable costs will be limited to the lesser of actual incurred project costs or PUC‑approved amounts, net of savings.

As of March 31, 2023, the Utilities annualized MPIR and EPRM revenue amounts totaled $26.2 million, including revenue taxes, for the Schofield Generating Station ($16.5 million), West Loch PV project ($3.5 million), Grid Modernization Strategy (GMS) Phase 1 project ($6.1 million for all three utilities) and Waiawa UFLS project ($0.1 million) that included the 2022 return on project amount (based on approved amounts) in rate base, depreciation and incremental O&M expenses. The PUC approved the Utilities’ recovery of the annualized 2022 MPIR amounts for the Schofield Generating Station, West Loch PV, and GMS Phase 1 projects effective June 1, 2022 through the RBA rate adjustment. Recovery of the incremental change to the West Loch PV project and Waiawa UFLS project were approved on December 7, 2022 and December 5, 2022, respectively.

As of March 31, 2023, the PUC approved two EPRM applications for projects totaling $41 million to the extent that the project costs are not included in rates. Currently, the Utilities are seeking EPRM recovery for six projects with total project costs up to $480 million, subject to PUC approval.

Pilot process. As part of the PBR Framework, the PUC approved a Pilot Process to foster innovation by establishing an expedited implementation process for pilots that tests new technologies, programs, business models, and other arrangements. Under the Pilot Process, the Utilities submit specific pilot proposals (Pilot Notices) that are within the scope of the approved Workplan to the PUC for their expedited review. The PUC will strive to issue an order addressing a proposed pilot within 45 days of the filing date of a Pilot Notice. If the PUC does not take affirmative action on a Pilot Notice by the end of the 45-day period, the Pilot Notice shall be considered approved as submitted. The PUC may modify the pilot as originally proposed, and the Utilities shall have 15 days to notify the PUC whether the Utilities accept the modification, propose further modification, or withdraw the Pilot Notice. The PUC may also, where necessary, suspend the Pilot Notice for further investigation.

The approved Pilot Process includes a cost recovery process that generally allows the Utilities to defer and recover total annual expenditures of approved pilot projects net of revenues, subject to an annual cap of $10 million, over 12 months beginning June 1 of the year following pilot implementation through the RBA rate adjustment, although the PUC may determine on a case-by-case basis that a particular project’s deferred costs should be amortized over a period greater than 12 months.

On February 28, 2023, the Utilities filed their annual Pilot Update report covering pilot projects that were active during 2022, including reporting on pilot projects that were initiated prior to the commencement of the Pilot Process. The Pilot Update reported on approximately $0.4 million of 2022 recorded pilot project costs including revenue taxes for the Utilities. The 2022 recorded pilot project costs were included in the Utilities’ proposed adjustments to target revenue in the 2023 spring revenue report filed on March 28, 2023.

On February 2, 2023, the Utilities filed a Pilot Notice to commence an EV Telematics Pilot project in April 2023. On March 22, 2023, the PUC issued an order approving the Utilities’ EV Telematics Pilot project. The order also temporarily suspends the filing of Pilot Notices, pending a stakeholder meeting to be held in the second quarter of 2023, to discuss the Pilot Process and potential improvements.

Performance incentive mechanisms. The PUC has established the following PIMs and SSMs: (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, (4) new PIMs established in the PBR D&O and (5) new PIMs and a SSM established in the June 2022 D&O.

•Service Quality performance incentives (ongoing). Service Quality performance incentives are measured on a calendar-year basis. The PIM tariff requires the performance targets, deadbands and the amount of maximum financial incentives used to determine the PIM financial incentive levels for each of the PIMs to remain constant in interim periods, unless otherwise amended by order of the PUC.

•Service Reliability Performance measured by Transmission and Distribution-caused 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). For the 2022 evaluation period, the Utilities incurred $(0.1) million in penalties.

•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 eight 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).

•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. The first portion 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 2025.

•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. On July 9, 2020, the Utilities filed two Grid Services Purchase Agreements (GSPA) 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 one PPA that qualified for a PIM incentive and on February 16, 2021, the Utilities filed one additional PPA that qualified for a declining PIM incentive. The PUC approved two PPAs in September 2021 and November 2021 and two GSPAs on December 31, 2020. Based on the two approved PPAs, the Utilities recognized $0.1 million in rewards in 2021. In December 2022 and March 2023, these two PPAs were terminated or declared null and void.

•The PUC previously established the following two PIMs in its PBR D&O, which were approved in an order issued on March 23, 2021 and became effective on June 1, 2021. In its June 2022 D&O, the PUC modified and extended the Grid Services PIM.

•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 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 PIM that provides financial rewards on a $/kW basis for the acquisition of eligible grid services. The eligibility period for this PIM initially commenced on January 1, 2021 and was scheduled to end on

December 31, 2022. However, the June 2022 D&O extended the eligibility period for this PIM through December 31, 2023. The June 2022 D&O also increased the incentive rate for the acquisition of load reduction grid services. During the PIM performance period, newly acquired committed capacity in the Oahu Scheduled Dispatch Program (SDP), the Oahu Fast DR program (up to the 7 MW cap), and the Maui SDP program shall qualify for the incentive. The Utilities can earn a maximum reward of $1.5 million from 2021 through 2023. In 2022, the Utilities earned $0.04 million in rewards.

•The PUC also previously established the following three 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 DER 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. In 2022, the Utilities earned $3.0 million in rewards.

•Low-to-Moderate Income (LMI) Energy Efficiency PIM that provides financial rewards 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. The Utilities earned $0.5 million in rewards for the program period ending 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.

•The PUC established the following new PIMs and SSM in its June 2022 D&O, which became effective on January 1, 2023.

•Generation-caused System Average Interruption Duration and Frequency Indexes PIMs to incentivize achievement of generation-based reliability targets, measured by Generation 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 3 basis points applied to the common equity share of each respective utility’s approved rate base (or maximum penalties of approximately $1 million - for both indices in total for the three utilities).

•An IRS PIM to incentivize the timely completion of the IRS process for large-scale renewable energy projects (rewards and penalties) measured by the number of months between final model checkout and delivery of IRS results to the developer. Target performance is ten months with an asymmetrical deadband of two-months for penalties and no deadband for rewards. The maximum penalty and reward will depend on the specifics of the upcoming procurement.

•A CSSM to incentivize cost control over the Utilities’ fuel, purchased power, and EPRM/MPIR costs (collectively, non-ARA costs). This is a reward only incentive where the Utilities retain 20% share of savings when non-ARA costs in a performance year are lower than target year non-ARA costs, which are adjusted for changes in fuel prices, inflation, and system generation from a base year (calendar year 2021). The CSSM does not have a potential penalty and does not have a cap for maximum reward.

For the 2022 evaluation period, the Utilities earned $3.4 million ($2.5 million for Hawaiian Electric, $0.4 million for Hawaii Electric Light and $0.5 million for Maui Electric) in rewards net of penalties. The net rewards related to 2022 were reflected in the 2023 PIMs annual report and 2023 spring revenue report filings.

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 spring revenue report on March 28, 2023, which is subject to PUC approval.

The net incremental amounts between the 2022 fall and 2023 spring revenue reports are shown in the following table. The amounts are to be collected (refunded) from June, 1, 2023 through May 31, 2024 under the RBA rate tariffs, which were included in the 2023 spring revenue report filing.

(in millions)	Hawaiian Electric		Hawaii Electric Light		Maui Electric		Total
Incremental Performance Incentive Mechanisms (net)	(0.4)		0.1		0.1		(0.2)
Incremental EPRM/MPIR Revenue Adjustment	2.5		1.4		1.0		4.9
Other	0.4		0.1		—		$	0.5
Net incremental amount to be collected under the RBA rate tariffs	$	2.5	$	1.5	$	1.1	$	5.1

Note: Columns may not foot due to rounding.

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. As the moratorium on customer disconnections ended on May 31, 2021, the Utilities have resumed charging late payment fees in July 2021. Pursuant to PUC orders, the deferral of COVID-19 related costs by the Utilities ended on December 31, 2020. On October 1, 2021, the PUC approved the Utilities’ request to extend the deferral period to December 31, 2021. In December 2021, to keep customers connected and provide some relief to customers experiencing financial difficulty during the pandemic, the Utilities committed to issuing $2 million in bill credits to qualified customers. The Utilities will not seek recovery for the issued bill credits, resulting in a reduction to the cumulative deferred costs. On June 9, 2022, the Utilities filed an application with the PUC, requesting recovery of a portion of the COVID-19 related deferral costs, net of cost savings realized, not to exceed the amount of $27.8 million over three years, from June 2023 through May 2026. Annual requests will be limited to actual costs incurred. On January 25, 2023, the PUC issued an order to modify the procedural schedule to allow more time for more discovery and consideration of the application. As of March 31, 2023, the Utilities have recorded $9.6 million in regulatory assets for deferral of COVID-19 related costs. The updated amounts have been reflected in the Utilities’ First Supplemental Report to the PUC filed on April 28, 2023.

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. On March 1, 2022, Hawaiian Electric acquired the Army’s existing distribution system for a purchase price of $14.5 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. The acquisition of additional assets contemplated in the contract, with an estimated value of $4 million, is planned for 2024.

Hawaiian Electric took ownership and all responsibilities for operation and maintenance of the system on March 1, 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 replace 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. 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.

Condensed consolidating financial information. Condensed consolidating financial information for Hawaiian Electric and its subsidiaries are presented for the three month periods ended March 31, 2023 and 2022, and as of March 31, 2023 and December 31, 2022.

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.

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Revenues	$	601,530	115,288	113,673	—	(130)	$	830,361
Expenses
Fuel oil	253,827		27,760	52,510	—	—	334,097
Purchased power	110,279		34,086	8,396	—	—	152,761
Other operation and maintenance	83,233		21,350	23,733	—	—	128,316
Depreciation	41,038		10,635	9,254	—	—	60,927
Taxes, other than income taxes	56,953		10,737	10,695	—	—	78,385
Total expenses	545,330		104,568	104,588	—	—	754,486
Operating income	56,200		10,720	9,085	—	(130)	75,875
Allowance for equity funds used during construction	2,640		284	377	—	—	3,301
Equity in earnings of subsidiaries	11,541		—	—	—	(11,541)	—
Retirement defined benefits credit (expense)—other than service costs	904		169	(26)	—	—	1,047
Interest expense and other charges, net	(14,557)		(2,831)	(2,988)	—	130	(20,246)
Allowance for borrowed funds used during construction	918		91	122	—	—	1,131
Income before income taxes	57,646		8,433	6,570	—	(11,541)	61,108
Income taxes	10,367		1,909	1,324	—	—	13,600
Net income	47,279		6,524	5,246	—	(11,541)	47,508
Preferred stock dividends of subsidiaries	—		134	95	—	—	229
Net income attributable to Hawaiian Electric	47,279		6,390	5,151	—	(11,541)	47,279
Preferred stock dividends of Hawaiian Electric	270		—	—	—	—	270
Net income for common stock	$	47,009	6,390	5,151	—	(11,541)	$	47,009

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Comprehensive Income

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net income for common stock	$	47,009	6,390	5,151	—	(11,541)	$	47,009
Other comprehensive loss, net of taxes:
Retirement benefit plans:
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes	(470)		(56)	(63)	—	119	(470)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	425		50	57	—	(107)	425
Other comprehensive loss, net of taxes	(45)		(6)	(6)	—	12	(45)
Comprehensive income attributable to common shareholder	$	46,964	6,384	5,145	—	(11,529)	$	46,964

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Revenues	$	500,242	108,528	100,028	—	(6)	$	708,792
Expenses
Fuel oil	154,425		25,251	41,610	—	—	221,286
Purchased power	124,183		30,712	8,638	—	—	163,533
Other operation and maintenance	83,656		20,214	21,387	—	—	125,257
Depreciation	39,484		10,351	8,636	—	—	58,471
Taxes, other than income taxes	47,274		10,032	9,344	—	—	66,650
Total expenses	449,022		96,560	89,615	—	—	635,197
Operating income	51,220		11,968	10,413	—	(6)	73,595
Allowance for equity funds used during construction	1,990		193	226	—	—	2,409
Equity in earnings of subsidiaries	13,661		—	—	—	(13,661)	—
Retirement defined benefits credit (expense)—other than service costs	855		167	(32)	—	—	990
Interest expense and other charges, net	(13,093)		(2,609)	(2,630)	—	6	(18,326)
Allowance for borrowed funds used during construction	651		60	67	—	—	778
Income before income taxes	55,284		9,779	8,044	—	(13,661)	59,446
Income taxes	8,605		2,268	1,665	—	—	12,538
Net income	46,679		7,511	6,379	—	(13,661)	46,908
Preferred stock dividends of subsidiaries	—		134	95	—	—	229
Net income attributable to Hawaiian Electric	46,679		7,377	6,284	—	(13,661)	46,679
Preferred stock dividends of Hawaiian Electric	270		—	—	—	—	270
Net income for common stock	$	46,409	7,377	6,284	—	(13,661)	$	46,409

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Comprehensive Income

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net income for common stock	$	46,409	7,377	6,284	—	(13,661)	$	46,409
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	4,376		670	603	—	(1,273)	4,376
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	(4,325)		(670)	(603)	—	1,273	(4,325)
Other comprehensive income, net of taxes	51		—	—	—	—	51
Comprehensive income attributable to common shareholder	$	46,460	7,377	6,284	—	(13,661)	$	46,460

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Balance Sheet

March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsi- diaries	Consoli- dating adjustments	Hawaiian Electric Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	42,860	5,606	3,594	—	—	$	52,060
Plant and equipment	5,302,293		1,431,852	1,308,747	—	—	8,042,892
Right-of-use assets - finance lease	88,297		—	—	—	—	88,297
Less accumulated depreciation	(1,889,007)		(651,463)	(593,341)	—	—	(3,133,811)
Construction in progress	248,788		28,136	38,938	—	—	315,862
Utility property, plant and equipment, net	3,793,231		814,131	757,938	—	—	5,365,300
Nonutility property, plant and equipment, less accumulated depreciation	5,298		115	1,532	—	—	6,945
Total property, plant and equipment, net	3,798,529		814,246	759,470	—	—	5,372,245
Investment in wholly owned subsidiaries, at equity	705,212		—	—	—	(705,212)	—
Current assets
Cash and cash equivalents	49,393		28,006	38,546	77	—	116,022
Customer accounts receivable, net	172,426		34,224	28,655	—	—	235,305
Accrued unbilled revenues, net	118,035		21,831	20,666	—	—	160,532
Other accounts receivable, net	22,376		3,883	4,677	—	(19,509)	11,427
Fuel oil stock, at average cost	116,295		16,678	24,610	—	—	157,583
Materials and supplies, at average cost	50,744		10,578	22,771	—	—	84,093
Prepayments and other	33,369		5,025	5,515	—	—	43,909
Regulatory assets	58,943		2,575	3,455	—	—	64,973
Total current assets	621,581		122,800	148,895	77	(19,509)	873,844
Other long-term assets
Operating lease right-of-use assets	40,724		32,599	11,607	—	—	84,930
Regulatory assets	151,684		19,041	12,204	—	—	182,929
Other	113,888		32,786	30,402	—	(16,561)	160,515
Total other long-term assets	306,296		84,426	54,213	—	(16,561)	428,374
Total assets	$	5,431,618	1,021,472	962,578	77	(741,282)	$	6,674,463
Capitalization and liabilities
Capitalization
Common stock equity	$	2,358,884	346,629	358,506	77	(705,212)	$	2,358,884
Cumulative preferred stock—not subject to mandatory redemption	22,293		7,000	5,000	—	—	34,293
Long-term debt, net	1,226,587		249,346	258,414	—	—	1,734,347
Total capitalization	3,607,764		602,975	621,920	77	(705,212)	4,127,524
Current liabilities
Current portion of operating lease liabilities	8,955		6,780	2,679	—	—	18,414
Current portion of long-term debt	49,987		19,994	29,992	—	—	99,973
Accounts payable	146,125		20,957	24,687	—	—	191,769
Interest and preferred dividends payable	20,788		3,839	4,740	—	—	29,367
Taxes accrued, including revenue taxes	178,418		34,570	33,926	—	—	246,914
Regulatory liabilities	9,505		7,918	7,811	—	—	25,234
Other	61,360		21,072	23,657	—	(19,509)	86,580
Total current liabilities	475,138		115,130	127,492	—	(19,509)	698,251
Deferred credits and other liabilities
Operating lease liabilities	39,387		26,087	9,159	—	—	74,633
Finance lease liabilities	84,341		—	—	—	—	84,341
Deferred income taxes	271,588		50,657	62,708	—	—	384,953
Regulatory liabilities	745,894		195,238	103,185	—	—	1,044,317
Unamortized tax credits	68,123		12,903	12,419	—	—	93,445
Defined benefit pension and other postretirement benefit plans liability	65,917		—	—	—	(16,529)	49,388
Other	73,466		18,482	25,695	—	(32)	117,611
Total deferred credits and other liabilities	1,348,716		303,367	213,166	—	(16,561)	1,848,688
Total capitalization and liabilities	$	5,431,618	1,021,472	962,578	77	(741,282)	$	6,674,463

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Balance Sheet

December 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsi-diaries	Consoli- dating adjustments	Hawaiian Electric Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	42,860	5,606	3,594	—	—	$	52,060
Plant and equipment	5,260,685		1,425,442	1,293,383	—	—	7,979,510
Finance lease right-of-use assets	48,371		—	—	—	—	48,371
Less accumulated depreciation	(1,855,150)		(644,457)	(586,892)	—	—	(3,086,499)
Construction in progress	215,560		23,989	35,804	—	—	275,353
Utility property, plant and equipment, net	3,712,326		810,580	745,889	—	—	5,268,795
Nonutility property, plant and equipment, less accumulated depreciation	5,298		115	1,532	—	—	6,945
Total property, plant and equipment, net	3,717,624		810,695	747,421	—	—	5,275,740
Investment in wholly owned subsidiaries, at equity	701,833		—	—	—	(701,833)	—
Current assets
Cash and cash equivalents	27,579		5,092	6,494	77	—	39,242
Advances to affiliates	—		4,500	21,700	—	(26,200)	—
Customer accounts receivable, net	216,802		39,339	32,197	—	—	288,338
Accrued unbilled revenues, net	136,508		23,839	22,933	—	—	183,280
Other accounts receivable, net	23,746		5,519	6,686	—	(22,384)	13,567
Fuel oil stock, at average cost	153,342		16,964	21,224	—	—	191,530
Materials and supplies, at average cost	48,130		9,783	21,655	—	—	79,568
Prepayments and other	24,040		6,346	4,137	—	(1,041)	33,482
Regulatory assets	46,504		2,435	3,334	—	—	52,273
Total current assets	676,651		113,817	140,360	77	(49,625)	881,280
Other long-term assets
Operating lease right-of-use assets	42,752		34,283	12,283	—	—	89,318
Regulatory assets	154,040		21,816	14,384	—	—	190,240
Other	115,028		32,654	29,495	—	(16,288)	160,889
Total other long-term assets	311,820		88,753	56,162	—	(16,288)	440,447
Total assets	$	5,407,928	1,013,265	943,943	77	(767,746)	$	6,597,467
Capitalization and liabilities
Capitalization
Common stock equity	$	2,344,170	344,720	357,036	77	(701,833)	$	2,344,170
Cumulative preferred stock—not subject to mandatory redemption	22,293		7,000	5,000	—	—	34,293
Long-term debt, net	1,126,915		224,439	233,500	—	—	1,584,854
Total capitalization	3,493,378		576,159	595,536	77	(701,833)	3,963,317
Current liabilities
Current portion of operating lease liabilities	9,775		6,690	2,630	—	—	19,095
Current portion of long-term debt	49,981		19,992	29,989	—	—	99,962
Short-term borrowings-affiliate	26,200		—	—	—	(26,200)	—
Accounts payable	143,253		32,113	27,126	—	—	202,492
Interest and preferred dividends payable	12,398		2,576	2,282	—	(80)	17,176
Taxes accrued, including revenue taxes	207,798		42,436	40,709	—	(1,041)	289,902
Regulatory liabilities	13,145		8,553	9,777	—	—	31,475
Other	64,659		20,856	22,385	—	(22,304)	85,596
Total current liabilities	615,176		133,216	134,898	—	(49,625)	833,665
Deferred credits and other liabilities
Operating lease liabilities	41,049		27,817	9,849	—	—	78,715
Finance lease liabilities	46,048		—	—	—	—	46,048
Deferred income taxes	271,234		50,615	62,581	—	—	384,430
Regulatory liabilities	729,683		194,222	100,270	—	—	1,024,175
Unamortized tax credits	69,614		13,150	12,536	—	—	95,300
Defined benefit pension and other postretirement benefit plans liability	65,907		129	—	—	(16,288)	49,748
Other	75,839		17,957	28,273		—	122,069
Total deferred credits and other liabilities	1,299,374		303,890	213,509	—	(16,288)	1,800,485
Total capitalization and liabilities	$	5,407,928	1,013,265	943,943	77	(767,746)	$	6,597,467

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Changes in Common Stock Equity

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Balance, December 31, 2022	$	2,344,170	344,720	357,036	77	(701,833)	$	2,344,170
Net income for common stock	47,009		6,390	5,151	—	(11,541)	47,009
Other comprehensive loss, net of taxes	(45)		(6)	(6)	—	12	(45)
Common stock dividends	(32,250)		(4,475)	(3,675)	—	8,150	(32,250)
Balance, March 31, 2023	$	2,358,884	346,629	358,506	77	(705,212)	$	2,358,884

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Changes in Common Stock Equity

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Balance, December 31, 2021	$	2,261,899	332,900	343,260	77	(676,237)	$	2,261,899
Net income for common stock	46,409		7,377	6,284	—	(13,661)	46,409
Other comprehensive income, net of taxes	51		—	—	—	—	51
Common stock dividends	(31,475)		(4,100)	(3,800)	—	7,900	(31,475)
Balance, March 31, 2022	$	2,276,884	336,177	345,744	77	(681,998)	$	2,276,884

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Cash Flows

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net cash provided by operating activities	$	143,356	18,733	15,416	—	(8,150)	$	169,355
Cash flows from investing activities
Capital expenditures	(74,916)		(20,747)	(26,476)	—	—	(122,139)
Advances to affiliates	—		4,500	21,700	—	(26,200)	—
Other	1,094		153	298	—	—	1,545
Net cash used in investing activities	(73,822)		(16,094)	(4,478)	—	(26,200)	(120,594)
Cash flows from financing activities
Common stock dividends	(32,250)		(4,475)	(3,675)	—	8,150	(32,250)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(270)		(134)	(95)	—	—	(499)
Proceeds from issuance of long-term debt	100,000		25,000	25,000	—	—	150,000
Net decrease in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less	(114,167)		—	—	—	26,200	(87,967)
Payments of obligations under finance leases	(575)		—	—	—	—	(575)
Other	(458)		(116)	(116)	—	—	(690)
Net cash provided by (used in) financing activities	(47,720)		20,275	21,114	—	34,350	28,019
Net increase in cash and cash equivalents	21,814		22,914	32,052	—	—	76,780
Cash and cash equivalents, beginning of period	27,579		5,092	6,494	77	—	39,242
Cash and cash equivalents, end of period	$	49,393	28,006	38,546	77	—	$	116,022

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Cash Flows

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net cash provided by operating activities	$	55,669	15,778	13,228	—	(7,900)	$	76,775
Cash flows from investing activities
Capital expenditures	(44,084)		(15,133)	(17,141)	—	—	(76,358)
Advances to affiliates	(4,000)		—	(12,800)	—	16,800	—
Other	961		280	253	—	—	1,494
Net cash used in investing activities	(47,123)		(14,853)	(29,688)	—	16,800	(74,864)
Cash flows from financing activities
Common stock dividends	(31,475)		(4,100)	(3,800)	—	7,900	(31,475)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(270)		(134)	(95)	—	—	(499)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less	18,800		4,000	—	—	(16,800)	6,000
Net cash used in financing activities	(12,945)		(234)	(3,895)	—	(8,900)	(25,974)
Net increase (decrease) in cash and cash equivalents	(4,399)		691	(20,355)	—	—	(24,063)
Cash, cash equivalents and restricted cash, beginning of period	26,433		5,326	23,422	77	—	55,258
Cash, cash equivalents and restricted cash, end of period	22,034		6,017	3,067	77	—	31,195
Less: Restricted cash	(2,140)		—	—	—	—	(2,140)
Cash and cash equivalents, end of period	$	19,894	6,017	3,067	77	—	$	29,055

XML

Bank segment

3 Months Ended

Mar. 31, 2023

Bank Subsidiary [Abstract]

Bank segment

Bank segment

Selected financial information

American Savings Bank, F.S.B.

Statements of Income and Comprehensive Income Data

	Three months ended March 31
(in thousands)	2023		2022
Interest and dividend income
Interest and fees on loans	$	64,842	$	46,005
Interest and dividends on investment securities	14,637		13,984
Total interest and dividend income	79,479		59,989
Interest expense
Interest on deposit liabilities	6,837		947
Interest on other borrowings	7,721		5
Total interest expense	14,558		952
Net interest income	64,921		59,037
Provision for credit losses	1,175		(3,263)
Net interest income after provision for credit losses	63,746		62,300
Noninterest income
Fees from other financial services	4,679		5,587
Fee income on deposit liabilities	4,599		4,691
Fee income on other financial products	2,744		2,718
Bank-owned life insurance	1,425		681
Mortgage banking income	130		1,077
Gain on sale of real estate	—		1,002
Other income, net	801		372
Total noninterest income	14,378		16,128
Noninterest expense
Compensation and employee benefits	30,204		27,215
Occupancy	5,588		5,952
Data processing	5,012		4,151
Services	2,595		2,439
Equipment	2,646		2,329
Office supplies, printing and postage	1,165		1,060
Marketing	1,016		1,018
Other expense	6,191		4,049
Total noninterest expense	54,417		48,213
Income before income taxes	23,707		30,215
Income taxes	5,145		6,345
Net income	18,562		23,870
Other comprehensive income (loss), net of taxes	18,430		(122,441)
Comprehensive income (loss)	$	36,992	$	(98,571)

Reconciliation to amounts per HEI Condensed Consolidated Statements of Income*:

	Three months ended March 31
(in thousands)	2023		2022
Interest and dividend income	$	79,479	$	59,989
Noninterest income	14,378		16,128
Less: Gain on sale of real estate	—		1,002
*Revenues-Bank	93,857		75,115
Total interest expense	14,558		952
Provision for credit losses	1,175		(3,263)
Noninterest expense	54,417		48,213
Less: Gain on sale of real estate	—		1,002
Less: Retirement defined benefits credit—other than service costs	(187)		(185)
*Expenses-Bank	70,337		45,085
*Operating income-Bank	23,520		30,030
Add back: Retirement defined benefits credit—other than service costs	(187)		(185)
Income before income taxes	$	23,707	$	30,215

American Savings Bank, F.S.B.

Balance Sheets Data

(in thousands)	March 31, 2023				December 31, 2022
Assets
Cash and due from banks			$	138,742			$	153,042
Interest-bearing deposits			44,315				3,107
Cash and cash equivalents			183,057				156,149
Investment securities
Available-for-sale, at fair value			1,419,755				1,429,667
Held-to-maturity, at amortized cost (fair value of $1,158,090 and $1,150,971, respectively)			1,238,185				1,251,747
Stock in Federal Home Loan Bank, at cost			10,000				26,560
Loans held for investment			6,059,354				5,978,906
Allowance for credit losses			(71,296)				(72,216)
Net loans			5,988,058				5,906,690
Loans held for sale, at lower of cost or fair value			660				824
Other			688,165				692,143
Goodwill			82,190				82,190
Total assets			$	9,610,070			$	9,545,970
Liabilities and shareholder’s equity
Deposit liabilities—noninterest-bearing			$	2,769,789			$	2,811,077
Deposit liabilities—interest-bearing			5,460,812				5,358,619
Other borrowings			680,690				695,120
Other			206,317				212,269
Total liabilities			9,117,608				9,077,085
Common stock			1				1
Additional paid-in capital			356,391				355,806
Retained earnings			454,255				449,693
Accumulated other comprehensive loss, net of tax benefits
Net unrealized losses on securities	$	(308,622)			$	(328,904)
Retirement benefit plans	(9,563)		(318,185)		(7,711)		(336,615)
Total shareholder’s equity			492,462				468,885
Total liabilities and shareholder’s equity			$	9,610,070			$	9,545,970
Other assets
Bank-owned life insurance			$	183,936			$	182,986
Premises and equipment, net			192,789				195,324
Accrued interest receivable			26,547				25,077
Mortgage-servicing rights			8,745				9,047
Low-income housing investments			110,748				106,978
Real estate held for sale			100				—
Deferred tax asset			109,885				116,441
Real estate acquired in settlement of loans, net			614				115
Other			54,801				56,175
			$	688,165			$	692,143
Other liabilities
Accrued expenses			$	95,066			$	97,295
Federal and state income taxes payable			2,614				863
Cashier’s checks			34,616				36,401
Advance payments by borrowers			5,466				9,637
Other			68,555				68,073
			$	206,317			$	212,269

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 FHLB advances, borrowings from the Federal Reserve Bank and securities sold under agreements to repurchase.

Investment securities.  The major components of investment securities were as follows:

	Amortized cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value		Gross unrealized losses
									Less than 12 months					12 months or longer
(dollars in thousands)									Number of issues	Fair  value		Amount		Number of issues	Fair  value		Amount
March 31, 2023
Available-for-sale
U.S. Treasury and federal agency obligations	$	85,786	$	—	$	(6,042)	$	79,744	—	$	—	$	—	14	$	79,744	$	(6,042)
Mortgage-backed securities*	1,500,717		1		(216,783)		1,283,935		24	89,727		(7,367)		158	1,193,633		(209,416)
Corporate bonds	44,341		—		(3,031)		41,310		2	8,951		(50)		3	32,359		(2,981)
Mortgage revenue bonds	14,766		—		—		14,766		—	—		—		—	—		—
	$	1,645,610	$	1	$	(225,856)	$	1,419,755	26	$	98,678	$	(7,417)	175	$	1,305,736	$	(218,439)
Held-to-maturity
U.S. Treasury and federal agency obligations	$	59,900	$	—	$	(7,172)	$	52,728	—	$	—	$	—	3	$	52,728	$	(7,172)
Mortgage-backed securities*	1,178,285		8,875		(81,798)		1,105,362		6	64,288		(532)		41	427,520		(81,266)
	$	1,238,185	$	8,875	$	(88,970)	$	1,158,090	6	$	64,288	$	(532)	44	$	480,248	$	(88,438)
December 31, 2022
Available-for-sale
U.S. Treasury and federal agency obligations	$	88,344	$	—	$	(7,281)	$	81,063	12	$	41,201	$	(2,120)	4	$	39,862	$	(5,161)
Mortgage-backed securities*	1,530,582		—		(237,614)		1,292,968		113	455,836		(56,999)		70	837,132		(180,615)
Corporate bonds	44,377		—		(3,643)		40,734		4	29,644		(2,028)		1	11,090		(1,615)
Mortgage revenue bonds	14,902		—		—		14,902		—	—		—		—	—		—
	$	1,678,205	$	—	$	(248,538)	$	1,429,667	129	$	526,681	$	(61,147)	75	$	888,084	$	(187,391)
Held-to-maturity
U.S. Treasury and federal agency obligations	$	59,894	$	—	$	(8,478)	$	51,416	1	$	16,874	$	(3,222)	2	$	34,542	$	(5,256)
Mortgage-backed securities*	1,191,853		2,670		(94,968)		1,099,555		22	183,629		(10,593)		51	567,250		(84,375)
	$	1,251,747	$	2,670	$	(103,446)	$	1,150,971	23	$	200,503	$	(13,815)	53	$	601,792	$	(89,631)

* 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 March 31, 2023 and December 31, 2022, 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 rated 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 March 31, 2023 and December 31, 2022.

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.

The contractual maturities of investment securities were as follows:

March 31, 2023	Amortized  cost		Fair value
(in thousands)
Available-for-sale
Due in one year or less	$	2,579	$	2,531
Due after one year through five years	127,548		118,523
Due after five years through ten years	14,766		14,766
Due after ten years	—		—
	144,893		135,820
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	1,500,717		1,283,935
Total available-for-sale securities	$	1,645,610	$	1,419,755
Held-to-maturity
Due in one year or less	$	—	$	—
Due after one year through five years	—		—
Due after five years through ten years	59,900		52,728
Due after ten years	—		—
	59,900		52,728
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	1,178,285		1,105,362
Total held-to-maturity securities	$	1,238,185	$	1,158,090

There were no sales of available-for-sale securities for the quarters ended March 31, 2023 and 2022.

The components of loans were summarized as follows:

	March 31, 2023		December 31, 2022
(in thousands)
Real estate:
Residential 1-4 family	$	2,484,316	$	2,479,637
Commercial real estate	1,377,184		1,358,123
Home equity line of credit	1,022,800		1,002,905
Residential land	20,061		20,679
Commercial construction	94,267		88,489
Residential construction	15,749		20,788
Total real estate	5,014,377		4,970,621
Commercial	800,949		779,691
Consumer	272,401		254,709
Total loans	6,087,727		6,005,021
Less: Deferred fees and discounts	(28,373)		(26,115)
Allowance for credit losses	(71,296)		(72,216)
Total loans, net	$	5,988,058	$	5,906,690

ASB's policy is to require private mortgage insurance on all real estate loans when the loan-to-value ratio of the property exceeds 80% of the lower of the appraised value or purchase price at origination. For non-owner occupied residential property purchases, the loan-to-value ratio may not exceed 75% of the lower of the appraised value or purchase price at origination.

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 land		Commercial construction		Residential construction		Commercial loans		Consumer loans		Total
Three months ended March 31, 2023
Allowance for credit losses:
Beginning balance	$	6,270	$	21,898	$	6,125	$	717	$	1,195	$	46	$	12,426	$	23,539	$	72,216
Charge-offs	(809)		—		(63)		—		—		—		(227)		(2,323)		(3,422)
Recoveries	4		—		17		—		—		—		398		908		1,327
Provision	(853)		803		(26)		(97)		(460)		(18)		(661)		2,487		1,175
Ending balance	$	4,612	$	22,701	$	6,053	$	620	$	735	$	28	$	11,936	$	24,611	$	71,296
Three months ended March 31, 2022
Allowance for credit losses:
Beginning balance	$	6,545	$	24,696	$	5,657	$	646	$	2,186	$	18	$	15,798	$	15,584	$	71,130
Charge-offs	—		—		—		—		—		—		(76)		(1,482)		(1,558)
Recoveries	8		—		11		5		—		—		353		1,025		1,402
Provision	1,321		(4,520)		(18)		46		154		13		(1,761)		1,002		(3,763)
Ending balance	$	7,874	$	20,176	$	5,650	$	697	$	2,340	$	31	$	14,314	$	16,129	$	67,211

Allowance for loan commitments.  The allowance for loan commitments by portfolio segment were as follows:

(in thousands)	Home equity  line of credit		Commercial construction		Commercial loans		Total
Three months ended March 31, 2023
Allowance for loan commitments:
Beginning balance	$	400	$	2,600	$	1,400	$	4,400
Provision	—		—		—		—
Ending balance	$	400	$	2,600	$	1,400	$	4,400
Three months ended March 31, 2022
Allowance for loan commitments:
Beginning balance	$	400	$	3,700	$	800	$	4,900
Provision	—		(100)		600		500
Ending balance	$	400	$	3,600	$	1,400	$	5,400

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.

The credit risk profile by vintage date based on payment activity or internally assigned grade for loans was as follows:

	Term Loans by Origination Year												Revolving Loans
(in thousands)	2023		2022		2021		2020		2019		Prior		Revolving		Converted to term loans		Total
March 31, 2023
Residential 1-4 family
Current	$	46,292	$	425,843	$	750,578	$	418,780	$	110,618	$	727,411	$	—	$	—	$	2,479,522
30-59 days past due	—		—		—		—		938		971		—		—		1,909
60-89 days past due	—		—		—		—		—		930		—		—		930
Greater than 89 days past due	—		—		—		267		—		1,688		—		—		1,955
	46,292		425,843		750,578		419,047		111,556		731,000		—		—		2,484,316
Current YTD period
Gross charge-offs	—		—		—		—		—		809		—		—		809
Home equity line of credit
Current	—		—		—		—		—		—		973,686		46,565		1,020,251
30-59 days past due	—		—		—		—		—		—		781		115		896
60-89 days past due	—		—		—		—		—		—		346		337		683
Greater than 89 days past due	—		—		—		—		—		—		573		397		970
	—		—		—		—		—		—		975,386		47,414		1,022,800
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		63		63
Residential land
Current	1,204		5,237		8,587		4,039		—		994		—		—		20,061
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	1,204		5,237		8,587		4,039		—		994		—		—		20,061
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Residential construction
Current	1,444		6,786		7,519		—		—		—		—		—		15,749
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	1,444		6,786		7,519		—		—		—		—		—		15,749
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Consumer
Current	36,794		189,133		18,047		4,233		4,301		341		9,589		4,904		267,342
30-59 days past due	203		1,628		235		54		170		11		78		120		2,499
60-89 days past due	—		899		116		59		129		4		16		117		1,340
Greater than 89 days past due	—		502		199		59		105		26		82		247		1,220
	36,997		192,162		18,597		4,405		4,705		382		9,765		5,388		272,401
Current YTD period
Gross charge-offs	189		1,523		319		57		135		21		15		64		2,323
Commercial real estate
Pass	41,312		392,018		174,655		276,754		52,121		339,660		8,235		—		1,284,755
Special Mention	—		—		11,250		3,425		30,179		21,307		—		—		66,161
Substandard	5,433		—		—		659		11,356		8,820		—		—		26,268
Doubtful	—		—		—		—		—		—		—		—		—
	46,745		392,018		185,905		280,838		93,656		369,787		8,235		—		1,377,184

	Term Loans by Origination Year												Revolving Loans
(in thousands)	2023		2022		2021		2020		2019		Prior		Revolving		Converted to term loans		Total
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Commercial construction
Pass	—		11,206		54,924		44		—		—		28,093		—		94,267
Special Mention	—		—		—		—		—		—		—		—		—
Substandard	—		—		—		—		—		—		—		—		—
Doubtful	—		—		—		—		—		—		—		—		—
	—		11,206		54,924		44		—		—		28,093		—		94,267
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Commercial
Pass	30,142		238,671		184,551		86,275		60,265		97,277		66,200		12,918		776,299
Special Mention	—		—		—		—		2,255		—		8,492		6		10,753
Substandard	—		3,234		1,507		398		1,320		5,195		899		1,344		13,897
Doubtful	—		—		—		—		—		—		—		—		—
	30,142		241,905		186,058		86,673		63,840		102,472		75,591		14,268		800,949
Current YTD period
Gross charge-offs	—		—		51		—		—		—		14		162		227
Total loans	$	162,824	$	1,275,157	$	1,212,168	$	795,046	$	273,757	$	1,204,635	$	1,097,070	$	67,070	$	6,087,727

	Term Loans by Origination Year												Revolving Loans
(in thousands)	2022		2021		2020		2019		2018		Prior		Revolving		Converted to term loans		Total
December 31, 2022
Residential 1-4 family
Current	$	432,707	$	755,056	$	423,455	$	113,096	$	51,860	$	698,354	$	—	$	—	$	2,474,528
30-59 days past due	—		—		—		—		448		1,098		—		—		1,546
60-89 days past due	—		—		268		—		—		90		—		—		358
Greater than 89 days past due	—		—		—		—		809		2,396		—		—		3,205
	432,707		755,056		423,723		113,096		53,117		701,938		—		—		2,479,637
Home equity line of credit
Current	—		—		—		—		—		—		959,131		40,814		999,945
30-59 days past due	—		—		—		—		—		—		1,103		209		1,312
60-89 days past due	—		—		—		—		—		—		209		226		435
Greater than 89 days past due	—		—		—		—		—		—		587		626		1,213
	—		—		—		—		—		—		961,030		41,875		1,002,905
Residential land
Current	5,245		9,010		5,222		203		522		477		—		—		20,679
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	5,245		9,010		5,222		203		522		477		—		—		20,679
Residential construction
Current	7,986		11,624		1,178		—		—		—		—		—		20,788
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	7,986		11,624		1,178		—		—		—		—		—		20,788
Consumer
Current	199,574		21,330		5,543		7,580		527		140		10,810		4,782		250,286
30-59 days past due	1,110		287		65		239		30		—		81		167		1,979
60-89 days past due	756		163		88		137		19		—		45		107		1,315
Greater than 89 days past due	621		105		37		176		28		—		20		142		1,129
	202,061		21,885		5,733		8,132		604		140		10,956		5,198		254,709
Commercial real estate
Pass	390,206		177,130		283,321		51,542		63,084		278,280		8,235		—		1,251,798
Special Mention	—		11,250		3,446		40,423		—		24,466		—		—		79,585
Substandard	—		—		665		11,357		—		14,718		—		—		26,740
Doubtful	—		—		—		—		—		—		—		—		—
	390,206		188,380		287,432		103,322		63,084		317,464		8,235		—		1,358,123
Commercial construction
Pass	15,094		47,478		44		—		—		—		25,873		—		88,489
Special Mention	—		—		—		—		—		—		—		—		—
Substandard	—		—		—		—		—		—		—		—		—
Doubtful	—		—		—		—		—		—		—		—		—
	15,094		47,478		44		—		—		—		25,873		—		88,489
Commercial
Pass	239,852		185,013		85,220		68,161		46,142		53,192		60,871		13,964		752,415
Special Mention	—		—		—		2,374		—		645		9,005		8		12,032
Substandard	3,322		2,305		401		1,304		1,346		3,849		1,664		1,053		15,244
Doubtful	—		—		—		—		—		—		—		—		—
	243,174		187,318		85,621		71,839		47,488		57,686		71,540		15,025		779,691
Total loans	$	1,296,473	$	1,220,751	$	808,953	$	296,592	$	164,815	$	1,077,705	$	1,077,634	$	62,098	$	6,005,021

Revolving loans converted to term loans during the three months ended March 31, 2023 in the commercial, home equity line of credit and consumer portfolios were $1.2 million, $7.8 million and $1.1 million, respectively. Revolving loans converted to term loans during the three months ended March 31, 2022 in the commercial, home equity line of credit and consumer portfolios were $0.5 million, $4.4 million and $1.0 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		Current		Total financing receivables		Amortized cost> 90 days and accruing
March 31, 2023
Real estate:
Residential 1-4 family	$	1,909	$	930	$	1,955	$	4,794	$	2,479,522	$	2,484,316	$	—
Commercial real estate	—		—		—		—		1,377,184		1,377,184		—
Home equity line of credit	896		683		970		2,549		1,020,251		1,022,800		—
Residential land	—		—		—		—		20,061		20,061		—
Commercial construction	—		—		—		—		94,267		94,267		—
Residential construction	—		—		—		—		15,749		15,749		—
Commercial	263		71		427		761		800,188		800,949		—
Consumer	2,499		1,340		1,220		5,059		267,342		272,401		—
Total loans	$	5,567	$	3,024	$	4,572	$	13,163	$	6,074,564	$	6,087,727	$	—
December 31, 2022
Real estate:
Residential 1-4 family	$	1,546	$	358	$	3,205	$	5,109	$	2,474,528	$	2,479,637	$	—
Commercial real estate	508		217		—		725		1,357,398		1,358,123		—
Home equity line of credit	1,312		435		1,213		2,960		999,945		1,002,905		—
Residential land	—		—		—		—		20,679		20,679		—
Commercial construction	—		—		—		—		88,489		88,489		—
Residential construction	—		—		—		—		20,788		20,788		—
Commercial	614		18		77		709		778,982		779,691		—
Consumer	1,979		1,315		1,129		4,423		250,286		254,709		—
Total loans	$	5,959	$	2,343	$	5,624	$	13,926	$	5,991,095	$	6,005,021	$	—

The credit risk profile based on nonaccrual loans were as follows:

(in thousands)	March 31, 2023						December 31, 2022
	With a Related ACL		Without a Related ACL		Total		With a Related ACL		Without a Related ACL		Total
Real estate:
Residential 1-4 family	$	3,371	$	2,117	$	5,488	$	4,198	$	2,981	$	7,179
Commercial real estate	—		—		—		—		—		—
Home equity line of credit	4,014		1,237		5,251		3,654		1,442		5,096
Residential land	109		—		109		420		—		420
Commercial construction	—		—		—		—		—		—
Residential construction	—		—		—		—		—		—
Commercial	1,744		—		1,744		2,183		—		2,183
Consumer	1,895		—		1,895		1,588		—		1,588
Total	$	11,133	$	3,354	$	14,487	$	12,043	$	4,423	$	16,466

ASB did not recognize interest on nonaccrual loans for the three months ended March 31, 2023 and 2022.

Modifications Made to Borrowers Experiencing Financial Difficulty. The allowance for credit losses incorporates an estimate of lifetime expected credit losses and is recorded on each asset upon origination. The starting point for the estimate of the allowance for credit losses is historical loan information, which includes losses from modifications of receivables to borrowers experiencing financial difficulty. ASB uses a probability of default/loss given default model to determine the allowance for credit losses. An assessment of whether a borrower is experiencing financial difficulty is made at the time of the modification.

Because the effect of most modifications made to borrowers experiencing financial difficulty is already included in the allowance for credit losses, a change to the allowance for credit losses is generally not recorded upon modification.

Modifications may include interest rate reductions, interest only payments for an extended period of time, protracted terms such as amortization and maturity beyond the customary length of time found in the normal marketplace, and other actions intended to minimize economic loss and to provide alternatives to foreclosure or repossession of collateral.

During the first three months of 2023, no loans received a material modification based on borrower financial difficulty.

Troubled debt restructurings. Prior to January 1, 2023, a loan modification was 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. With the adoption of ASU No. 2022-02, accounting guidance for TDRs by creditors is eliminated. Loan refinancing and restructuring guidance is applied to determine whether a modification results in a new loan or a continuation of an existing loan. ASB will continue TDR disclosures for years prior to the adoption of ASU No. 2022-02.

The credit risk profile based on loans whose terms have been modified and accruing interest were as follows:

(in thousands)	December 31, 2022
Real estate:
Residential 1-4 family	$	8,821
Commercial real estate	9,477
Home equity line of credit	4,404
Residential land	782
Commercial construction	—
Residential construction	—
Commercial	6,596
Consumer	50
Total troubled debt restructured loans accruing interest	$	30,130

Loans modified as a TDR.  There were no loan modifications that occurred during the three months ended March 31, 2022.

There were no loans modified in TDRs that experienced a payment default of 90 days or more during the first three months of 2022.

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 December 31, 2022.

Collateral-dependent loans. A loan is considered collateral-dependent when the borrower is experiencing financial difficulty and repayment of the loan is expected to be provided substantially through the operation or sale of the collateral. Loans considered collateral-dependent were as follows:

	Amortized cost
(in thousands)	March 31, 2023		December 31, 2022		Collateral type
Real estate:
Residential 1-4 family	$	2,353	$	3,959	Residential real estate property
Home equity line of credit	1,237		1,425		Residential real estate property
Total	$	3,590	$	5,384

ASB had $3.4 million and $4.2 million of consumer mortgage loans collateralized by residential real estate property that were in the process of foreclosure at March 31, 2023 and December 31, 2022, 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 $5.7 million and $75.6 million for the three months ended March 31, 2023 and 2022, respectively, and recognized gains on such sales of $0.1 million and $1.1 million for the three months ended March 31, 2023 and 2022, respectively.

There were no repurchased mortgage loans for the three months ended March 31, 2023 and 2022.

Mortgage servicing fees, a component of other income, net, were $0.9 million for the three months ended March 31, 2023 and 2022.

Changes in the carrying value of MSRs were as follows:

(in thousands)	Gross carrying amount		Accumulated amortization		Valuation allowance		Net carrying amount
March 31, 2023	$	17,868	$	(9,123)	$	—	$	8,745
December 31, 2022	19,544		(10,497)		—		9,047

Changes related to MSRs were as follows:

	Three months ended March 31
(in thousands)	2023		2022
Mortgage servicing rights
Beginning balance	$	9,047	$	9,950
Amount capitalized	51		719
Amortization	(353)		(645)
Other-than-temporary impairment	—		—
Carrying amount before valuation allowance	8,745		10,024
Valuation allowance for mortgage servicing rights
Beginning balance	—		—
Provision	—		—
Other-than-temporary impairment	—		—
Ending balance	—		—
Net carrying value of mortgage servicing rights	$	8,745	$	10,024

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)	March 31, 2023			December 31, 2022
Unpaid principal balance	$	1,431,037		$	1,451,322
Weighted average note rate	3.39		%	3.38		%
Weighted average discount rate	10.00		%	10.00		%
Weighted average prepayment speed	6.39		%	6.56		%

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)	March 31, 2023		December 31, 2022
Prepayment rate:
25 basis points adverse rate change	$	(109)	$	(92)
50 basis points adverse rate change	(243)		(214)
Discount rate:
25 basis points adverse rate change	(190)		(182)
50 basis points adverse rate change	(376)		(361)

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 March 31, 2023 and December 31, 2022, ASB had nil and $414.0 million of FHLB advances outstanding, respectively, and borrowings with the Federal Reserve Bank of $550.0 million and nil, respectively. As of March 31, 2023, ASB was in compliance with all FHLB Advances, Pledge and Security Agreement requirements and all requirements to borrow at the Federal Reserve Discount Window Primary Credit Facility under 12 CFR 201.4(a) guidelines.

Securities sold under agreements to repurchase are accounted for as financing transactions and the obligations to repurchase these securities are recorded as liabilities in the condensed consolidated balance sheets. ASB pledges investment securities as collateral for securities sold under agreements to repurchase. All such agreements are subject to master netting arrangements, which provide for a conditional right of set-off in case of default by either party; however, ASB presents securities sold under agreements to repurchase on a gross basis in the balance sheet. The following tables present information about the securities sold under agreements to repurchase, including the related collateral received from or pledged to counterparties:

(in millions)	Gross amount  of recognized  liabilities		Gross amount  offset in the  Balance Sheets		Net amount of liabilities presented in the Balance Sheets
Repurchase agreements
March 31, 2023	$	131	$	—	$	131
December 31, 2022	281		—		281

	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
March 31, 2023	$	131	$	172	$	—
December 31, 2022	281		327		—

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:

	March 31, 2023				December 31, 2022
(in thousands)	Notional amount		Fair value		Notional amount		Fair value
Interest rate lock commitments	$	2,467	$	26	$	1,720	$	9
Forward commitments	2,250		5		1,500		18

ASB’s derivative financial instruments, their fair values and balance sheet location were as follows:

Derivative Financial Instruments Not Designated as Hedging Instruments 1	March 31, 2023				December 31, 2022
(in thousands)	Asset derivatives		Liability derivatives		Asset derivatives		Liability derivatives
Interest rate lock commitments	$	26	$	—	$	9	$	—
Forward commitments	9		4		18		—
	$	35	$	4	$	27	$	—

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 Income	Three months ended March 31
(in thousands)		2023		2022
Interest rate lock commitments	Mortgage banking income	$	17	$	(655)
Forward commitments	Mortgage banking income	(13)		178
		$	4	$	(477)

Low-Income Housing Tax Credit (LIHTC). ASB’s unfunded commitments to fund its LIHTC investment partnerships were $77.1 million and $70.1 million at March 31, 2023 and December 31, 2022, respectively. These unfunded commitments were unconditional and legally binding and are recorded in other liabilities with a corresponding increase in other assets. As of March 31, 2023, ASB did not have any impairment losses resulting from forfeiture or ineligibility of tax credits or other circumstances related to its LIHTC investment partnerships.

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Credit agreement and changes in debt

3 Months Ended

Mar. 31, 2023

Debt Disclosure [Abstract]

Credit agreement and changes in debt

Credit agreements and changes in debt

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 Credit Facilities) to amend and restate their respective previously existing revolving unsecured credit agreements. The $175 million HEI Facility and the $200 million Hawaiian Electric Facility both terminate on May 14, 2026. On February 18, 2022, the PUC approved Hawaiian Electric’s request to extend the term of the $200 million Hawaiian Electric Facility to May 14, 2026. In addition to extending the term, Hawaiian Electric also received 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 March 31, 2023 and December 31, 2022, no amounts were outstanding under the Credit Facilities.

The Credit Facilities will be maintained to support each company’s respective short-term commercial paper program, but may be drawn on to meet each company’s respective working capital needs and general corporate purposes.

Changes in debt.

HEI private placement. On March 16, 2023, HEI entered into a note purchase agreement (HEI NPA) under which HEI has authorized the issue and sale of $100 million of unsecured senior notes that may be drawn on or before June 2, 2023. The proceeds of the notes, when drawn, are expected to be used to refinance the $100 million term loan facility. The terms of the notes are as follows:

	HEI Series 2023A	HEI Series 2023B
Aggregate principal amount	$39 million	$61 million
Fixed coupon interest rate	6.04%	6.10%
Maturity date	6/15/2028	6/15/2033

Once drawn, interest on the notes is paid semiannually on June 15th and December 15th. The HEI NPA contains certain restrictive financial covenants that are substantially the same as the financial covenants contained in HEI’s revolving unsecured 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.

HEI term loan. On October 20, 2022, HEI entered into a term loan facility in the aggregate principal amount of $100 million. On December 28, 2022, HEI drew $35 million on the term loan, and on March 31, 2023, HEI drew the remaining $65 million at an initial interest rate of 5.81% for an initial one month interest period. Any borrowings under the facility mature on November 30, 2023. Borrowings under the facility bear interest at Term Secured Overnight Financing Rate (SOFR), as defined in the agreement, plus an applicable margin and a SOFR spread adjustment. The term loan facility contains certain restrictive financial covenants that are substantially the same as the financial covenants contained in the HEI Facility.

Utilities private placement. On January 10, 2023, the Utilities executed through a private placement pursuant to separate Note Purchase Agreements (the NPAs), the following unsecured senior notes bearing taxable interest (2023 Notes). The 2023 Notes had a delayed draw feature and the Utilities drew down all the proceeds on February 9, 2023.

	Series 2023A	Series 2023B	Series 2023C
Aggregate principal amount	$90 million	$40 million	$20 million
Fixed coupon interest rate
Hawaiian Electric	6.11%	6.25%	6.70%
Hawaii Electric Light	6.25%	—	—
Maui Electric	6.25%	—	—
Maturity date
Hawaiian Electric	2/9/2030	2/9/2033	2/9/2053
Hawaii Electric Light	2/9/2033	—	—
Maui Electric	2/9/2033	—	—
Principal amount by company:
Hawaiian Electric	$40 million	$40 million	$20 million
Hawaii Electric Light	$25 million	—	—
Maui Electric	$25 million	—	—

The 2023 Notes include substantially the same financial covenants and customary conditions as Hawaiian Electric’s credit agreement. Hawaiian Electric is also a party as guarantor under the NPAs entered into by Hawaii Electric Light and Maui Electric. The Utilities did not obtain any of the proceeds at execution and instead drew down all the proceeds on February 9, 2023. The proceeds were used to finance their respective capital expenditures, repay short-term debt used to finance or refinance capital expenditures and/or reimburse funds used for the payment of capital expenditures. The 2023 Notes may be prepaid in whole or in part at any time at the prepayment price of the principal amount plus a “Make-Whole Amount” as defined in the NPAs.

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Shareholders' equity

3 Months Ended

Mar. 31, 2023

Equity [Abstract]

Shareholders' equity

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 Consolidated								Hawaiian Electric Consolidated
(in thousands)	Net unrealized gains (losses) on securities		Unrealized gains (losses) on derivatives		Retirement benefit plans		AOCI		AOCI-Retirement benefit plans
Balance, December 31, 2022	$	(328,904)	$	1,991	$	(9,115)	$	(336,028)	$	2,861
Current period other comprehensive income (loss)	20,282		138		68		20,488		(45)
Balance, March 31, 2023	$	(308,622)	$	2,129	$	(9,047)	$	(315,540)	$	2,816
Balance, December 31, 2021	$	(32,037)	$	(3,638)	$	(16,858)	$	(52,533)	$	(3,280)
Current period other comprehensive income (loss)	(120,407)		3,072		176		(117,159)		51
Balance, March 31, 2022	$	(152,444)	$	(566)	$	(16,682)	$	(169,692)	$	(3,229)

Reclassifications out of AOCI were as follows:

	Amount reclassified from AOCI					Affected line item in the  Statements of Income / Balance Sheets
		Three months ended March 31
(in thousands)		2023		2022
HEI consolidated
Net unrealized gains (losses) on available-for sale investment securities - amortization of unrealized holding losses on held-to-maturity securities		$	3,677	$	—	Bank revenues
Net realized losses (gains) on derivatives qualifying as cash flow hedges		(48)		55		Interest expense
Retirement benefit plans:
Amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost		(357)		4,501		See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets		425		(4,325)		See Note 8 for additional details
Total reclassifications		$	3,697	$	231
Hawaiian Electric consolidated
Retirement benefit plans:
Amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost		$	(470)	$	4,376	See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets		425		(4,325)		See Note 8 for additional details
Total reclassifications		$	(45)	$	51

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Revenues

3 Months Ended

Mar. 31, 2023

Revenue from Contract with Customer [Abstract]

Revenues

Revenues

Revenue from contracts with customers. The following tables disaggregate revenues by major source, timing of revenue recognition, and segment:

	Three months ended March 31, 2023
(in thousands)	Electric  utility		Bank		Other		Total
Revenues from contracts with customers
Electric energy sales - residential	$	255,550	$	—	$	—	$	255,550
Electric energy sales - commercial	254,470		—		—		254,470
Electric energy sales - large light and power	290,978		—		—		290,978
Electric energy sales - other	5,457		—		—		5,457
Bank fees	—		12,022		—		12,022
Other sales	—		—		3,907		3,907
Total revenues from contracts with customers	806,455		12,022		3,907		822,384
Revenues from other sources
Regulatory revenue	$	15,604	$	—	$	—	$	15,604
Bank interest and dividend income	—		79,479		—		79,479
Other bank noninterest income	—		2,356		—		2,356
Other	8,302		—		112		8,414
Total revenues from other sources	23,906		81,835		112		105,853
Total revenues	$	830,361	$	93,857	$	4,019	$	928,237
Timing of revenue recognition
Services/goods transferred at a point in time	$	—	$	12,022	$	—	$	12,022
Services/goods transferred over time	806,455		—		3,907		810,362
Total revenues from contracts with customers	$	806,455	$	12,022	$	3,907	$	822,384

	Three months ended March 31, 2022
(in thousands)	Electric  utility		Bank		Other		Total
Revenues from contracts with customers
Electric energy sales - residential	$	224,574	$	—	$	—	$	224,574
Electric energy sales - commercial	219,597		—		—		219,597
Electric energy sales - large light and power	241,123		—		—		241,123
Electric energy sales - other	1,426		—		—		1,426
Bank fees	—		12,996		—		12,996
Other sales	—		—		1,115		1,115
Total revenues from contracts with customers	686,720		12,996		1,115		700,831
Revenues from other sources
Regulatory revenue	12,886		—		—		12,886
Bank interest and dividend income	—		59,989		—		59,989
Other bank noninterest income	—		2,130		—		2,130
Other	9,186		—		46		9,232
Total revenues from other sources	22,072		62,119		46		84,237
Total revenues	$	708,792	$	75,115	$	1,161	$	785,068
Timing of revenue recognition
Services/goods transferred at a point in time	$	—	$	12,996	$	—	$	12,996
Services/goods transferred over time	686,720		—		1,115		687,835
Total revenues from contracts with customers	$	686,720	$	12,996	$	1,115	$	700,831

There are no material contract assets or liabilities associated with revenues from contracts with customers existing at December 31, 2022 or as of March 31, 2023. 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 March 31, 2023, 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.

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Retirement benefits

3 Months Ended

Mar. 31, 2023

Retirement Benefits [Abstract]

Retirement benefits

Retirement benefits

Defined benefit pension and other postretirement benefit plans information.  For the first three months of 2023, the Company contributed $2 million ($2 million by the Utilities) to its pension and other postretirement benefit plans, compared to $10 million ($10 million by the Utilities) in the first three months of 2022. The Company’s current estimate of total contributions to its pension and other postretirement benefit plans in 2023 is $8 million ($8 million by the Utilities), compared to $43 million ($42 million by the Utilities) in 2022. In addition, the Company expects to pay directly $3 million ($1 million by the Utilities) of benefits in 2023, compared to $2 million ($1 million by the Utilities) paid in 2022.

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 March 31
	Pension benefits				Other benefits
(in thousands)	2023		2022		2023		2022
HEI consolidated
Service cost	$	11,396	$	19,824	$	344	$	656
Interest cost	25,621		19,811		2,157		1,637
Expected return on plan assets	(35,195)		(35,333)		(3,405)		(3,397)
Amortization of net prior period gain	—		—		(219)		(232)
Amortization of net actuarial (gain)/losses	188		6,297		(449)		(3)
Net periodic pension/benefit cost (return)	2,010		10,599		(1,572)		(1,339)
Impact of PUC D&Os	18,133		9,551		1,425		1,219
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)	$	20,143	$	20,150	$	(147)	$	(120)
Hawaiian Electric consolidated
Service cost	$	11,019	$	19,318	$	340	$	649
Interest cost	23,698		18,462		2,063		1,573
Expected return on plan assets	(32,972)		(33,546)		(3,353)		(3,347)
Amortization of net prior period gain	—		—		(218)		(231)
Amortization of net actuarial (gain)/losses	19		6,125		(434)		—
Net periodic pension/benefit cost (return)	1,764		10,359		(1,602)		(1,356)
Impact of PUC D&Os	18,133		9,551		1,425		1,219
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)	$	19,897	$	19,910	$	(177)	$	(137)

HEI consolidated recorded retirement benefits expense of $11 million ($11 million by the Utilities) in the first three months of 2023 and $12 million ($12 million by the Utilities) in the first three months of 2022 and charged the remaining net periodic benefit cost primarily to electric utility plant.

The Utilities have implemented pension and OPEB tracking mechanisms under which all of their retirement benefit expenses (except for executive life and nonqualified pension plan expenses) determined in accordance with GAAP are recovered over time. Under the tracking mechanisms, any actual costs determined in accordance with GAAP that are over/under amounts allowed in rates are charged/credited to a regulatory asset/liability. The regulatory asset/liability for each utility will then be amortized over five years beginning with the respective utility’s next rate case.

Defined contribution plans information.  For the first three months of 2023 and 2022, 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 $2.7 million and $2.0 million, respectively, and cash contributions were $2.7 million and $1.9 million, respectively. For the first three months of 2023 and 2022, the Utilities’ expenses and cash contributions for its defined contribution plan under the HEIRSP were $1.3 million and $0.9 million, respectively.

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Share-based compensation

3 Months Ended

Mar. 31, 2023

Share-Based Payment Arrangement [Abstract]

Share-based compensation

Share-based compensation

Under the 2010 Equity and Incentive Plan, as amended and restated effective March 1,2014 (EIP), 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 original 2010 Equity and Incentive Plan was amended and restated effective March 1, 2014 and an additional 1.5 million shares were added to the shares available for issuance under these programs.

As of March 31, 2023, approximately 2.7 million shares remained available for future issuance under the terms of the EIP, assuming recycling of shares withheld to satisfy statutory tax liabilities relating to EIP awards, including an estimated 0.7 million shares that could be issued upon the vesting of outstanding restricted stock units and the achievement of performance goals for awards outstanding under long-term incentive plans (assuming that such performance goals are achieved at maximum levels).

Under the 2011 Nonemployee Director Stock Plan (2011 Director Plan), HEI can issue shares of common stock as compensation to nonemployee directors of HEI, Hawaiian Electric and ASB. As of March 31, 2023, there were 207,118 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 March 31
(in millions)	2023		2022
HEI consolidated
Share-based compensation expense 1	$	2.0	$	2.1
Income tax benefit	0.3		0.3
Hawaiian Electric consolidated
Share-based compensation expense 1	0.7		0.6
Income tax benefit	0.1		0.1

1    For the three months ended March 31, 2023 and 2022, 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 March 31
(dollars in millions)	2023		2022
Shares granted	1,509		—
Fair value	$	0.1	$	—
Income tax benefit	—		—

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.

Restricted stock units.  Information about HEI’s grants of restricted stock units was as follows:

	Three months ended March 31
	2023				2022
	Shares		(1)		Shares		(1)
Outstanding, beginning of period	182,528		$	39.75	233,448		$	38.10
Granted	100,088		42.41		96,455		41.29
Vested	(80,077)		39.30		(90,380)		37.58
Forfeited	(406)		38.39		(31,178)		38.78
Outstanding, end of period	202,133		$	41.25	208,345		$	39.71
Total weighted-average grant-date fair value of shares granted (in millions)	$	4.2			$	4.0

(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 three months ended March 31, 2023 and 2022, total restricted stock units and related dividends that vested had a fair value of $3.6 million and $3.9 million, respectively, and the related tax benefits were $0.8 million and $0.6 million, respectively.

As of March 31, 2023, there was $7.5 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 2021-23, 2022-24 and 2023-25 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 Peer Group (Edison Electric Institute Index (EEI Index) for the 2021-23 and 2022-24 performance periods, and compared to the Company's compensation peer group consisting of companies in the EEI Index and approved by the Company's Compensation and Human Capital Management Committee for the 2023-25 performance period), in each case over the relevant three-year period. The other performance condition goals relate to EPS growth, cumulative EPS, return on average common equity (ROACE), renewable portfolio standards, carbon emissions reduction, 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 March 31
	2023				2022
	Shares		(1)		Shares		(1)
Outstanding, beginning of period	71,574		$	47.67	90,974		$	42.86
Granted	27,123		55.98		26,079		54.92
Vested (issued or unissued and cancelled)	(18,691)		48.62		(29,042)		41.07
Forfeited	—		—		(11,671)		42.60
Outstanding, end of period	80,006		$	50.27	76,340		$	47.70
Total weighted-average grant-date fair value of shares granted (in millions)	$	1.5			$	1.4

(1)    Weighted-average grant-date fair value per share determined using a Monte Carlo simulation model.

The grant date fair values of the shares were determined using a Monte Carlo simulation model utilizing actual information for the common shares of HEI and the Peer Group for the period from the beginning of the performance period to the grant date and estimated future stock volatility of HEI and the Peer Group over the remaining three-year performance period. The expected stock volatility assumptions for HEI and the 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.

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:

	2023		2022
Risk-free interest rate	4.19	%	1.71	%
Expected life in years	3		3
Expected volatility	33.1	%	31.0	%
Range of expected volatility for Peer Group	28.7% to 38.8%		25.4% to 76.7%
Grant date fair value (per share)	$55.98		$54.92

There were no share-based LTIP awards linked to TSR with a vesting date in 2023. For the three months ended March 31, 2022, total vested LTIP awards linked to TSR and related dividends had a fair value of $0.8 million and the related tax benefits were $0.1 million.

As of March 31, 2023, there was $2.4 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 1.7 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 March 31
	2023				2022
	Shares		(1)		Shares		(1)
Outstanding, beginning of period	309,589		$	39.50	306,342		$	38.42
Granted	108,499		42.41		104,300		41.29
Vested	(62,778)		48.07		(71,807)		37.68
Forfeited	—		—		(46,684)		36.77
Outstanding, end of period	355,310		$	38.87	292,151		$	39.89
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)	$	4.6			$	4.3

(1)    Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.

For the three months ended March 31, 2023 and 2022, total vested LTIP awards linked to other performance conditions and related dividends had a fair value of $2.9 million and $3.2 million, respectively, and the related tax benefits were $0.6 million and $0.4 million, respectively.

As of March 31, 2023, there was $7.4 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.

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Income taxes

3 Months Ended

Mar. 31, 2023

Income Tax Disclosure [Abstract]

Income taxes

Income taxes

The Company’s and the Utilities’ effective tax rates (combined federal and state income tax rates) for the three months ended March 31, 2023 were 21% and 22%, respectively. 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 2017 Tax Cuts and Jobs Act that lowered the federal income tax rate from 35% to 21% and the tax benefits derived from the low income housing tax credit investments.

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 audit is still in progress and the Company has responded to all information requests. The Company has not been notified of any material audit adjustments to date.

The Inflation Reduction Act of 2022 (IRA) was signed by President Biden on August 16, 2022. Key provisions under the IRA include a 15% corporate alternative minimum tax (CAMT) imposed on certain large corporations and a 1% excise tax on stock repurchases after December 31, 2022. Based on current interpretation of the law and current guidance available we do not believe HEI will be impacted by the CAMT or stock repurchase excise tax provisions.

The IRA also creates new tax credits and enhances others to stimulate investment in renewable energy sources. Certain provisions of the IRA became effective beginning tax year 2023. The Company continues to monitor guidance and assess related tax planning opportunities.

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Cash flows

3 Months Ended

Mar. 31, 2023

Supplemental Cash Flow Elements [Abstract]

Cash flows

Cash flows

Three months ended March 31	2023		2022
(in millions)
Supplemental disclosures of cash flow information
HEI consolidated
Interest paid to non-affiliates, net of amounts capitalized	$	21	$	10
Hawaiian Electric consolidated
Interest paid to non-affiliates	6		6
Income taxes paid (including refundable credits)	3		—
Supplemental disclosures of noncash activities
HEI consolidated
Property, plant and equipment
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)	50		24
Increase related to an acquisition (investing)	—		15
Right-of-use assets obtained in exchange for finance lease obligations (financing)	40		—
Right-of-use assets obtained in exchange for operating lease obligations (investing)	1		35
Common stock issued (gross) for director and executive/management compensation (financing)1	7		8
Obligations to fund low income housing investments (investing)	7		—
Unsettled trades to purchase investment securities (investing)	—		25
Other receivable related to pending sales proceeds from the sale of an equity-method investment (investing)	—		9
Hawaiian Electric consolidated
Electric utility property, plant and equipment
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)	48		21
Increase related to an acquisition (investing)	—		15
Right-of-use assets obtained in exchange for finance lease obligations (financing)	40		—
Right-of-use assets obtained in exchange for operating lease obligations (investing)	—		32

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.

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Fair value measurements

3 Months Ended

Mar. 31, 2023

Fair Value Disclosures [Abstract]

Fair value measurements

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.

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 initially measured at fair value (less estimated costs to sell) and subsequently measured at the lower of the carrying value or fair value less selling costs. Fair values 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 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.

Interest rate swaps. The Company measures its interest rate swaps at fair value. The fair values of the Company's interest rate swaps are based on the estimated amounts that the Company would receive or pay to terminate the contracts at the reporting date and are determined using interest rate pricing models and interest rate related observable inputs. The fair values of the Company's interest rate swaps are classified as a 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 amount		Quoted prices in active markets for identical assets  (Level 1)		Significant  other observable  inputs  (Level 2)		Significant unobservable inputs  (Level 3)		Total
March 31, 2023
Financial assets
HEI consolidated
Available-for-sale investment securities	$	1,419,755	$	—	$	1,404,989	$	14,766	$	1,419,755
Held-to-maturity investment securities	1,238,185		—		1,158,090		—		1,158,090
Loans, net	5,988,718		—		661		5,605,699		5,606,360
Mortgage servicing rights	8,745		—		—		18,117		18,117
Derivative assets	38,050		9		1,133		—		1,142
Financial liabilities
HEI consolidated
Deposit liabilities	843,415		—		829,709		—		829,709
Short-term borrowings—other than bank	148,802		—		148,802		—		148,802
Other bank borrowings	680,690		—		675,107		—		675,107
Long-term debt, net—other than bank	2,480,948		—		2,296,948		—		2,296,948
Derivative liabilities	250		4		—		—		4
Hawaiian Electric consolidated
Long-term debt, net	1,834,320		—		1,702,247		—		1,702,247
December 31, 2022
Financial assets
HEI consolidated
Available-for-sale investment securities	$	1,429,667	$	—	$	1,414,765	$	14,902	$	1,429,667
Held-to-maturity investment securities	1,251,747		—		1,150,971		—		1,150,971
Loans, net	5,907,514		—		821		5,453,381		5,454,202
Mortgage servicing rights	9,047		—		—		17,646		17,646
Derivative assets	16,220		18		1,330		—		1,348
Financial liabilities
HEI consolidated
Deposit liabilities	611,718		—		597,617		—		597,617
Short-term borrowings—other than bank	172,568		—		172,568		—		172,568
Other bank borrowings	695,120		—		695,095		—		695,095
Long-term debt, net—other than bank	2,384,980		—		2,122,605		—		2,122,605
Derivative liabilities	22,949		—		472		—		472
Hawaiian Electric consolidated
Short-term borrowings	87,967		—		87,967		—		87,967
Long-term debt, net	1,684,816		—		1,487,496		—		1,487,496

Fair value measurements on a recurring basis.  Assets and liabilities measured at fair value on a recurring basis were as follows:

	March 31, 2023						December 31, 2022
	Fair value measurements using						Fair value measurements using
(in thousands)	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
Available-for-sale investment securities (bank segment)
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	$	—	$	1,283,935	$	—	$	—	$	1,292,968	$	—
U.S. Treasury and federal agency obligations	—		79,744		—		—		81,063		—
Corporate bonds	—		41,310		—		—		40,734		—
Mortgage revenue bonds	—		—		14,766		—		—		14,902
	$	—	$	1,404,989	$	14,766	$	—	$	1,414,765	$	14,902
Derivative assets
Interest rate lock commitments (bank segment)1	$	—	$	26	$	—	$	—	$	9	$	—
Forward commitments (bank segment)1	9		—		—		18		—		—
Interest rate swap (Other segment)2	—		1,107		—		—		1,321		—
	$	9	$	1,133	$	—	$	18	$	1,330	$	—
Derivative liabilities
Forward commitments (bank segment)1	$	4	$	—	$	—	$	—	$	—	$	—
Interest rate swap (Other segment)2	—		—		—		—		472		—
	$	4	$	—	$	—	$	—	$	472	$	—

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.

There were no transfers of financial assets and liabilities between Level 1 and Level 2 of the fair value hierarchy during the three months ended March 31, 2023 and 2022.

The changes in Level 3 assets and liabilities measured at fair value on a recurring basis were as follows:

	Three months ended March 31
Mortgage revenue bonds	2023		2022
(in thousands)
Beginning balance	$	14,902	$	15,427
Principal payments received	(136)		(131)
Purchases	—		—
Unrealized gain (loss) included in other comprehensive income	—		—
Ending balance	$	14,766	$	15,296

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 March 31, 2023, the weighted average discount rate was 5.07%, 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.

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. As of March 31, 2023 and December 31, 2022, there were no financial instruments measured at fair value on a nonrecurring basis.

For the three months ended March 31, 2023 and 2022, there were no adjustments to fair value for ASB’s loans held for sale.

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Basis of presentation (Policies)

3 Months Ended

Mar. 31, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

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.

Recent accounting pronouncements

Recent accounting pronouncements.

Credit Losses. In March 2022, Financial Accounting Standards Board issued Accounting Standards Update (ASU) No. 2022-02, “Financial Instruments-Credit Losses (Topic 326): Troubled Debt Restructurings and Vintage Disclosures,” which eliminates the accounting guidance for Troubled Debt Restructurings (TDRs) by creditors in Subtopic 310-40, Receivables-Troubled Debt Restructurings by Creditors, while enhancing disclosure requirements for certain loan refinancings and restructurings by creditors when a borrower is experiencing financial difficulty. Specifically, rather than applying the recognition and measurement guidance for TDRs, an entity must apply the loan refinancing and restructuring guidance in paragraphs 310-20-35-9 through 35-11 to determine whether a modification results in a new loan or a continuation of an existing loan. The amendments in this update also require that an entity disclose current-period gross write-offs by year of origination for financing receivables and net investments in leases within the scope of Subtopic 326-20, “Financial Instruments-Credit Losses-Measured at Amortized Cost.” Gross write-off information must be included in the vintage disclosures required for public business entities in accordance with paragraph 325-20-50-6, which requires that an entity disclose the amortized cost basis of financing receivables by credit-quality indicator and class of financing receivable by year of origination. The amendments in this update are effective for fiscal years beginning after December 15, 2022, including interim periods within those fiscal years. ASB updated the accounting for certain loan refinancings and restructurings, and included the required disclosures in the Notes herein in accordance with ASU No. 2022-02.

Troubled debt restructurings

Troubled debt restructurings. Prior to January 1, 2023, a loan modification was 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. With the adoption of ASU No. 2022-02, accounting guidance for TDRs by creditors is eliminated. Loan refinancing and restructuring guidance is applied to determine whether a modification results in a new loan or a continuation of an existing loan. ASB will continue TDR disclosures for years prior to the adoption of ASU No. 2022-02.

Fair value measurements

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.

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 initially measured at fair value (less estimated costs to sell) and subsequently measured at the lower of the carrying value or fair value less selling costs. Fair values 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 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.

Interest rate swaps. The Company measures its interest rate swaps at fair value. The fair values of the Company's interest rate swaps are based on the estimated amounts that the Company would receive or pay to terminate the contracts at the reporting date and are determined using interest rate pricing models and interest rate related observable inputs. The fair values of the Company's interest rate swaps are classified as a Level 2 measurements.

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Segment financial information (Tables)

3 Months Ended

Mar. 31, 2023

Segment Reporting [Abstract]

Schedule of segment financial information

(in thousands)	Electric utility		Bank		Other		Total
Three months ended March 31, 2023
Revenues	$	830,361	$	93,857	$	4,019	$	928,237
Income (loss) before income taxes	$	61,108	$	23,707	$	(14,511)	$	70,304
Income taxes (benefit)	13,600		5,145		(3,635)		15,110
Net income (loss)	47,508		18,562		(10,876)		55,194
Preferred stock dividends of subsidiaries	499		—		(26)		473
Net income (loss) for common stock	$	47,009	$	18,562	$	(10,850)	$	54,721
Total assets (at March 31, 2023)	$	6,674,463	$	9,610,070	$	159,252	$	16,443,785
Three months ended March 31, 2022
Revenues from external customers and other sources	$	708,788	$	75,115	$	1,165	$	785,068
Intersegment revenues (eliminations)	4		—		(4)		—
Revenues	$	708,792	$	75,115	$	1,161	$	785,068
Income (loss) before income taxes	$	59,446	$	30,215	$	(2,181)	$	87,480
Income taxes (benefit)	12,538		6,345		(1,043)		17,840
Net income (loss)	46,908		23,870		(1,138)		69,640
Preferred stock dividends of subsidiaries	499		—		(26)		473
Net income (loss) for common stock	$	46,409	$	23,870	$	(1,112)	$	69,167
Total assets (at December 31, 2022)	$	6,597,467	$	9,545,970	$	140,807	$	16,284,244

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Electric utility segment (Tables)

3 Months Ended

Mar. 31, 2023

Electric Utility Subsidiary [Abstract]

Schedule of purchases from all IPPs

Purchases from all IPPs were as follows:

	Three months ended March 31
(in millions)	2023		2022
Kalaeloa	$	67	$	60
AES Hawaii 1	—		27
HPOWER	18		19
Hamakua Energy	20		16
Puna Geothermal Venture	8		10
Wind IPPs	24		18
Solar IPPs	14		13
Other IPPs 2	2		1
Total IPPs	$	153	$	164

1 The term of the PPA with AES Hawaii expired on September 1, 2022 and the AES Hawaii coal plant ceased operations.2 Includes hydro power and other PPAs.

Schedule of net annual incremental amounts proposed to be collected (refunded)

The net incremental amounts between the 2022 fall and 2023 spring revenue reports are shown in the following table. The amounts are to be collected (refunded) from June, 1, 2023 through May 31, 2024 under the RBA rate tariffs, which were included in the 2023 spring revenue report filing.

(in millions)	Hawaiian Electric		Hawaii Electric Light		Maui Electric		Total
Incremental Performance Incentive Mechanisms (net)	(0.4)		0.1		0.1		(0.2)
Incremental EPRM/MPIR Revenue Adjustment	2.5		1.4		1.0		4.9
Other	0.4		0.1		—		$	0.5
Net incremental amount to be collected under the RBA rate tariffs	$	2.5	$	1.5	$	1.1	$	5.1

Note: Columns may not foot due to rounding.

Schedule of condensed consolidating statements of income

Condensed Consolidating Statement of Income

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Revenues	$	601,530	115,288	113,673	—	(130)	$	830,361
Expenses
Fuel oil	253,827		27,760	52,510	—	—	334,097
Purchased power	110,279		34,086	8,396	—	—	152,761
Other operation and maintenance	83,233		21,350	23,733	—	—	128,316
Depreciation	41,038		10,635	9,254	—	—	60,927
Taxes, other than income taxes	56,953		10,737	10,695	—	—	78,385
Total expenses	545,330		104,568	104,588	—	—	754,486
Operating income	56,200		10,720	9,085	—	(130)	75,875
Allowance for equity funds used during construction	2,640		284	377	—	—	3,301
Equity in earnings of subsidiaries	11,541		—	—	—	(11,541)	—
Retirement defined benefits credit (expense)—other than service costs	904		169	(26)	—	—	1,047
Interest expense and other charges, net	(14,557)		(2,831)	(2,988)	—	130	(20,246)
Allowance for borrowed funds used during construction	918		91	122	—	—	1,131
Income before income taxes	57,646		8,433	6,570	—	(11,541)	61,108
Income taxes	10,367		1,909	1,324	—	—	13,600
Net income	47,279		6,524	5,246	—	(11,541)	47,508
Preferred stock dividends of subsidiaries	—		134	95	—	—	229
Net income attributable to Hawaiian Electric	47,279		6,390	5,151	—	(11,541)	47,279
Preferred stock dividends of Hawaiian Electric	270		—	—	—	—	270
Net income for common stock	$	47,009	6,390	5,151	—	(11,541)	$	47,009

Condensed Consolidating Statement of Income

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Revenues	$	500,242	108,528	100,028	—	(6)	$	708,792
Expenses
Fuel oil	154,425		25,251	41,610	—	—	221,286
Purchased power	124,183		30,712	8,638	—	—	163,533
Other operation and maintenance	83,656		20,214	21,387	—	—	125,257
Depreciation	39,484		10,351	8,636	—	—	58,471
Taxes, other than income taxes	47,274		10,032	9,344	—	—	66,650
Total expenses	449,022		96,560	89,615	—	—	635,197
Operating income	51,220		11,968	10,413	—	(6)	73,595
Allowance for equity funds used during construction	1,990		193	226	—	—	2,409
Equity in earnings of subsidiaries	13,661		—	—	—	(13,661)	—
Retirement defined benefits credit (expense)—other than service costs	855		167	(32)	—	—	990
Interest expense and other charges, net	(13,093)		(2,609)	(2,630)	—	6	(18,326)
Allowance for borrowed funds used during construction	651		60	67	—	—	778
Income before income taxes	55,284		9,779	8,044	—	(13,661)	59,446
Income taxes	8,605		2,268	1,665	—	—	12,538
Net income	46,679		7,511	6,379	—	(13,661)	46,908
Preferred stock dividends of subsidiaries	—		134	95	—	—	229
Net income attributable to Hawaiian Electric	46,679		7,377	6,284	—	(13,661)	46,679
Preferred stock dividends of Hawaiian Electric	270		—	—	—	—	270
Net income for common stock	$	46,409	7,377	6,284	—	(13,661)	$	46,409

Statements of Income and Comprehensive Income Data

	Three months ended March 31
(in thousands)	2023		2022
Interest and dividend income
Interest and fees on loans	$	64,842	$	46,005
Interest and dividends on investment securities	14,637		13,984
Total interest and dividend income	79,479		59,989
Interest expense
Interest on deposit liabilities	6,837		947
Interest on other borrowings	7,721		5
Total interest expense	14,558		952
Net interest income	64,921		59,037
Provision for credit losses	1,175		(3,263)
Net interest income after provision for credit losses	63,746		62,300
Noninterest income
Fees from other financial services	4,679		5,587
Fee income on deposit liabilities	4,599		4,691
Fee income on other financial products	2,744		2,718
Bank-owned life insurance	1,425		681
Mortgage banking income	130		1,077
Gain on sale of real estate	—		1,002
Other income, net	801		372
Total noninterest income	14,378		16,128
Noninterest expense
Compensation and employee benefits	30,204		27,215
Occupancy	5,588		5,952
Data processing	5,012		4,151
Services	2,595		2,439
Equipment	2,646		2,329
Office supplies, printing and postage	1,165		1,060
Marketing	1,016		1,018
Other expense	6,191		4,049
Total noninterest expense	54,417		48,213
Income before income taxes	23,707		30,215
Income taxes	5,145		6,345
Net income	18,562		23,870
Other comprehensive income (loss), net of taxes	18,430		(122,441)
Comprehensive income (loss)	$	36,992	$	(98,571)

Reconciliation to amounts per HEI Condensed Consolidated Statements of Income*:

	Three months ended March 31
(in thousands)	2023		2022
Interest and dividend income	$	79,479	$	59,989
Noninterest income	14,378		16,128
Less: Gain on sale of real estate	—		1,002
*Revenues-Bank	93,857		75,115
Total interest expense	14,558		952
Provision for credit losses	1,175		(3,263)
Noninterest expense	54,417		48,213
Less: Gain on sale of real estate	—		1,002
Less: Retirement defined benefits credit—other than service costs	(187)		(185)
*Expenses-Bank	70,337		45,085
*Operating income-Bank	23,520		30,030
Add back: Retirement defined benefits credit—other than service costs	(187)		(185)
Income before income taxes	$	23,707	$	30,215

Schedule of condensed consolidating statement of comprehensive income

Condensed Consolidating Statement of Comprehensive Income

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net income for common stock	$	47,009	6,390	5,151	—	(11,541)	$	47,009
Other comprehensive loss, net of taxes:
Retirement benefit plans:
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes	(470)		(56)	(63)	—	119	(470)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	425		50	57	—	(107)	425
Other comprehensive loss, net of taxes	(45)		(6)	(6)	—	12	(45)
Comprehensive income attributable to common shareholder	$	46,964	6,384	5,145	—	(11,529)	$	46,964

Condensed Consolidating Statement of Comprehensive Income

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net income for common stock	$	46,409	7,377	6,284	—	(13,661)	$	46,409
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	4,376		670	603	—	(1,273)	4,376
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	(4,325)		(670)	(603)	—	1,273	(4,325)
Other comprehensive income, net of taxes	51		—	—	—	—	51
Comprehensive income attributable to common shareholder	$	46,460	7,377	6,284	—	(13,661)	$	46,460

Schedule of condensed consolidating balance sheet

Condensed Consolidating Balance Sheet

March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsi- diaries	Consoli- dating adjustments	Hawaiian Electric Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	42,860	5,606	3,594	—	—	$	52,060
Plant and equipment	5,302,293		1,431,852	1,308,747	—	—	8,042,892
Right-of-use assets - finance lease	88,297		—	—	—	—	88,297
Less accumulated depreciation	(1,889,007)		(651,463)	(593,341)	—	—	(3,133,811)
Construction in progress	248,788		28,136	38,938	—	—	315,862
Utility property, plant and equipment, net	3,793,231		814,131	757,938	—	—	5,365,300
Nonutility property, plant and equipment, less accumulated depreciation	5,298		115	1,532	—	—	6,945
Total property, plant and equipment, net	3,798,529		814,246	759,470	—	—	5,372,245
Investment in wholly owned subsidiaries, at equity	705,212		—	—	—	(705,212)	—
Current assets
Cash and cash equivalents	49,393		28,006	38,546	77	—	116,022
Customer accounts receivable, net	172,426		34,224	28,655	—	—	235,305
Accrued unbilled revenues, net	118,035		21,831	20,666	—	—	160,532
Other accounts receivable, net	22,376		3,883	4,677	—	(19,509)	11,427
Fuel oil stock, at average cost	116,295		16,678	24,610	—	—	157,583
Materials and supplies, at average cost	50,744		10,578	22,771	—	—	84,093
Prepayments and other	33,369		5,025	5,515	—	—	43,909
Regulatory assets	58,943		2,575	3,455	—	—	64,973
Total current assets	621,581		122,800	148,895	77	(19,509)	873,844
Other long-term assets
Operating lease right-of-use assets	40,724		32,599	11,607	—	—	84,930
Regulatory assets	151,684		19,041	12,204	—	—	182,929
Other	113,888		32,786	30,402	—	(16,561)	160,515
Total other long-term assets	306,296		84,426	54,213	—	(16,561)	428,374
Total assets	$	5,431,618	1,021,472	962,578	77	(741,282)	$	6,674,463
Capitalization and liabilities
Capitalization
Common stock equity	$	2,358,884	346,629	358,506	77	(705,212)	$	2,358,884
Cumulative preferred stock—not subject to mandatory redemption	22,293		7,000	5,000	—	—	34,293
Long-term debt, net	1,226,587		249,346	258,414	—	—	1,734,347
Total capitalization	3,607,764		602,975	621,920	77	(705,212)	4,127,524
Current liabilities
Current portion of operating lease liabilities	8,955		6,780	2,679	—	—	18,414
Current portion of long-term debt	49,987		19,994	29,992	—	—	99,973
Accounts payable	146,125		20,957	24,687	—	—	191,769
Interest and preferred dividends payable	20,788		3,839	4,740	—	—	29,367
Taxes accrued, including revenue taxes	178,418		34,570	33,926	—	—	246,914
Regulatory liabilities	9,505		7,918	7,811	—	—	25,234
Other	61,360		21,072	23,657	—	(19,509)	86,580
Total current liabilities	475,138		115,130	127,492	—	(19,509)	698,251
Deferred credits and other liabilities
Operating lease liabilities	39,387		26,087	9,159	—	—	74,633
Finance lease liabilities	84,341		—	—	—	—	84,341
Deferred income taxes	271,588		50,657	62,708	—	—	384,953
Regulatory liabilities	745,894		195,238	103,185	—	—	1,044,317
Unamortized tax credits	68,123		12,903	12,419	—	—	93,445
Defined benefit pension and other postretirement benefit plans liability	65,917		—	—	—	(16,529)	49,388
Other	73,466		18,482	25,695	—	(32)	117,611
Total deferred credits and other liabilities	1,348,716		303,367	213,166	—	(16,561)	1,848,688
Total capitalization and liabilities	$	5,431,618	1,021,472	962,578	77	(741,282)	$	6,674,463

Condensed Consolidating Balance Sheet

December 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsi-diaries	Consoli- dating adjustments	Hawaiian Electric Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	42,860	5,606	3,594	—	—	$	52,060
Plant and equipment	5,260,685		1,425,442	1,293,383	—	—	7,979,510
Finance lease right-of-use assets	48,371		—	—	—	—	48,371
Less accumulated depreciation	(1,855,150)		(644,457)	(586,892)	—	—	(3,086,499)
Construction in progress	215,560		23,989	35,804	—	—	275,353
Utility property, plant and equipment, net	3,712,326		810,580	745,889	—	—	5,268,795
Nonutility property, plant and equipment, less accumulated depreciation	5,298		115	1,532	—	—	6,945
Total property, plant and equipment, net	3,717,624		810,695	747,421	—	—	5,275,740
Investment in wholly owned subsidiaries, at equity	701,833		—	—	—	(701,833)	—
Current assets
Cash and cash equivalents	27,579		5,092	6,494	77	—	39,242
Advances to affiliates	—		4,500	21,700	—	(26,200)	—
Customer accounts receivable, net	216,802		39,339	32,197	—	—	288,338
Accrued unbilled revenues, net	136,508		23,839	22,933	—	—	183,280
Other accounts receivable, net	23,746		5,519	6,686	—	(22,384)	13,567
Fuel oil stock, at average cost	153,342		16,964	21,224	—	—	191,530
Materials and supplies, at average cost	48,130		9,783	21,655	—	—	79,568
Prepayments and other	24,040		6,346	4,137	—	(1,041)	33,482
Regulatory assets	46,504		2,435	3,334	—	—	52,273
Total current assets	676,651		113,817	140,360	77	(49,625)	881,280
Other long-term assets
Operating lease right-of-use assets	42,752		34,283	12,283	—	—	89,318
Regulatory assets	154,040		21,816	14,384	—	—	190,240
Other	115,028		32,654	29,495	—	(16,288)	160,889
Total other long-term assets	311,820		88,753	56,162	—	(16,288)	440,447
Total assets	$	5,407,928	1,013,265	943,943	77	(767,746)	$	6,597,467
Capitalization and liabilities
Capitalization
Common stock equity	$	2,344,170	344,720	357,036	77	(701,833)	$	2,344,170
Cumulative preferred stock—not subject to mandatory redemption	22,293		7,000	5,000	—	—	34,293
Long-term debt, net	1,126,915		224,439	233,500	—	—	1,584,854
Total capitalization	3,493,378		576,159	595,536	77	(701,833)	3,963,317
Current liabilities
Current portion of operating lease liabilities	9,775		6,690	2,630	—	—	19,095
Current portion of long-term debt	49,981		19,992	29,989	—	—	99,962
Short-term borrowings-affiliate	26,200		—	—	—	(26,200)	—
Accounts payable	143,253		32,113	27,126	—	—	202,492
Interest and preferred dividends payable	12,398		2,576	2,282	—	(80)	17,176
Taxes accrued, including revenue taxes	207,798		42,436	40,709	—	(1,041)	289,902
Regulatory liabilities	13,145		8,553	9,777	—	—	31,475
Other	64,659		20,856	22,385	—	(22,304)	85,596
Total current liabilities	615,176		133,216	134,898	—	(49,625)	833,665
Deferred credits and other liabilities
Operating lease liabilities	41,049		27,817	9,849	—	—	78,715
Finance lease liabilities	46,048		—	—	—	—	46,048
Deferred income taxes	271,234		50,615	62,581	—	—	384,430
Regulatory liabilities	729,683		194,222	100,270	—	—	1,024,175
Unamortized tax credits	69,614		13,150	12,536	—	—	95,300
Defined benefit pension and other postretirement benefit plans liability	65,907		129	—	—	(16,288)	49,748
Other	75,839		17,957	28,273		—	122,069
Total deferred credits and other liabilities	1,299,374		303,890	213,509	—	(16,288)	1,800,485
Total capitalization and liabilities	$	5,407,928	1,013,265	943,943	77	(767,746)	$	6,597,467

Balance Sheets Data

(in thousands)	March 31, 2023				December 31, 2022
Assets
Cash and due from banks			$	138,742			$	153,042
Interest-bearing deposits			44,315				3,107
Cash and cash equivalents			183,057				156,149
Investment securities
Available-for-sale, at fair value			1,419,755				1,429,667
Held-to-maturity, at amortized cost (fair value of $1,158,090 and $1,150,971, respectively)			1,238,185				1,251,747
Stock in Federal Home Loan Bank, at cost			10,000				26,560
Loans held for investment			6,059,354				5,978,906
Allowance for credit losses			(71,296)				(72,216)
Net loans			5,988,058				5,906,690
Loans held for sale, at lower of cost or fair value			660				824
Other			688,165				692,143
Goodwill			82,190				82,190
Total assets			$	9,610,070			$	9,545,970
Liabilities and shareholder’s equity
Deposit liabilities—noninterest-bearing			$	2,769,789			$	2,811,077
Deposit liabilities—interest-bearing			5,460,812				5,358,619
Other borrowings			680,690				695,120
Other			206,317				212,269
Total liabilities			9,117,608				9,077,085
Common stock			1				1
Additional paid-in capital			356,391				355,806
Retained earnings			454,255				449,693
Accumulated other comprehensive loss, net of tax benefits
Net unrealized losses on securities	$	(308,622)			$	(328,904)
Retirement benefit plans	(9,563)		(318,185)		(7,711)		(336,615)
Total shareholder’s equity			492,462				468,885
Total liabilities and shareholder’s equity			$	9,610,070			$	9,545,970
Other assets
Bank-owned life insurance			$	183,936			$	182,986
Premises and equipment, net			192,789				195,324
Accrued interest receivable			26,547				25,077
Mortgage-servicing rights			8,745				9,047
Low-income housing investments			110,748				106,978
Real estate held for sale			100				—
Deferred tax asset			109,885				116,441
Real estate acquired in settlement of loans, net			614				115
Other			54,801				56,175
			$	688,165			$	692,143
Other liabilities
Accrued expenses			$	95,066			$	97,295
Federal and state income taxes payable			2,614				863
Cashier’s checks			34,616				36,401
Advance payments by borrowers			5,466				9,637
Other			68,555				68,073
			$	206,317			$	212,269

Schedule of condensed consolidating statement of changes in common stock equity

Condensed Consolidating Statement of Changes in Common Stock Equity

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Balance, December 31, 2022	$	2,344,170	344,720	357,036	77	(701,833)	$	2,344,170
Net income for common stock	47,009		6,390	5,151	—	(11,541)	47,009
Other comprehensive loss, net of taxes	(45)		(6)	(6)	—	12	(45)
Common stock dividends	(32,250)		(4,475)	(3,675)	—	8,150	(32,250)
Balance, March 31, 2023	$	2,358,884	346,629	358,506	77	(705,212)	$	2,358,884

Condensed Consolidating Statement of Changes in Common Stock Equity

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Balance, December 31, 2021	$	2,261,899	332,900	343,260	77	(676,237)	$	2,261,899
Net income for common stock	46,409		7,377	6,284	—	(13,661)	46,409
Other comprehensive income, net of taxes	51		—	—	—	—	51
Common stock dividends	(31,475)		(4,100)	(3,800)	—	7,900	(31,475)
Balance, March 31, 2022	$	2,276,884	336,177	345,744	77	(681,998)	$	2,276,884

Schedule of condensed consolidating statement of cash flows

Condensed Consolidating Statement of Cash Flows

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net cash provided by operating activities	$	143,356	18,733	15,416	—	(8,150)	$	169,355
Cash flows from investing activities
Capital expenditures	(74,916)		(20,747)	(26,476)	—	—	(122,139)
Advances to affiliates	—		4,500	21,700	—	(26,200)	—
Other	1,094		153	298	—	—	1,545
Net cash used in investing activities	(73,822)		(16,094)	(4,478)	—	(26,200)	(120,594)
Cash flows from financing activities
Common stock dividends	(32,250)		(4,475)	(3,675)	—	8,150	(32,250)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(270)		(134)	(95)	—	—	(499)
Proceeds from issuance of long-term debt	100,000		25,000	25,000	—	—	150,000
Net decrease in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less	(114,167)		—	—	—	26,200	(87,967)
Payments of obligations under finance leases	(575)		—	—	—	—	(575)
Other	(458)		(116)	(116)	—	—	(690)
Net cash provided by (used in) financing activities	(47,720)		20,275	21,114	—	34,350	28,019
Net increase in cash and cash equivalents	21,814		22,914	32,052	—	—	76,780
Cash and cash equivalents, beginning of period	27,579		5,092	6,494	77	—	39,242
Cash and cash equivalents, end of period	$	49,393	28,006	38,546	77	—	$	116,022

Condensed Consolidating Statement of Cash Flows

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Net cash provided by operating activities	$	55,669	15,778	13,228	—	(7,900)	$	76,775
Cash flows from investing activities
Capital expenditures	(44,084)		(15,133)	(17,141)	—	—	(76,358)
Advances to affiliates	(4,000)		—	(12,800)	—	16,800	—
Other	961		280	253	—	—	1,494
Net cash used in investing activities	(47,123)		(14,853)	(29,688)	—	16,800	(74,864)
Cash flows from financing activities
Common stock dividends	(31,475)		(4,100)	(3,800)	—	7,900	(31,475)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(270)		(134)	(95)	—	—	(499)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less	18,800		4,000	—	—	(16,800)	6,000
Net cash used in financing activities	(12,945)		(234)	(3,895)	—	(8,900)	(25,974)
Net increase (decrease) in cash and cash equivalents	(4,399)		691	(20,355)	—	—	(24,063)
Cash, cash equivalents and restricted cash, beginning of period	26,433		5,326	23,422	77	—	55,258
Cash, cash equivalents and restricted cash, end of period	22,034		6,017	3,067	77	—	31,195
Less: Restricted cash	(2,140)		—	—	—	—	(2,140)
Cash and cash equivalents, end of period	$	19,894	6,017	3,067	77	—	$	29,055

XML

Bank segment (Tables)

3 Months Ended

Mar. 31, 2023

Bank Subsidiary [Abstract]

Schedule of statements of income data

Condensed Consolidating Statement of Income

Three months ended March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Revenues	$	601,530	115,288	113,673	—	(130)	$	830,361
Expenses
Fuel oil	253,827		27,760	52,510	—	—	334,097
Purchased power	110,279		34,086	8,396	—	—	152,761
Other operation and maintenance	83,233		21,350	23,733	—	—	128,316
Depreciation	41,038		10,635	9,254	—	—	60,927
Taxes, other than income taxes	56,953		10,737	10,695	—	—	78,385
Total expenses	545,330		104,568	104,588	—	—	754,486
Operating income	56,200		10,720	9,085	—	(130)	75,875
Allowance for equity funds used during construction	2,640		284	377	—	—	3,301
Equity in earnings of subsidiaries	11,541		—	—	—	(11,541)	—
Retirement defined benefits credit (expense)—other than service costs	904		169	(26)	—	—	1,047
Interest expense and other charges, net	(14,557)		(2,831)	(2,988)	—	130	(20,246)
Allowance for borrowed funds used during construction	918		91	122	—	—	1,131
Income before income taxes	57,646		8,433	6,570	—	(11,541)	61,108
Income taxes	10,367		1,909	1,324	—	—	13,600
Net income	47,279		6,524	5,246	—	(11,541)	47,508
Preferred stock dividends of subsidiaries	—		134	95	—	—	229
Net income attributable to Hawaiian Electric	47,279		6,390	5,151	—	(11,541)	47,279
Preferred stock dividends of Hawaiian Electric	270		—	—	—	—	270
Net income for common stock	$	47,009	6,390	5,151	—	(11,541)	$	47,009

Condensed Consolidating Statement of Income

Three months ended March 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsidiaries	Consolidating adjustments	Hawaiian Electric Consolidated
Revenues	$	500,242	108,528	100,028	—	(6)	$	708,792
Expenses
Fuel oil	154,425		25,251	41,610	—	—	221,286
Purchased power	124,183		30,712	8,638	—	—	163,533
Other operation and maintenance	83,656		20,214	21,387	—	—	125,257
Depreciation	39,484		10,351	8,636	—	—	58,471
Taxes, other than income taxes	47,274		10,032	9,344	—	—	66,650
Total expenses	449,022		96,560	89,615	—	—	635,197
Operating income	51,220		11,968	10,413	—	(6)	73,595
Allowance for equity funds used during construction	1,990		193	226	—	—	2,409
Equity in earnings of subsidiaries	13,661		—	—	—	(13,661)	—
Retirement defined benefits credit (expense)—other than service costs	855		167	(32)	—	—	990
Interest expense and other charges, net	(13,093)		(2,609)	(2,630)	—	6	(18,326)
Allowance for borrowed funds used during construction	651		60	67	—	—	778
Income before income taxes	55,284		9,779	8,044	—	(13,661)	59,446
Income taxes	8,605		2,268	1,665	—	—	12,538
Net income	46,679		7,511	6,379	—	(13,661)	46,908
Preferred stock dividends of subsidiaries	—		134	95	—	—	229
Net income attributable to Hawaiian Electric	46,679		7,377	6,284	—	(13,661)	46,679
Preferred stock dividends of Hawaiian Electric	270		—	—	—	—	270
Net income for common stock	$	46,409	7,377	6,284	—	(13,661)	$	46,409

Statements of Income and Comprehensive Income Data

	Three months ended March 31
(in thousands)	2023		2022
Interest and dividend income
Interest and fees on loans	$	64,842	$	46,005
Interest and dividends on investment securities	14,637		13,984
Total interest and dividend income	79,479		59,989
Interest expense
Interest on deposit liabilities	6,837		947
Interest on other borrowings	7,721		5
Total interest expense	14,558		952
Net interest income	64,921		59,037
Provision for credit losses	1,175		(3,263)
Net interest income after provision for credit losses	63,746		62,300
Noninterest income
Fees from other financial services	4,679		5,587
Fee income on deposit liabilities	4,599		4,691
Fee income on other financial products	2,744		2,718
Bank-owned life insurance	1,425		681
Mortgage banking income	130		1,077
Gain on sale of real estate	—		1,002
Other income, net	801		372
Total noninterest income	14,378		16,128
Noninterest expense
Compensation and employee benefits	30,204		27,215
Occupancy	5,588		5,952
Data processing	5,012		4,151
Services	2,595		2,439
Equipment	2,646		2,329
Office supplies, printing and postage	1,165		1,060
Marketing	1,016		1,018
Other expense	6,191		4,049
Total noninterest expense	54,417		48,213
Income before income taxes	23,707		30,215
Income taxes	5,145		6,345
Net income	18,562		23,870
Other comprehensive income (loss), net of taxes	18,430		(122,441)
Comprehensive income (loss)	$	36,992	$	(98,571)

Reconciliation to amounts per HEI Condensed Consolidated Statements of Income*:

	Three months ended March 31
(in thousands)	2023		2022
Interest and dividend income	$	79,479	$	59,989
Noninterest income	14,378		16,128
Less: Gain on sale of real estate	—		1,002
*Revenues-Bank	93,857		75,115
Total interest expense	14,558		952
Provision for credit losses	1,175		(3,263)
Noninterest expense	54,417		48,213
Less: Gain on sale of real estate	—		1,002
Less: Retirement defined benefits credit—other than service costs	(187)		(185)
*Expenses-Bank	70,337		45,085
*Operating income-Bank	23,520		30,030
Add back: Retirement defined benefits credit—other than service costs	(187)		(185)
Income before income taxes	$	23,707	$	30,215

Schedule of statements of comprehensive income data

Statements of Income and Comprehensive Income Data

	Three months ended March 31
(in thousands)	2023		2022
Interest and dividend income
Interest and fees on loans	$	64,842	$	46,005
Interest and dividends on investment securities	14,637		13,984
Total interest and dividend income	79,479		59,989
Interest expense
Interest on deposit liabilities	6,837		947
Interest on other borrowings	7,721		5
Total interest expense	14,558		952
Net interest income	64,921		59,037
Provision for credit losses	1,175		(3,263)
Net interest income after provision for credit losses	63,746		62,300
Noninterest income
Fees from other financial services	4,679		5,587
Fee income on deposit liabilities	4,599		4,691
Fee income on other financial products	2,744		2,718
Bank-owned life insurance	1,425		681
Mortgage banking income	130		1,077
Gain on sale of real estate	—		1,002
Other income, net	801		372
Total noninterest income	14,378		16,128
Noninterest expense
Compensation and employee benefits	30,204		27,215
Occupancy	5,588		5,952
Data processing	5,012		4,151
Services	2,595		2,439
Equipment	2,646		2,329
Office supplies, printing and postage	1,165		1,060
Marketing	1,016		1,018
Other expense	6,191		4,049
Total noninterest expense	54,417		48,213
Income before income taxes	23,707		30,215
Income taxes	5,145		6,345
Net income	18,562		23,870
Other comprehensive income (loss), net of taxes	18,430		(122,441)
Comprehensive income (loss)	$	36,992	$	(98,571)

Reconciliation to amounts per HEI Condensed Consolidated Statements of Income*:

	Three months ended March 31
(in thousands)	2023		2022
Interest and dividend income	$	79,479	$	59,989
Noninterest income	14,378		16,128
Less: Gain on sale of real estate	—		1,002
*Revenues-Bank	93,857		75,115
Total interest expense	14,558		952
Provision for credit losses	1,175		(3,263)
Noninterest expense	54,417		48,213
Less: Gain on sale of real estate	—		1,002
Less: Retirement defined benefits credit—other than service costs	(187)		(185)
*Expenses-Bank	70,337		45,085
*Operating income-Bank	23,520		30,030
Add back: Retirement defined benefits credit—other than service costs	(187)		(185)
Income before income taxes	$	23,707	$	30,215

Schedule of balance sheets data

Condensed Consolidating Balance Sheet

March 31, 2023

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsi- diaries	Consoli- dating adjustments	Hawaiian Electric Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	42,860	5,606	3,594	—	—	$	52,060
Plant and equipment	5,302,293		1,431,852	1,308,747	—	—	8,042,892
Right-of-use assets - finance lease	88,297		—	—	—	—	88,297
Less accumulated depreciation	(1,889,007)		(651,463)	(593,341)	—	—	(3,133,811)
Construction in progress	248,788		28,136	38,938	—	—	315,862
Utility property, plant and equipment, net	3,793,231		814,131	757,938	—	—	5,365,300
Nonutility property, plant and equipment, less accumulated depreciation	5,298		115	1,532	—	—	6,945
Total property, plant and equipment, net	3,798,529		814,246	759,470	—	—	5,372,245
Investment in wholly owned subsidiaries, at equity	705,212		—	—	—	(705,212)	—
Current assets
Cash and cash equivalents	49,393		28,006	38,546	77	—	116,022
Customer accounts receivable, net	172,426		34,224	28,655	—	—	235,305
Accrued unbilled revenues, net	118,035		21,831	20,666	—	—	160,532
Other accounts receivable, net	22,376		3,883	4,677	—	(19,509)	11,427
Fuel oil stock, at average cost	116,295		16,678	24,610	—	—	157,583
Materials and supplies, at average cost	50,744		10,578	22,771	—	—	84,093
Prepayments and other	33,369		5,025	5,515	—	—	43,909
Regulatory assets	58,943		2,575	3,455	—	—	64,973
Total current assets	621,581		122,800	148,895	77	(19,509)	873,844
Other long-term assets
Operating lease right-of-use assets	40,724		32,599	11,607	—	—	84,930
Regulatory assets	151,684		19,041	12,204	—	—	182,929
Other	113,888		32,786	30,402	—	(16,561)	160,515
Total other long-term assets	306,296		84,426	54,213	—	(16,561)	428,374
Total assets	$	5,431,618	1,021,472	962,578	77	(741,282)	$	6,674,463
Capitalization and liabilities
Capitalization
Common stock equity	$	2,358,884	346,629	358,506	77	(705,212)	$	2,358,884
Cumulative preferred stock—not subject to mandatory redemption	22,293		7,000	5,000	—	—	34,293
Long-term debt, net	1,226,587		249,346	258,414	—	—	1,734,347
Total capitalization	3,607,764		602,975	621,920	77	(705,212)	4,127,524
Current liabilities
Current portion of operating lease liabilities	8,955		6,780	2,679	—	—	18,414
Current portion of long-term debt	49,987		19,994	29,992	—	—	99,973
Accounts payable	146,125		20,957	24,687	—	—	191,769
Interest and preferred dividends payable	20,788		3,839	4,740	—	—	29,367
Taxes accrued, including revenue taxes	178,418		34,570	33,926	—	—	246,914
Regulatory liabilities	9,505		7,918	7,811	—	—	25,234
Other	61,360		21,072	23,657	—	(19,509)	86,580
Total current liabilities	475,138		115,130	127,492	—	(19,509)	698,251
Deferred credits and other liabilities
Operating lease liabilities	39,387		26,087	9,159	—	—	74,633
Finance lease liabilities	84,341		—	—	—	—	84,341
Deferred income taxes	271,588		50,657	62,708	—	—	384,953
Regulatory liabilities	745,894		195,238	103,185	—	—	1,044,317
Unamortized tax credits	68,123		12,903	12,419	—	—	93,445
Defined benefit pension and other postretirement benefit plans liability	65,917		—	—	—	(16,529)	49,388
Other	73,466		18,482	25,695	—	(32)	117,611
Total deferred credits and other liabilities	1,348,716		303,367	213,166	—	(16,561)	1,848,688
Total capitalization and liabilities	$	5,431,618	1,021,472	962,578	77	(741,282)	$	6,674,463

Condensed Consolidating Balance Sheet

December 31, 2022

(in thousands)	Hawaiian Electric		Hawaii Electric Light	Maui Electric	Other subsi-diaries	Consoli- dating adjustments	Hawaiian Electric Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	42,860	5,606	3,594	—	—	$	52,060
Plant and equipment	5,260,685		1,425,442	1,293,383	—	—	7,979,510
Finance lease right-of-use assets	48,371		—	—	—	—	48,371
Less accumulated depreciation	(1,855,150)		(644,457)	(586,892)	—	—	(3,086,499)
Construction in progress	215,560		23,989	35,804	—	—	275,353
Utility property, plant and equipment, net	3,712,326		810,580	745,889	—	—	5,268,795
Nonutility property, plant and equipment, less accumulated depreciation	5,298		115	1,532	—	—	6,945
Total property, plant and equipment, net	3,717,624		810,695	747,421	—	—	5,275,740
Investment in wholly owned subsidiaries, at equity	701,833		—	—	—	(701,833)	—
Current assets
Cash and cash equivalents	27,579		5,092	6,494	77	—	39,242
Advances to affiliates	—		4,500	21,700	—	(26,200)	—
Customer accounts receivable, net	216,802		39,339	32,197	—	—	288,338
Accrued unbilled revenues, net	136,508		23,839	22,933	—	—	183,280
Other accounts receivable, net	23,746		5,519	6,686	—	(22,384)	13,567
Fuel oil stock, at average cost	153,342		16,964	21,224	—	—	191,530
Materials and supplies, at average cost	48,130		9,783	21,655	—	—	79,568
Prepayments and other	24,040		6,346	4,137	—	(1,041)	33,482
Regulatory assets	46,504		2,435	3,334	—	—	52,273
Total current assets	676,651		113,817	140,360	77	(49,625)	881,280
Other long-term assets
Operating lease right-of-use assets	42,752		34,283	12,283	—	—	89,318
Regulatory assets	154,040		21,816	14,384	—	—	190,240
Other	115,028		32,654	29,495	—	(16,288)	160,889
Total other long-term assets	311,820		88,753	56,162	—	(16,288)	440,447
Total assets	$	5,407,928	1,013,265	943,943	77	(767,746)	$	6,597,467
Capitalization and liabilities
Capitalization
Common stock equity	$	2,344,170	344,720	357,036	77	(701,833)	$	2,344,170
Cumulative preferred stock—not subject to mandatory redemption	22,293		7,000	5,000	—	—	34,293
Long-term debt, net	1,126,915		224,439	233,500	—	—	1,584,854
Total capitalization	3,493,378		576,159	595,536	77	(701,833)	3,963,317
Current liabilities
Current portion of operating lease liabilities	9,775		6,690	2,630	—	—	19,095
Current portion of long-term debt	49,981		19,992	29,989	—	—	99,962
Short-term borrowings-affiliate	26,200		—	—	—	(26,200)	—
Accounts payable	143,253		32,113	27,126	—	—	202,492
Interest and preferred dividends payable	12,398		2,576	2,282	—	(80)	17,176
Taxes accrued, including revenue taxes	207,798		42,436	40,709	—	(1,041)	289,902
Regulatory liabilities	13,145		8,553	9,777	—	—	31,475
Other	64,659		20,856	22,385	—	(22,304)	85,596
Total current liabilities	615,176		133,216	134,898	—	(49,625)	833,665
Deferred credits and other liabilities
Operating lease liabilities	41,049		27,817	9,849	—	—	78,715
Finance lease liabilities	46,048		—	—	—	—	46,048
Deferred income taxes	271,234		50,615	62,581	—	—	384,430
Regulatory liabilities	729,683		194,222	100,270	—	—	1,024,175
Unamortized tax credits	69,614		13,150	12,536	—	—	95,300
Defined benefit pension and other postretirement benefit plans liability	65,907		129	—	—	(16,288)	49,748
Other	75,839		17,957	28,273		—	122,069
Total deferred credits and other liabilities	1,299,374		303,890	213,509	—	(16,288)	1,800,485
Total capitalization and liabilities	$	5,407,928	1,013,265	943,943	77	(767,746)	$	6,597,467

Balance Sheets Data

(in thousands)	March 31, 2023				December 31, 2022
Assets
Cash and due from banks			$	138,742			$	153,042
Interest-bearing deposits			44,315				3,107
Cash and cash equivalents			183,057				156,149
Investment securities
Available-for-sale, at fair value			1,419,755				1,429,667
Held-to-maturity, at amortized cost (fair value of $1,158,090 and $1,150,971, respectively)			1,238,185				1,251,747
Stock in Federal Home Loan Bank, at cost			10,000				26,560
Loans held for investment			6,059,354				5,978,906
Allowance for credit losses			(71,296)				(72,216)
Net loans			5,988,058				5,906,690
Loans held for sale, at lower of cost or fair value			660				824
Other			688,165				692,143
Goodwill			82,190				82,190
Total assets			$	9,610,070			$	9,545,970
Liabilities and shareholder’s equity
Deposit liabilities—noninterest-bearing			$	2,769,789			$	2,811,077
Deposit liabilities—interest-bearing			5,460,812				5,358,619
Other borrowings			680,690				695,120
Other			206,317				212,269
Total liabilities			9,117,608				9,077,085
Common stock			1				1
Additional paid-in capital			356,391				355,806
Retained earnings			454,255				449,693
Accumulated other comprehensive loss, net of tax benefits
Net unrealized losses on securities	$	(308,622)			$	(328,904)
Retirement benefit plans	(9,563)		(318,185)		(7,711)		(336,615)
Total shareholder’s equity			492,462				468,885
Total liabilities and shareholder’s equity			$	9,610,070			$	9,545,970
Other assets
Bank-owned life insurance			$	183,936			$	182,986
Premises and equipment, net			192,789				195,324
Accrued interest receivable			26,547				25,077
Mortgage-servicing rights			8,745				9,047
Low-income housing investments			110,748				106,978
Real estate held for sale			100				—
Deferred tax asset			109,885				116,441
Real estate acquired in settlement of loans, net			614				115
Other			54,801				56,175
			$	688,165			$	692,143
Other liabilities
Accrued expenses			$	95,066			$	97,295
Federal and state income taxes payable			2,614				863
Cashier’s checks			34,616				36,401
Advance payments by borrowers			5,466				9,637
Other			68,555				68,073
			$	206,317			$	212,269

Schedule of the book value and aggregate fair value by major security type

The major components of investment securities were as follows:

	Amortized cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value		Gross unrealized losses
									Less than 12 months					12 months or longer
(dollars in thousands)									Number of issues	Fair  value		Amount		Number of issues	Fair  value		Amount
March 31, 2023
Available-for-sale
U.S. Treasury and federal agency obligations	$	85,786	$	—	$	(6,042)	$	79,744	—	$	—	$	—	14	$	79,744	$	(6,042)
Mortgage-backed securities*	1,500,717		1		(216,783)		1,283,935		24	89,727		(7,367)		158	1,193,633		(209,416)
Corporate bonds	44,341		—		(3,031)		41,310		2	8,951		(50)		3	32,359		(2,981)
Mortgage revenue bonds	14,766		—		—		14,766		—	—		—		—	—		—
	$	1,645,610	$	1	$	(225,856)	$	1,419,755	26	$	98,678	$	(7,417)	175	$	1,305,736	$	(218,439)
Held-to-maturity
U.S. Treasury and federal agency obligations	$	59,900	$	—	$	(7,172)	$	52,728	—	$	—	$	—	3	$	52,728	$	(7,172)
Mortgage-backed securities*	1,178,285		8,875		(81,798)		1,105,362		6	64,288		(532)		41	427,520		(81,266)
	$	1,238,185	$	8,875	$	(88,970)	$	1,158,090	6	$	64,288	$	(532)	44	$	480,248	$	(88,438)
December 31, 2022
Available-for-sale
U.S. Treasury and federal agency obligations	$	88,344	$	—	$	(7,281)	$	81,063	12	$	41,201	$	(2,120)	4	$	39,862	$	(5,161)
Mortgage-backed securities*	1,530,582		—		(237,614)		1,292,968		113	455,836		(56,999)		70	837,132		(180,615)
Corporate bonds	44,377		—		(3,643)		40,734		4	29,644		(2,028)		1	11,090		(1,615)
Mortgage revenue bonds	14,902		—		—		14,902		—	—		—		—	—		—
	$	1,678,205	$	—	$	(248,538)	$	1,429,667	129	$	526,681	$	(61,147)	75	$	888,084	$	(187,391)
Held-to-maturity
U.S. Treasury and federal agency obligations	$	59,894	$	—	$	(8,478)	$	51,416	1	$	16,874	$	(3,222)	2	$	34,542	$	(5,256)
Mortgage-backed securities*	1,191,853		2,670		(94,968)		1,099,555		22	183,629		(10,593)		51	567,250		(84,375)
	$	1,251,747	$	2,670	$	(103,446)	$	1,150,971	23	$	200,503	$	(13,815)	53	$	601,792	$	(89,631)

* Issued or guaranteed by U.S. Government agencies or sponsored agencies

Schedule of contractual maturities of available-for-sale securities

The contractual maturities of investment securities were as follows:

March 31, 2023	Amortized  cost		Fair value
(in thousands)
Available-for-sale
Due in one year or less	$	2,579	$	2,531
Due after one year through five years	127,548		118,523
Due after five years through ten years	14,766		14,766
Due after ten years	—		—
	144,893		135,820
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	1,500,717		1,283,935
Total available-for-sale securities	$	1,645,610	$	1,419,755
Held-to-maturity
Due in one year or less	$	—	$	—
Due after one year through five years	—		—
Due after five years through ten years	59,900		52,728
Due after ten years	—		—
	59,900		52,728
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	1,178,285		1,105,362
Total held-to-maturity securities	$	1,238,185	$	1,158,090

Schedule of components of loans receivable

The components of loans were summarized as follows:

	March 31, 2023		December 31, 2022
(in thousands)
Real estate:
Residential 1-4 family	$	2,484,316	$	2,479,637
Commercial real estate	1,377,184		1,358,123
Home equity line of credit	1,022,800		1,002,905
Residential land	20,061		20,679
Commercial construction	94,267		88,489
Residential construction	15,749		20,788
Total real estate	5,014,377		4,970,621
Commercial	800,949		779,691
Consumer	272,401		254,709
Total loans	6,087,727		6,005,021
Less: Deferred fees and discounts	(28,373)		(26,115)
Allowance for credit losses	(71,296)		(72,216)
Total loans, net	$	5,988,058	$	5,906,690

Schedule of 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 land		Commercial construction		Residential construction		Commercial loans		Consumer loans		Total
Three months ended March 31, 2023
Allowance for credit losses:
Beginning balance	$	6,270	$	21,898	$	6,125	$	717	$	1,195	$	46	$	12,426	$	23,539	$	72,216
Charge-offs	(809)		—		(63)		—		—		—		(227)		(2,323)		(3,422)
Recoveries	4		—		17		—		—		—		398		908		1,327
Provision	(853)		803		(26)		(97)		(460)		(18)		(661)		2,487		1,175
Ending balance	$	4,612	$	22,701	$	6,053	$	620	$	735	$	28	$	11,936	$	24,611	$	71,296
Three months ended March 31, 2022
Allowance for credit losses:
Beginning balance	$	6,545	$	24,696	$	5,657	$	646	$	2,186	$	18	$	15,798	$	15,584	$	71,130
Charge-offs	—		—		—		—		—		—		(76)		(1,482)		(1,558)
Recoveries	8		—		11		5		—		—		353		1,025		1,402
Provision	1,321		(4,520)		(18)		46		154		13		(1,761)		1,002		(3,763)
Ending balance	$	7,874	$	20,176	$	5,650	$	697	$	2,340	$	31	$	14,314	$	16,129	$	67,211

Schedule of allowance for loan commitments

The allowance for loan commitments by portfolio segment were as follows:

(in thousands)	Home equity  line of credit		Commercial construction		Commercial loans		Total
Three months ended March 31, 2023
Allowance for loan commitments:
Beginning balance	$	400	$	2,600	$	1,400	$	4,400
Provision	—		—		—		—
Ending balance	$	400	$	2,600	$	1,400	$	4,400
Three months ended March 31, 2022
Allowance for loan commitments:
Beginning balance	$	400	$	3,700	$	800	$	4,900
Provision	—		(100)		600		500
Ending balance	$	400	$	3,600	$	1,400	$	5,400

Schedule of credit risk profile by internally assigned grade for loans

The credit risk profile by vintage date based on payment activity or internally assigned grade for loans was as follows:

	Term Loans by Origination Year												Revolving Loans
(in thousands)	2023		2022		2021		2020		2019		Prior		Revolving		Converted to term loans		Total
March 31, 2023
Residential 1-4 family
Current	$	46,292	$	425,843	$	750,578	$	418,780	$	110,618	$	727,411	$	—	$	—	$	2,479,522
30-59 days past due	—		—		—		—		938		971		—		—		1,909
60-89 days past due	—		—		—		—		—		930		—		—		930
Greater than 89 days past due	—		—		—		267		—		1,688		—		—		1,955
	46,292		425,843		750,578		419,047		111,556		731,000		—		—		2,484,316
Current YTD period
Gross charge-offs	—		—		—		—		—		809		—		—		809
Home equity line of credit
Current	—		—		—		—		—		—		973,686		46,565		1,020,251
30-59 days past due	—		—		—		—		—		—		781		115		896
60-89 days past due	—		—		—		—		—		—		346		337		683
Greater than 89 days past due	—		—		—		—		—		—		573		397		970
	—		—		—		—		—		—		975,386		47,414		1,022,800
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		63		63
Residential land
Current	1,204		5,237		8,587		4,039		—		994		—		—		20,061
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	1,204		5,237		8,587		4,039		—		994		—		—		20,061
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Residential construction
Current	1,444		6,786		7,519		—		—		—		—		—		15,749
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	1,444		6,786		7,519		—		—		—		—		—		15,749
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Consumer
Current	36,794		189,133		18,047		4,233		4,301		341		9,589		4,904		267,342
30-59 days past due	203		1,628		235		54		170		11		78		120		2,499
60-89 days past due	—		899		116		59		129		4		16		117		1,340
Greater than 89 days past due	—		502		199		59		105		26		82		247		1,220
	36,997		192,162		18,597		4,405		4,705		382		9,765		5,388		272,401
Current YTD period
Gross charge-offs	189		1,523		319		57		135		21		15		64		2,323
Commercial real estate
Pass	41,312		392,018		174,655		276,754		52,121		339,660		8,235		—		1,284,755
Special Mention	—		—		11,250		3,425		30,179		21,307		—		—		66,161
Substandard	5,433		—		—		659		11,356		8,820		—		—		26,268
Doubtful	—		—		—		—		—		—		—		—		—
	46,745		392,018		185,905		280,838		93,656		369,787		8,235		—		1,377,184

	Term Loans by Origination Year												Revolving Loans
(in thousands)	2023		2022		2021		2020		2019		Prior		Revolving		Converted to term loans		Total
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Commercial construction
Pass	—		11,206		54,924		44		—		—		28,093		—		94,267
Special Mention	—		—		—		—		—		—		—		—		—
Substandard	—		—		—		—		—		—		—		—		—
Doubtful	—		—		—		—		—		—		—		—		—
	—		11,206		54,924		44		—		—		28,093		—		94,267
Current YTD period
Gross charge-offs	—		—		—		—		—		—		—		—		—
Commercial
Pass	30,142		238,671		184,551		86,275		60,265		97,277		66,200		12,918		776,299
Special Mention	—		—		—		—		2,255		—		8,492		6		10,753
Substandard	—		3,234		1,507		398		1,320		5,195		899		1,344		13,897
Doubtful	—		—		—		—		—		—		—		—		—
	30,142		241,905		186,058		86,673		63,840		102,472		75,591		14,268		800,949
Current YTD period
Gross charge-offs	—		—		51		—		—		—		14		162		227
Total loans	$	162,824	$	1,275,157	$	1,212,168	$	795,046	$	273,757	$	1,204,635	$	1,097,070	$	67,070	$	6,087,727

	Term Loans by Origination Year												Revolving Loans
(in thousands)	2022		2021		2020		2019		2018		Prior		Revolving		Converted to term loans		Total
December 31, 2022
Residential 1-4 family
Current	$	432,707	$	755,056	$	423,455	$	113,096	$	51,860	$	698,354	$	—	$	—	$	2,474,528
30-59 days past due	—		—		—		—		448		1,098		—		—		1,546
60-89 days past due	—		—		268		—		—		90		—		—		358
Greater than 89 days past due	—		—		—		—		809		2,396		—		—		3,205
	432,707		755,056		423,723		113,096		53,117		701,938		—		—		2,479,637
Home equity line of credit
Current	—		—		—		—		—		—		959,131		40,814		999,945
30-59 days past due	—		—		—		—		—		—		1,103		209		1,312
60-89 days past due	—		—		—		—		—		—		209		226		435
Greater than 89 days past due	—		—		—		—		—		—		587		626		1,213
	—		—		—		—		—		—		961,030		41,875		1,002,905
Residential land
Current	5,245		9,010		5,222		203		522		477		—		—		20,679
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	5,245		9,010		5,222		203		522		477		—		—		20,679
Residential construction
Current	7,986		11,624		1,178		—		—		—		—		—		20,788
30-59 days past due	—		—		—		—		—		—		—		—		—
60-89 days past due	—		—		—		—		—		—		—		—		—
Greater than 89 days past due	—		—		—		—		—		—		—		—		—
	7,986		11,624		1,178		—		—		—		—		—		20,788
Consumer
Current	199,574		21,330		5,543		7,580		527		140		10,810		4,782		250,286
30-59 days past due	1,110		287		65		239		30		—		81		167		1,979
60-89 days past due	756		163		88		137		19		—		45		107		1,315
Greater than 89 days past due	621		105		37		176		28		—		20		142		1,129
	202,061		21,885		5,733		8,132		604		140		10,956		5,198		254,709
Commercial real estate
Pass	390,206		177,130		283,321		51,542		63,084		278,280		8,235		—		1,251,798
Special Mention	—		11,250		3,446		40,423		—		24,466		—		—		79,585
Substandard	—		—		665		11,357		—		14,718		—		—		26,740
Doubtful	—		—		—		—		—		—		—		—		—
	390,206		188,380		287,432		103,322		63,084		317,464		8,235		—		1,358,123
Commercial construction
Pass	15,094		47,478		44		—		—		—		25,873		—		88,489
Special Mention	—		—		—		—		—		—		—		—		—
Substandard	—		—		—		—		—		—		—		—		—
Doubtful	—		—		—		—		—		—		—		—		—
	15,094		47,478		44		—		—		—		25,873		—		88,489
Commercial
Pass	239,852		185,013		85,220		68,161		46,142		53,192		60,871		13,964		752,415
Special Mention	—		—		—		2,374		—		645		9,005		8		12,032
Substandard	3,322		2,305		401		1,304		1,346		3,849		1,664		1,053		15,244
Doubtful	—		—		—		—		—		—		—		—		—
	243,174		187,318		85,621		71,839		47,488		57,686		71,540		15,025		779,691
Total loans	$	1,296,473	$	1,220,751	$	808,953	$	296,592	$	164,815	$	1,077,705	$	1,077,634	$	62,098	$	6,005,021

Schedule of credit risk profile based on payment activity for loans

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		Current		Total financing receivables		Amortized cost> 90 days and accruing
March 31, 2023
Real estate:
Residential 1-4 family	$	1,909	$	930	$	1,955	$	4,794	$	2,479,522	$	2,484,316	$	—
Commercial real estate	—		—		—		—		1,377,184		1,377,184		—
Home equity line of credit	896		683		970		2,549		1,020,251		1,022,800		—
Residential land	—		—		—		—		20,061		20,061		—
Commercial construction	—		—		—		—		94,267		94,267		—
Residential construction	—		—		—		—		15,749		15,749		—
Commercial	263		71		427		761		800,188		800,949		—
Consumer	2,499		1,340		1,220		5,059		267,342		272,401		—
Total loans	$	5,567	$	3,024	$	4,572	$	13,163	$	6,074,564	$	6,087,727	$	—
December 31, 2022
Real estate:
Residential 1-4 family	$	1,546	$	358	$	3,205	$	5,109	$	2,474,528	$	2,479,637	$	—
Commercial real estate	508		217		—		725		1,357,398		1,358,123		—
Home equity line of credit	1,312		435		1,213		2,960		999,945		1,002,905		—
Residential land	—		—		—		—		20,679		20,679		—
Commercial construction	—		—		—		—		88,489		88,489		—
Residential construction	—		—		—		—		20,788		20,788		—
Commercial	614		18		77		709		778,982		779,691		—
Consumer	1,979		1,315		1,129		4,423		250,286		254,709		—
Total loans	$	5,959	$	2,343	$	5,624	$	13,926	$	5,991,095	$	6,005,021	$	—

Schedule of credit risk profile based on nonaccrual loans, accruing loans 90 days or more past due

The credit risk profile based on nonaccrual loans were as follows:

(in thousands)	March 31, 2023						December 31, 2022
	With a Related ACL		Without a Related ACL		Total		With a Related ACL		Without a Related ACL		Total
Real estate:
Residential 1-4 family	$	3,371	$	2,117	$	5,488	$	4,198	$	2,981	$	7,179
Commercial real estate	—		—		—		—		—		—
Home equity line of credit	4,014		1,237		5,251		3,654		1,442		5,096
Residential land	109		—		109		420		—		420
Commercial construction	—		—		—		—		—		—
Residential construction	—		—		—		—		—		—
Commercial	1,744		—		1,744		2,183		—		2,183
Consumer	1,895		—		1,895		1,588		—		1,588
Total	$	11,133	$	3,354	$	14,487	$	12,043	$	4,423	$	16,466

The credit risk profile based on loans whose terms have been modified and accruing interest were as follows:

(in thousands)	December 31, 2022
Real estate:
Residential 1-4 family	$	8,821
Commercial real estate	9,477
Home equity line of credit	4,404
Residential land	782
Commercial construction	—
Residential construction	—
Commercial	6,596
Consumer	50
Total troubled debt restructured loans accruing interest	$	30,130

Schedule of collateral-dependent loans

Loans considered collateral-dependent were as follows:

	Amortized cost
(in thousands)	March 31, 2023		December 31, 2022		Collateral type
Real estate:
Residential 1-4 family	$	2,353	$	3,959	Residential real estate property
Home equity line of credit	1,237		1,425		Residential real estate property
Total	$	3,590	$	5,384

Schedule of amortized intangible assets

Changes in the carrying value of MSRs were as follows:

(in thousands)	Gross carrying amount		Accumulated amortization		Valuation allowance		Net carrying amount
March 31, 2023	$	17,868	$	(9,123)	$	—	$	8,745
December 31, 2022	19,544		(10,497)		—		9,047

Changes related to MSRs were as follows:

	Three months ended March 31
(in thousands)	2023		2022
Mortgage servicing rights
Beginning balance	$	9,047	$	9,950
Amount capitalized	51		719
Amortization	(353)		(645)
Other-than-temporary impairment	—		—
Carrying amount before valuation allowance	8,745		10,024
Valuation allowance for mortgage servicing rights
Beginning balance	—		—
Provision	—		—
Other-than-temporary impairment	—		—
Ending balance	—		—
Net carrying value of mortgage servicing rights	$	8,745	$	10,024

Schedule of key assumptions used in estimating fair value

Key assumptions used in estimating the fair value of ASB’s MSRs used in the impairment analysis were as follows:

(dollars in thousands)	March 31, 2023			December 31, 2022
Unpaid principal balance	$	1,431,037		$	1,451,322
Weighted average note rate	3.39		%	3.38		%
Weighted average discount rate	10.00		%	10.00		%
Weighted average prepayment speed	6.39		%	6.56		%

Schedule of sensitivity analysis of fair value, transferor's interests in transferred financial assets

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)	March 31, 2023		December 31, 2022
Prepayment rate:
25 basis points adverse rate change	$	(109)	$	(92)
50 basis points adverse rate change	(243)		(214)
Discount rate:
25 basis points adverse rate change	(190)		(182)
50 basis points adverse rate change	(376)		(361)

Schedule of securities sold under agreements to repurchase

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
March 31, 2023	$	131	$	—	$	131
December 31, 2022	281		—		281

	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
March 31, 2023	$	131	$	172	$	—
December 31, 2022	281		327		—

Schedule of notional and fair value of derivatives

The notional amount and fair value of ASB’s derivative financial instruments were as follows:

	March 31, 2023				December 31, 2022
(in thousands)	Notional amount		Fair value		Notional amount		Fair value
Interest rate lock commitments	$	2,467	$	26	$	1,720	$	9
Forward commitments	2,250		5		1,500		18

Schedule of derivative financial instruments

ASB’s derivative financial instruments, their fair values and balance sheet location were as follows:

Derivative Financial Instruments Not Designated as Hedging Instruments 1	March 31, 2023				December 31, 2022
(in thousands)	Asset derivatives		Liability derivatives		Asset derivatives		Liability derivatives
Interest rate lock commitments	$	26	$	—	$	9	$	—
Forward commitments	9		4		18		—
	$	35	$	4	$	27	$	—

1 Asset derivatives are included in other assets and liability derivatives are included in other liabilities in the balance sheets.

Schedule of derivative financial instruments and net gain or loss

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 Income	Three months ended March 31
(in thousands)		2023		2022
Interest rate lock commitments	Mortgage banking income	$	17	$	(655)
Forward commitments	Mortgage banking income	(13)		178
		$	4	$	(477)

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Credit agreement and changes in debt (Tables)

3 Months Ended

Mar. 31, 2023

Debt Disclosure [Abstract]

Schedule of notes

	HEI Series 2023A	HEI Series 2023B
Aggregate principal amount	$39 million	$61 million
Fixed coupon interest rate	6.04%	6.10%
Maturity date	6/15/2028	6/15/2033

	Series 2023A	Series 2023B	Series 2023C
Aggregate principal amount	$90 million	$40 million	$20 million
Fixed coupon interest rate
Hawaiian Electric	6.11%	6.25%	6.70%
Hawaii Electric Light	6.25%	—	—
Maui Electric	6.25%	—	—
Maturity date
Hawaiian Electric	2/9/2030	2/9/2033	2/9/2053
Hawaii Electric Light	2/9/2033	—	—
Maui Electric	2/9/2033	—	—
Principal amount by company:
Hawaiian Electric	$40 million	$40 million	$20 million
Hawaii Electric Light	$25 million	—	—
Maui Electric	$25 million	—	—

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Shareholders' equity (Tables)

3 Months Ended

Mar. 31, 2023

Equity [Abstract]

Schedule of accumulated other comprehensive income

Changes in the balances of each component of accumulated other comprehensive income/(loss) (AOCI) were as follows:

	HEI Consolidated								Hawaiian Electric Consolidated
(in thousands)	Net unrealized gains (losses) on securities		Unrealized gains (losses) on derivatives		Retirement benefit plans		AOCI		AOCI-Retirement benefit plans
Balance, December 31, 2022	$	(328,904)	$	1,991	$	(9,115)	$	(336,028)	$	2,861
Current period other comprehensive income (loss)	20,282		138		68		20,488		(45)
Balance, March 31, 2023	$	(308,622)	$	2,129	$	(9,047)	$	(315,540)	$	2,816
Balance, December 31, 2021	$	(32,037)	$	(3,638)	$	(16,858)	$	(52,533)	$	(3,280)
Current period other comprehensive income (loss)	(120,407)		3,072		176		(117,159)		51
Balance, March 31, 2022	$	(152,444)	$	(566)	$	(16,682)	$	(169,692)	$	(3,229)

Schedule of reclassifications out of accumulated other comprehensive income/(loss)

Reclassifications out of AOCI were as follows:

	Amount reclassified from AOCI					Affected line item in the  Statements of Income / Balance Sheets
		Three months ended March 31
(in thousands)		2023		2022
HEI consolidated
Net unrealized gains (losses) on available-for sale investment securities - amortization of unrealized holding losses on held-to-maturity securities		$	3,677	$	—	Bank revenues
Net realized losses (gains) on derivatives qualifying as cash flow hedges		(48)		55		Interest expense
Retirement benefit plans:
Amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost		(357)		4,501		See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets		425		(4,325)		See Note 8 for additional details
Total reclassifications		$	3,697	$	231
Hawaiian Electric consolidated
Retirement benefit plans:
Amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost		$	(470)	$	4,376	See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets		425		(4,325)		See Note 8 for additional details
Total reclassifications		$	(45)	$	51

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Revenues (Tables)

3 Months Ended

Mar. 31, 2023

Revenue from Contract with Customer [Abstract]

Disaggregation of revenue

The following tables disaggregate revenues by major source, timing of revenue recognition, and segment:

	Three months ended March 31, 2023
(in thousands)	Electric  utility		Bank		Other		Total
Revenues from contracts with customers
Electric energy sales - residential	$	255,550	$	—	$	—	$	255,550
Electric energy sales - commercial	254,470		—		—		254,470
Electric energy sales - large light and power	290,978		—		—		290,978
Electric energy sales - other	5,457		—		—		5,457
Bank fees	—		12,022		—		12,022
Other sales	—		—		3,907		3,907
Total revenues from contracts with customers	806,455		12,022		3,907		822,384
Revenues from other sources
Regulatory revenue	$	15,604	$	—	$	—	$	15,604
Bank interest and dividend income	—		79,479		—		79,479
Other bank noninterest income	—		2,356		—		2,356
Other	8,302		—		112		8,414
Total revenues from other sources	23,906		81,835		112		105,853
Total revenues	$	830,361	$	93,857	$	4,019	$	928,237
Timing of revenue recognition
Services/goods transferred at a point in time	$	—	$	12,022	$	—	$	12,022
Services/goods transferred over time	806,455		—		3,907		810,362
Total revenues from contracts with customers	$	806,455	$	12,022	$	3,907	$	822,384

	Three months ended March 31, 2022
(in thousands)	Electric  utility		Bank		Other		Total
Revenues from contracts with customers
Electric energy sales - residential	$	224,574	$	—	$	—	$	224,574
Electric energy sales - commercial	219,597		—		—		219,597
Electric energy sales - large light and power	241,123		—		—		241,123
Electric energy sales - other	1,426		—		—		1,426
Bank fees	—		12,996		—		12,996
Other sales	—		—		1,115		1,115
Total revenues from contracts with customers	686,720		12,996		1,115		700,831
Revenues from other sources
Regulatory revenue	12,886		—		—		12,886
Bank interest and dividend income	—		59,989		—		59,989
Other bank noninterest income	—		2,130		—		2,130
Other	9,186		—		46		9,232
Total revenues from other sources	22,072		62,119		46		84,237
Total revenues	$	708,792	$	75,115	$	1,161	$	785,068
Timing of revenue recognition
Services/goods transferred at a point in time	$	—	$	12,996	$	—	$	12,996
Services/goods transferred over time	686,720		—		1,115		687,835
Total revenues from contracts with customers	$	686,720	$	12,996	$	1,115	$	700,831

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Retirement benefits (Tables)

3 Months Ended

Mar. 31, 2023

Retirement Benefits [Abstract]

Schedule of components of net periodic benefit cost for consolidated HEI

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 March 31
	Pension benefits				Other benefits
(in thousands)	2023		2022		2023		2022
HEI consolidated
Service cost	$	11,396	$	19,824	$	344	$	656
Interest cost	25,621		19,811		2,157		1,637
Expected return on plan assets	(35,195)		(35,333)		(3,405)		(3,397)
Amortization of net prior period gain	—		—		(219)		(232)
Amortization of net actuarial (gain)/losses	188		6,297		(449)		(3)
Net periodic pension/benefit cost (return)	2,010		10,599		(1,572)		(1,339)
Impact of PUC D&Os	18,133		9,551		1,425		1,219
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)	$	20,143	$	20,150	$	(147)	$	(120)
Hawaiian Electric consolidated
Service cost	$	11,019	$	19,318	$	340	$	649
Interest cost	23,698		18,462		2,063		1,573
Expected return on plan assets	(32,972)		(33,546)		(3,353)		(3,347)
Amortization of net prior period gain	—		—		(218)		(231)
Amortization of net actuarial (gain)/losses	19		6,125		(434)		—
Net periodic pension/benefit cost (return)	1,764		10,359		(1,602)		(1,356)
Impact of PUC D&Os	18,133		9,551		1,425		1,219
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)	$	19,897	$	19,910	$	(177)	$	(137)

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Share-based compensation (Tables)

3 Months Ended

Mar. 31, 2023

Share-Based Payment Arrangement [Abstract]

Schedule of share-based compensation expense and related income tax benefit

Share-based compensation expense and the related income tax benefit were as follows:

	Three months ended March 31
(in millions)	2023		2022
HEI consolidated
Share-based compensation expense 1	$	2.0	$	2.1
Income tax benefit	0.3		0.3
Hawaiian Electric consolidated
Share-based compensation expense 1	0.7		0.6
Income tax benefit	0.1		0.1

1    For the three months ended March 31, 2023 and 2022, the Company has not capitalized any share-based compensation.

Schedule of common stock granted to nonemployee directors

HEI granted HEI common stock to nonemployee directors under the 2011 Director Plan as follows:

	Three months ended March 31
(dollars in millions)	2023		2022
Shares granted	1,509		—
Fair value	$	0.1	$	—
Income tax benefit	—		—

Schedule of restricted stock units

Information about HEI’s grants of restricted stock units was as follows:

	Three months ended March 31
	2023				2022
	Shares		(1)		Shares		(1)
Outstanding, beginning of period	182,528		$	39.75	233,448		$	38.10
Granted	100,088		42.41		96,455		41.29
Vested	(80,077)		39.30		(90,380)		37.58
Forfeited	(406)		38.39		(31,178)		38.78
Outstanding, end of period	202,133		$	41.25	208,345		$	39.71
Total weighted-average grant-date fair value of shares granted (in millions)	$	4.2			$	4.0

(1)    Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.

Schedule of Long-Term Incentive Plan (LTIP) linked to total return to shareholders

Information about HEI’s LTIP grants linked to TSR was as follows:

	Three months ended March 31
	2023				2022
	Shares		(1)		Shares		(1)
Outstanding, beginning of period	71,574		$	47.67	90,974		$	42.86
Granted	27,123		55.98		26,079		54.92
Vested (issued or unissued and cancelled)	(18,691)		48.62		(29,042)		41.07
Forfeited	—		—		(11,671)		42.60
Outstanding, end of period	80,006		$	50.27	76,340		$	47.70
Total weighted-average grant-date fair value of shares granted (in millions)	$	1.5			$	1.4

(1)    Weighted-average grant-date fair value per share determined using a Monte Carlo simulation model.

Schedule of Long-Term Incentive Plan assumptions

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:

	2023		2022
Risk-free interest rate	4.19	%	1.71	%
Expected life in years	3		3
Expected volatility	33.1	%	31.0	%
Range of expected volatility for Peer Group	28.7% to 38.8%		25.4% to 76.7%
Grant date fair value (per share)	$55.98		$54.92

Schedule of Long-Term Incentive Plan (LTIP) 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 March 31
	2023				2022
	Shares		(1)		Shares		(1)
Outstanding, beginning of period	309,589		$	39.50	306,342		$	38.42
Granted	108,499		42.41		104,300		41.29
Vested	(62,778)		48.07		(71,807)		37.68
Forfeited	—		—		(46,684)		36.77
Outstanding, end of period	355,310		$	38.87	292,151		$	39.89
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)	$	4.6			$	4.3

(1)    Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.

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Cash flows (Tables)

3 Months Ended

Mar. 31, 2023

Supplemental Cash Flow Elements [Abstract]

Schedule of supplemental disclosures of cash and noncash activity

Three months ended March 31	2023		2022
(in millions)
Supplemental disclosures of cash flow information
HEI consolidated
Interest paid to non-affiliates, net of amounts capitalized	$	21	$	10
Hawaiian Electric consolidated
Interest paid to non-affiliates	6		6
Income taxes paid (including refundable credits)	3		—
Supplemental disclosures of noncash activities
HEI consolidated
Property, plant and equipment
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)	50		24
Increase related to an acquisition (investing)	—		15
Right-of-use assets obtained in exchange for finance lease obligations (financing)	40		—
Right-of-use assets obtained in exchange for operating lease obligations (investing)	1		35
Common stock issued (gross) for director and executive/management compensation (financing)1	7		8
Obligations to fund low income housing investments (investing)	7		—
Unsettled trades to purchase investment securities (investing)	—		25
Other receivable related to pending sales proceeds from the sale of an equity-method investment (investing)	—		9
Hawaiian Electric consolidated
Electric utility property, plant and equipment
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)	48		21
Increase related to an acquisition (investing)	—		15
Right-of-use assets obtained in exchange for finance lease obligations (financing)	40		—
Right-of-use assets obtained in exchange for operating lease obligations (investing)	—		32

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.

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Fair value measurements (Tables)

3 Months Ended

Mar. 31, 2023

Fair Value Disclosures [Abstract]

Schedule of estimated fair values of certain of the Company's financial instruments

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 amount		Quoted prices in active markets for identical assets  (Level 1)		Significant  other observable  inputs  (Level 2)		Significant unobservable inputs  (Level 3)		Total
March 31, 2023
Financial assets
HEI consolidated
Available-for-sale investment securities	$	1,419,755	$	—	$	1,404,989	$	14,766	$	1,419,755
Held-to-maturity investment securities	1,238,185		—		1,158,090		—		1,158,090
Loans, net	5,988,718		—		661		5,605,699		5,606,360
Mortgage servicing rights	8,745		—		—		18,117		18,117
Derivative assets	38,050		9		1,133		—		1,142
Financial liabilities
HEI consolidated
Deposit liabilities	843,415		—		829,709		—		829,709
Short-term borrowings—other than bank	148,802		—		148,802		—		148,802
Other bank borrowings	680,690		—		675,107		—		675,107
Long-term debt, net—other than bank	2,480,948		—		2,296,948		—		2,296,948
Derivative liabilities	250		4		—		—		4
Hawaiian Electric consolidated
Long-term debt, net	1,834,320		—		1,702,247		—		1,702,247
December 31, 2022
Financial assets
HEI consolidated
Available-for-sale investment securities	$	1,429,667	$	—	$	1,414,765	$	14,902	$	1,429,667
Held-to-maturity investment securities	1,251,747		—		1,150,971		—		1,150,971
Loans, net	5,907,514		—		821		5,453,381		5,454,202
Mortgage servicing rights	9,047		—		—		17,646		17,646
Derivative assets	16,220		18		1,330		—		1,348
Financial liabilities
HEI consolidated
Deposit liabilities	611,718		—		597,617		—		597,617
Short-term borrowings—other than bank	172,568		—		172,568		—		172,568
Other bank borrowings	695,120		—		695,095		—		695,095
Long-term debt, net—other than bank	2,384,980		—		2,122,605		—		2,122,605
Derivative liabilities	22,949		—		472		—		472
Hawaiian Electric consolidated
Short-term borrowings	87,967		—		87,967		—		87,967
Long-term debt, net	1,684,816		—		1,487,496		—		1,487,496

Schedule of assets measured at fair value on a recurring basis

Assets and liabilities measured at fair value on a recurring basis were as follows:

	March 31, 2023						December 31, 2022
	Fair value measurements using						Fair value measurements using
(in thousands)	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
Available-for-sale investment securities (bank segment)
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	$	—	$	1,283,935	$	—	$	—	$	1,292,968	$	—
U.S. Treasury and federal agency obligations	—		79,744		—		—		81,063		—
Corporate bonds	—		41,310		—		—		40,734		—
Mortgage revenue bonds	—		—		14,766		—		—		14,902
	$	—	$	1,404,989	$	14,766	$	—	$	1,414,765	$	14,902
Derivative assets
Interest rate lock commitments (bank segment)1	$	—	$	26	$	—	$	—	$	9	$	—
Forward commitments (bank segment)1	9		—		—		18		—		—
Interest rate swap (Other segment)2	—		1,107		—		—		1,321		—
	$	9	$	1,133	$	—	$	18	$	1,330	$	—
Derivative liabilities
Forward commitments (bank segment)1	$	4	$	—	$	—	$	—	$	—	$	—
Interest rate swap (Other segment)2	—		—		—		—		472		—
	$	4	$	—	$	—	$	—	$	472	$	—

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.

Schedule of changes in Level 3 assets and liabilities measured at fair value on a recurring basis

The changes in Level 3 assets and liabilities measured at fair value on a recurring basis were as follows:

	Three months ended March 31
Mortgage revenue bonds	2023		2022
(in thousands)
Beginning balance	$	14,902	$	15,427
Principal payments received	(136)		(131)
Purchases	—		—
Unrealized gain (loss) included in other comprehensive income	—		—
Ending balance	$	14,766	$	15,296

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Segment financial information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Segment financial information
Revenues	$ 928,237	$ 785,068
Income (loss) before income taxes	70,304	87,480
Income taxes (benefit)	15,110	17,840
Net income attributable to Hawaiian Electric	55,194	69,640
Preferred stock dividends of Hawaiian Electric	473	473
Net income for common stock	54,721	69,167
Total assets	16,443,785		$ 16,284,244
Revenues from external customers
Segment financial information
Revenues		785,068
Intersegment revenues (eliminations)
Segment financial information
Revenues		0
Electric utility
Segment financial information
Revenues	830,361	708,792
Income (loss) before income taxes	61,108	59,446
Income taxes (benefit)	13,600	12,538
Net income attributable to Hawaiian Electric	47,508	46,908
Preferred stock dividends of Hawaiian Electric	499	499
Net income for common stock	47,009	46,409
Total assets	6,674,463		6,597,467
Electric utility | Revenues from external customers
Segment financial information
Revenues		708,788
Electric utility | Intersegment revenues (eliminations)
Segment financial information
Revenues		4
Bank
Segment financial information
Revenues	93,857	75,115
Income (loss) before income taxes	23,707	30,215
Income taxes (benefit)	5,145	6,345
Net income attributable to Hawaiian Electric	18,562	23,870
Preferred stock dividends of Hawaiian Electric	0	0
Net income for common stock	18,562	23,870
Total assets	9,610,070		9,545,970
Bank | Revenues from external customers
Segment financial information
Revenues		75,115
Bank | Intersegment revenues (eliminations)
Segment financial information
Revenues		0
Other
Segment financial information
Revenues	4,019	1,161
Income (loss) before income taxes	(14,511)	(2,181)
Income taxes (benefit)	(3,635)	(1,043)
Net income attributable to Hawaiian Electric	(10,876)	(1,138)
Preferred stock dividends of Hawaiian Electric	(26)	(26)
Net income for common stock	(10,850)	(1,112)
Total assets	$ 159,252		$ 140,807
Other | Revenues from external customers
Segment financial information
Revenues		1,165
Other | Intersegment revenues (eliminations)
Segment financial information
Revenues		$ (4)

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Electric utility segment - Unconsolidated variable interest entities (Details)	3 Months Ended
	Mar. 31, 2023 entity agreement
Power purchase agreement
Number of IPPs (in entities) | entity	2
Hawaiian Electric Company
Power purchase agreement
Number of power purchase agreements (PPAs) (in agreements) | agreement	4

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Electric utility segment - Power purchase agreements (Details) $ in Thousands		1 Months Ended				3 Months Ended		12 Months Ended
	Apr. 21, 2023 MWh MW	Oct. 31, 2021	Jul. 31, 2018 MW	Feb. 28, 2018 USD ($) agreement MW	May 31, 2012 MW	Mar. 31, 2023 USD ($) project	Mar. 31, 2022 USD ($)	Dec. 31, 1988 MW	Dec. 31, 2022 USD ($)
Regulatory Projects and Legal Obligations [Line Items]
Finance lease liabilities						$ 88,024			$ 48,709
Kalaeloa
Regulatory Projects and Legal Obligations [Line Items]
Purchase commitment, extension period		10 years
Stage 1 Renewable PPAs
Regulatory Projects and Legal Obligations [Line Items]
Number of power purchase agreements (PPAs) (in agreements) | agreement				8
Minimum power volume required (in megawatts) | MW				274.5
Estimated annual cost				$ 64,500
Long term purchase commitments, number of projects | project						2
Finance lease liabilities						$ 88,000
Financing lease right-of-use assets						88,000
Stage 1 Renewable PPAs | Subsequent Event
Regulatory Projects and Legal Obligations [Line Items]
Generates in minimum volume required (in megawatts) | MW	30
Generates in minimum volume required (in megawatts hour) | MWh	120
Hu Honua Bioenergy, LLC
Regulatory Projects and Legal Obligations [Line Items]
Minimum power volume required (in megawatts) | MW					21.5
Molokai New Energy Partners
Regulatory Projects and Legal Obligations [Line Items]
Total contracted PV capacity (in megawatts) | MW			4.88
Total contracted battery energy storage system capacity | MW			3
Maximum power volume to be delivered (in megawatts) | MW			2.64
Hawaiian Electric, Parent
Regulatory Projects and Legal Obligations [Line Items]
Purchased power						153,000	$ 164,000
Hawaiian Electric, Parent | Kalaeloa
Regulatory Projects and Legal Obligations [Line Items]
Purchased power						67,000	60,000
Increased power purchase commitment capacity (in megawatts) | MW								208
Hawaiian Electric, Parent | AES Hawaii
Regulatory Projects and Legal Obligations [Line Items]
Purchased power						0	27,000
Hawaiian Electric, Parent | HPOWER
Regulatory Projects and Legal Obligations [Line Items]
Purchased power						18,000	19,000
Hawaiian Electric, Parent | Hamakua Energy
Regulatory Projects and Legal Obligations [Line Items]
Purchased power						20,000	16,000
Hawaiian Electric, Parent | Puna Geothermal Venture
Regulatory Projects and Legal Obligations [Line Items]
Purchased power						8,000	10,000
Hawaiian Electric, Parent | Wind IPPs
Regulatory Projects and Legal Obligations [Line Items]
Purchased power						24,000	18,000
Hawaiian Electric, Parent | Solar IPPs
Regulatory Projects and Legal Obligations [Line Items]
Purchased power						14,000	13,000
Hawaiian Electric, Parent | Other IPPs
Regulatory Projects and Legal Obligations [Line Items]
Purchased power						$ 2,000	$ 1,000

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Electric utility segment - Utility projects (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($)	Nov. 30, 2021 USD ($)	Oct. 31, 2020 generationUnit transmission_line kV	Jun. 10, 2019 USD ($)	Oct. 31, 2018 USD ($)
Public Utilities, General Disclosures [Line Items]
Environmental loss contingency, statement of financial position, not disclosed	reserve account balance
Hawaiian Electric Company, Inc. and Subsidiaries | ERP/EAM Implementation Project
Public Utilities, General Disclosures [Line Items]
ERP/EAM project service period (in years)	12 years
ERP/EAM project service, savings over 12 years					$ 246.0
Future O&M expense reductions				$ 150.0
Future cost avoidance related to capital cost and tax costs				$ 96.0
Regulatory liability for O&M expense reductions	$ 11.0
Hawaiian Electric Company, Inc. and Subsidiaries | Waena Switchyard/Synchronous Condenser Project
Public Utilities, General Disclosures [Line Items]
Number of extended transmission lines | transmission_line			2
Number of kilovolts | kV			69
Number of generating units converting to synchronous condensers | generationUnit			2
Renewable energy generation project, approved funds		$ 38.8
Renewable energy generation project, incurred cost	17.1
Hawaiian Electric, Parent | PCB Contamination
Public Utilities, General Disclosures [Line Items]
Valuation allowances and reserves	9.9
Hawaiian Electric, Parent | ERP/EAM Implementation Project
Public Utilities, General Disclosures [Line Items]
Regulatory liability for O&M expense reductions	3.7
Hawaii Electric Light Company, Inc | ERP/EAM Implementation Project
Public Utilities, General Disclosures [Line Items]
Regulatory liability for O&M expense reductions	2.9
Maui Electric
Public Utilities, General Disclosures [Line Items]
Additional accrued investigation and estimated cleanup costs	2.6
Maui Electric | ERP/EAM Implementation Project
Public Utilities, General Disclosures [Line Items]
Regulatory liability for O&M expense reductions	$ 4.4
Regulatory liability, amortization period	5 years

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Electric utility segment - Regulatory proceedings (Details) $ in Thousands				3 Months Ended			4 Months Ended	12 Months Ended
	Feb. 16, 2021 agreement	Dec. 23, 2020 USD ($)	Sep. 15, 2020 agreement	Mar. 31, 2023 USD ($) MWh project contract	Nov. 30, 2021 agreement	Nov. 30, 2021 entity	Mar. 31, 2023 USD ($) contract project agreement	Dec. 31, 2022 USD ($)	Dec. 31, 2019 USD ($) agreement	Feb. 28, 2023 USD ($)	Jun. 30, 2022 USD ($)	Jun. 17, 2022 mechanism	Dec. 31, 2021 USD ($)	Jun. 01, 2021 mechanism	Mar. 23, 2021 mechanism	Dec. 31, 2020 entity	Jul. 09, 2020 agreement
Regulatory Projects and Legal Obligations [Line Items]
PUC proposal period		45 days
Public utilities, modified pilot process proposal period				15 days
Propose pilots annual cap				$ 10,000
Potential total annual maximum reward				$ 2,000			$ 2,000
Advanced metering infrastructure term				3 years
Hawaiian Electric Company, Inc. and Subsidiaries
Regulatory Projects and Legal Obligations [Line Items]
Number of performance incentive mechanisms | mechanism												2		3	2
Number of performance incentive mechanisms, penalty-only | mechanism												1
Multi-year rate period		5 years
Customer dividend, negative adjustment percentage		0.22%
Savings commitment liability, annual rate		$ 6,600
Earnings sharing mechanism, actual return on equity, dead band percentage above or below target				3.00%
Approved return on equity, percentage				9.50%
Percentage sharing between customers and utilities				50
Earnings sharing mechanism, actual earning, above or below dead band				1.50%
Percentage sharing for any further difference				90
MPIR and EPRM requested amount				$ 26,200
EPRM approved projects | contract				2			2
EPRM approved projects, capital costs				$ 41,000
Number of projects | project				6			6
Estimated capital costs				$ 480,000
2022 deferred cost recovery approved										$ 400
Decoupling order, service reliability performance, historical measurement period (in years)				10 years
Maximum penalty, percent of ROE				0.20%
Service reliability, pending adjusted maximum penalty amount				$ 6,800
Service reliability, estimated penalties								$ 100
Dead band percentage above or below the target				3.00%
Call center performance, maximum penalty percentage				0.08%
Call center performance, pending adjusted maximum penalty				$ 1,400
Number of power purchase agreements (PPAs) (in agreements) | agreement	1		1						7
Incentives accrued									$ 1,700				$ 100
Number of grid service purchase agreements | agreement																	2
Number of PPAs approved					2	2
Number of GSPAs approved | entity																2
Number of power purchase agreements terminated | agreement							2
Interpolated RPS rate goal, year one and two (in dollars per MWh) | MWh				20
Interpolated RPS rate goal, year three (in dollars per MWh) | MWh				15
Interpolated RPS rate goal, after year three (in dollars per MWh) | MWh				10
Failure to meet RPS targets, penalty rate (in dollars per MWh) | MWh				20
Potential total annual maximum reward				$ 1,500			$ 1,500
Public utilities, grid services procurement performance incentive mechanism, accrued estimated rewards								40
Potential total annual maximum reward				3,000			3,000
Total annual maximum penalty				900			900
Interconnection approval PIM, accrued estimated rewards								3,000
Performance incentive mechanism, maximum reward				$ 2,000			$ 2,000
Performance incentive mechanism, term				3 years
Performance incentive mechanism, accrued estimated rewards											$ 500
Target performance historical measurement period				10 years
Percent of return on equity				0.03%
Pending adjusted amount				$ 1,000
Target performance period				10 months
Target deadband period				2 months
Accrued earned rewards, net of penalties								3,400
Hawaiian Electric, Parent
Regulatory Projects and Legal Obligations [Line Items]
Public utilities retained percentage				20.00%
Accrued earned rewards, net of penalties								2,500
Hawaii Electric Light Company, Inc
Regulatory Projects and Legal Obligations [Line Items]
Accrued earned rewards, net of penalties								400
Maui Electric
Regulatory Projects and Legal Obligations [Line Items]
Accrued earned rewards, net of penalties								$ 500
Schofield Generation Station | Hawaiian Electric Company, Inc. and Subsidiaries
Regulatory Projects and Legal Obligations [Line Items]
MPIR requested amount				$ 16,500
West Loch PV Project | Hawaiian Electric Company, Inc. and Subsidiaries
Regulatory Projects and Legal Obligations [Line Items]
MPIR requested amount				3,500
Grid Modernization Strategy Phase 1 Project | Hawaiian Electric Company, Inc. and Subsidiaries
Regulatory Projects and Legal Obligations [Line Items]
MPIR requested amount				6,100
Waiawa UFLS Project | Hawaiian Electric Company, Inc. and Subsidiaries
Regulatory Projects and Legal Obligations [Line Items]
EPRM requested amount				$ 100

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Electric utility segment - Annual decoupling filings summary (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($)
Regulatory Projects and Legal Obligations [Line Items]
Incremental Performance Incentive Mechanisms (net)	$ (0.2)
Incremental EPRM/MPIR Revenue Adjustment	4.9
Other	0.5
Net incremental amount to be collected under the RBA rate tariffs	5.1
Hawaiian Electric, Parent
Regulatory Projects and Legal Obligations [Line Items]
Incremental Performance Incentive Mechanisms (net)	(0.4)
Incremental EPRM/MPIR Revenue Adjustment	2.5
Other	0.4
Net incremental amount to be collected under the RBA rate tariffs	2.5
Hawaii Electric Light
Regulatory Projects and Legal Obligations [Line Items]
Incremental Performance Incentive Mechanisms (net)	0.1
Incremental EPRM/MPIR Revenue Adjustment	1.4
Other	0.1
Net incremental amount to be collected under the RBA rate tariffs	1.5
Maui Electric
Regulatory Projects and Legal Obligations [Line Items]
Incremental Performance Incentive Mechanisms (net)	0.1
Incremental EPRM/MPIR Revenue Adjustment	1.0
Other	0.0
Net incremental amount to be collected under the RBA rate tariffs	$ 1.1

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Electric utility segment - Regulatory assets for COVID-19 related costs (Details) - Hawaiian Electric Company, Inc. and Subsidiaries - USD ($) $ in Millions		1 Months Ended	3 Months Ended
	Jun. 09, 2022	Dec. 31, 2021	Mar. 31, 2023
Regulatory Projects and Legal Obligations [Line Items]
Recovery of deferral costs	$ 27.8
Recovery of deferral costs period	3 years
COVID-19
Regulatory Projects and Legal Obligations [Line Items]
Customer bill forgiveness		$ 2.0
Public utilities in regulatory assets			$ 9.6

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Electric utility segment - Army privatization (Details) - Hawaiian Electric Company, Inc. and Subsidiaries $ in Millions	Mar. 01, 2022 USD ($)	Oct. 30, 2020 USD ($) installation
Regulatory Projects and Legal Obligations [Line Items]
Public utilities, electric distribution system, contract period	50 years	50 years
Number of U.S. army installations being serviced | installation		12
Purchase price	$ 14.5
price of acquisition, expected		$ 4.0
Transition period	1 year
Capital upgrade over the period	6 years

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Electric utility segment - Condensed consolidating statement of income (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Condensed Income Statements, Captions [Line Items]
Revenues	$ 928,237	$ 785,068
Expenses
Total expenses	834,719	685,792
Total operating income	93,518	99,276
Allowance for equity funds used during construction	3,301	2,409
Retirement defined benefits credit (expense)—other than service costs	1,152	1,243
Allowance for borrowed funds used during construction	1,131	778
Income before income taxes	70,304	87,480
Income taxes	15,110	17,840
Net income attributable to Hawaiian Electric	55,194	69,640
Preferred stock dividends of Hawaiian Electric	473	473
Net income for common stock	54,721	69,167
Hawaiian Electric Consolidated
Condensed Income Statements, Captions [Line Items]
Revenues	830,361	708,792
Expenses
Fuel oil	334,097	221,286
Purchased power	152,761	163,533
Other operation and maintenance	128,316	125,257
Depreciation	60,927	58,471
Taxes, other than income taxes	78,385	66,650
Total expenses	754,486	635,197
Total operating income	75,875	73,595
Allowance for equity funds used during construction	3,301	2,409
Equity in earnings of subsidiaries	0	0
Retirement defined benefits credit (expense)—other than service costs	1,047	990
Interest expense and other charges, net	(20,246)	(18,326)
Allowance for borrowed funds used during construction	1,131	778
Income before income taxes	61,108	59,446
Income taxes	13,600	12,538
Net income	47,508	46,908
Preferred stock dividends of subsidiaries	229	229
Net income attributable to Hawaiian Electric	47,279	46,679
Preferred stock dividends of Hawaiian Electric	270	270
Net income for common stock	47,009	46,409
Hawaiian Electric Consolidated | Reportable Legal Entities | Hawaiian Electric (parent only)
Condensed Income Statements, Captions [Line Items]
Revenues	601,530	500,242
Expenses
Fuel oil	253,827	154,425
Purchased power	110,279	124,183
Other operation and maintenance	83,233	83,656
Depreciation	41,038	39,484
Taxes, other than income taxes	56,953	47,274
Total expenses	545,330	449,022
Total operating income	56,200	51,220
Allowance for equity funds used during construction	2,640	1,990
Equity in earnings of subsidiaries	11,541	13,661
Retirement defined benefits credit (expense)—other than service costs	904	855
Interest expense and other charges, net	(14,557)	(13,093)
Allowance for borrowed funds used during construction	918	651
Income before income taxes	57,646	55,284
Income taxes	10,367	8,605
Net income	47,279	46,679
Preferred stock dividends of subsidiaries	0	0
Net income attributable to Hawaiian Electric	47,279	46,679
Preferred stock dividends of Hawaiian Electric	270	270
Net income for common stock	47,009	46,409
Hawaiian Electric Consolidated | Reportable Legal Entities | Hawaii Electric Light
Condensed Income Statements, Captions [Line Items]
Revenues	115,288	108,528
Expenses
Fuel oil	27,760	25,251
Purchased power	34,086	30,712
Other operation and maintenance	21,350	20,214
Depreciation	10,635	10,351
Taxes, other than income taxes	10,737	10,032
Total expenses	104,568	96,560
Total operating income	10,720	11,968
Allowance for equity funds used during construction	284	193
Equity in earnings of subsidiaries	0	0
Retirement defined benefits credit (expense)—other than service costs	169	167
Interest expense and other charges, net	(2,831)	(2,609)
Allowance for borrowed funds used during construction	91	60
Income before income taxes	8,433	9,779
Income taxes	1,909	2,268
Net income	6,524	7,511
Preferred stock dividends of subsidiaries	134	134
Net income attributable to Hawaiian Electric	6,390	7,377
Preferred stock dividends of Hawaiian Electric	0	0
Net income for common stock	6,390	7,377
Hawaiian Electric Consolidated | Reportable Legal Entities | Maui Electric
Condensed Income Statements, Captions [Line Items]
Revenues	113,673	100,028
Expenses
Fuel oil	52,510	41,610
Purchased power	8,396	8,638
Other operation and maintenance	23,733	21,387
Depreciation	9,254	8,636
Taxes, other than income taxes	10,695	9,344
Total expenses	104,588	89,615
Total operating income	9,085	10,413
Allowance for equity funds used during construction	377	226
Equity in earnings of subsidiaries	0	0
Retirement defined benefits credit (expense)—other than service costs	(26)	(32)
Interest expense and other charges, net	(2,988)	(2,630)
Allowance for borrowed funds used during construction	122	67
Income before income taxes	6,570	8,044
Income taxes	1,324	1,665
Net income	5,246	6,379
Preferred stock dividends of subsidiaries	95	95
Net income attributable to Hawaiian Electric	5,151	6,284
Preferred stock dividends of Hawaiian Electric	0	0
Net income for common stock	5,151	6,284
Hawaiian Electric Consolidated | Reportable Legal Entities | Other subsidiaries
Condensed Income Statements, Captions [Line Items]
Revenues	0	0
Expenses
Fuel oil	0	0
Purchased power	0	0
Other operation and maintenance	0	0
Depreciation	0	0
Taxes, other than income taxes	0	0
Total expenses	0	0
Total operating income	0	0
Allowance for equity funds used during construction	0	0
Equity in earnings of subsidiaries	0	0
Retirement defined benefits credit (expense)—other than service costs	0	0
Interest expense and other charges, net	0	0
Allowance for borrowed funds used during construction	0	0
Income before income taxes	0	0
Income taxes	0	0
Net income	0	0
Preferred stock dividends of subsidiaries	0	0
Net income attributable to Hawaiian Electric	0	0
Preferred stock dividends of Hawaiian Electric	0	0
Net income for common stock	0	0
Hawaiian Electric Consolidated | Consolidating adjustments
Condensed Income Statements, Captions [Line Items]
Revenues	(130)	(6)
Expenses
Fuel oil	0	0
Purchased power	0	0
Other operation and maintenance	0	0
Depreciation	0	0
Taxes, other than income taxes	0	0
Total expenses	0	0
Total operating income	(130)	(6)
Allowance for equity funds used during construction	0	0
Equity in earnings of subsidiaries	(11,541)	(13,661)
Retirement defined benefits credit (expense)—other than service costs	0	0
Interest expense and other charges, net	130	6
Allowance for borrowed funds used during construction	0	0
Income before income taxes	(11,541)	(13,661)
Income taxes	0	0
Net income	(11,541)	(13,661)
Preferred stock dividends of subsidiaries	0	0
Net income attributable to Hawaiian Electric	(11,541)	(13,661)
Preferred stock dividends of Hawaiian Electric	0	0
Net income for common stock	$ (11,541)	$ (13,661)

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Electric utility segment - Condensed consolidating statement of comprehensive income (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Condensed Statement of Income Captions [Line Items]
Net income for common stock	$ 54,721	$ 69,167
Retirement benefit plans:
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes	(357)	4,501
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	425	(4,325)
Other comprehensive income (loss), net of taxes	20,488	(117,159)
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	75,209	(47,992)
Hawaiian Electric Consolidated
Condensed Statement of Income Captions [Line Items]
Net income for common stock	47,009	46,409
Retirement benefit plans:
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes	(470)	4,376
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	425	(4,325)
Other comprehensive income (loss), net of taxes	(45)	51
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	46,964	46,460
Hawaiian Electric Consolidated | Reportable Legal Entities | Hawaiian Electric (parent only)
Condensed Statement of Income Captions [Line Items]
Net income for common stock	47,009	46,409
Retirement benefit plans:
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes	(470)	4,376
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	425	(4,325)
Other comprehensive income (loss), net of taxes	(45)	51
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	46,964	46,460
Hawaiian Electric Consolidated | Reportable Legal Entities | Hawaii Electric Light
Condensed Statement of Income Captions [Line Items]
Net income for common stock	6,390	7,377
Retirement benefit plans:
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes	(56)	670
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	50	(670)
Other comprehensive income (loss), net of taxes	(6)	0
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	6,384	7,377
Hawaiian Electric Consolidated | Reportable Legal Entities | Maui Electric
Condensed Statement of Income Captions [Line Items]
Net income for common stock	5,151	6,284
Retirement benefit plans:
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes	(63)	603
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	57	(603)
Other comprehensive income (loss), net of taxes	(6)	0
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	5,145	6,284
Hawaiian Electric Consolidated | Reportable Legal Entities | Other subsidiaries
Condensed Statement of Income Captions [Line Items]
Net income for common stock	0	0
Retirement benefit plans:
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes	0	0
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	0	0
Other comprehensive income (loss), net of taxes	0	0
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	0	0
Hawaiian Electric Consolidated | Consolidating adjustments
Condensed Statement of Income Captions [Line Items]
Net income for common stock	(11,541)	(13,661)
Retirement benefit plans:
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes	119	(1,273)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	(107)	1,273
Other comprehensive income (loss), net of taxes	12	0
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	$ (11,529)	$ (13,661)

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Electric utility segment - Condensed consolidating balance sheet (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022	Mar. 31, 2022	Dec. 31, 2021
Utility property, plant and equipment
Total property, plant and equipment, net	$ 5,778,571	$ 5,687,003
Current assets
Cash and cash equivalents	315,334	199,877	$ 301,704
Other long-term assets
Operating lease right-of-use assets	110,920	115,684
Total assets	16,443,785	16,284,244
Capitalization
Common stock equity	2,237,955	2,202,499	2,303,642	$ 2,390,884
Preferred stock of subsidiaries - not subject to mandatory redemption	34,293	34,293
Current liabilities
Interest and preferred dividends payable	41,382	21,333
Deferred credits and other liabilities
Deferred income taxes	273,081	262,462
Total liabilities and shareholders’ equity	16,443,785	16,284,244
Hawaiian Electric Consolidated
Utility property, plant and equipment
Land	52,060	52,060
Plant and equipment	8,042,892	7,979,510
Finance lease right-of-use assets	88,297	48,371
Less accumulated depreciation	(3,133,811)	(3,086,499)
Construction in progress	315,862	275,353
Utility property, plant and equipment, net	5,365,300	5,268,795
Nonutility property, plant and equipment, less accumulated depreciation	6,945	6,945
Total property, plant and equipment, net	5,372,245	5,275,740
Investment in wholly owned subsidiaries, at equity	0	0
Current assets
Cash and cash equivalents	116,022	39,242	29,055
Advances to affiliates		0
Customer accounts receivable, net	235,305	288,338
Accrued unbilled revenues, net	160,532	183,280
Other accounts receivable, net	11,427	13,567
Fuel oil stock, at average cost	157,583	191,530
Materials and supplies, at average cost	84,093	79,568
Prepayments and other	43,909	33,482
Regulatory assets	64,973	52,273
Total current assets	873,844	881,280
Other long-term assets
Operating lease right-of-use assets	84,930	89,318
Regulatory assets	182,929	190,240
Other	160,515	160,889
Total other long-term assets	428,374	440,447
Total assets	6,674,463	6,597,467
Capitalization
Common stock equity	2,358,884	2,344,170	2,276,884	2,261,899
Preferred stock of subsidiaries - not subject to mandatory redemption	34,293	34,293
Long-term debt, net	1,734,347	1,584,854
Total capitalization	4,127,524	3,963,317
Current liabilities
Current portion of operating lease liabilities	18,414	19,095
Current portion of long-term debt	99,973	99,962
Short-term borrowings from affiliate		0
Accounts payable	191,769	202,492
Interest and preferred dividends payable	29,367	17,176
Taxes accrued, including revenue taxes	246,914	289,902
Regulatory liabilities	25,234	31,475
Other	86,580	85,596
Total current liabilities	698,251	833,665
Deferred credits and other liabilities
Operating lease liabilities	74,633	78,715
Finance lease liabilities	84,341	46,048
Deferred income taxes	384,953	384,430
Regulatory liabilities	1,044,317	1,024,175
Unamortized tax credits	93,445	95,300
Defined benefit pension and other postretirement benefit plans liability	49,388	49,748
Other	117,611	122,069
Total deferred credits and other liabilities	1,848,688	1,800,485
Total liabilities and shareholders’ equity	6,674,463	6,597,467
Hawaiian Electric Consolidated | Reportable Legal Entities | Hawaiian Electric (parent only)
Utility property, plant and equipment
Land	42,860	42,860
Plant and equipment	5,302,293	5,260,685
Finance lease right-of-use assets	88,297	48,371
Less accumulated depreciation	(1,889,007)	(1,855,150)
Construction in progress	248,788	215,560
Utility property, plant and equipment, net	3,793,231	3,712,326
Nonutility property, plant and equipment, less accumulated depreciation	5,298	5,298
Total property, plant and equipment, net	3,798,529	3,717,624
Investment in wholly owned subsidiaries, at equity	705,212	701,833
Current assets
Cash and cash equivalents	49,393	27,579	19,894
Advances to affiliates		0
Customer accounts receivable, net	172,426	216,802
Accrued unbilled revenues, net	118,035	136,508
Other accounts receivable, net	22,376	23,746
Fuel oil stock, at average cost	116,295	153,342
Materials and supplies, at average cost	50,744	48,130
Prepayments and other	33,369	24,040
Regulatory assets	58,943	46,504
Total current assets	621,581	676,651
Other long-term assets
Operating lease right-of-use assets	40,724	42,752
Regulatory assets	151,684	154,040
Other	113,888	115,028
Total other long-term assets	306,296	311,820
Total assets	5,431,618	5,407,928
Capitalization
Common stock equity	2,358,884	2,344,170	2,276,884	2,261,899
Preferred stock of subsidiaries - not subject to mandatory redemption	22,293	22,293
Long-term debt, net	1,226,587	1,126,915
Total capitalization	3,607,764	3,493,378
Current liabilities
Current portion of operating lease liabilities	8,955	9,775
Current portion of long-term debt	49,987	49,981
Short-term borrowings from affiliate		26,200
Accounts payable	146,125	143,253
Interest and preferred dividends payable	20,788	12,398
Taxes accrued, including revenue taxes	178,418	207,798
Regulatory liabilities	9,505	13,145
Other	61,360	64,659
Total current liabilities	475,138	615,176
Deferred credits and other liabilities
Operating lease liabilities	39,387	41,049
Finance lease liabilities	84,341	46,048
Deferred income taxes	271,588	271,234
Regulatory liabilities	745,894	729,683
Unamortized tax credits	68,123	69,614
Defined benefit pension and other postretirement benefit plans liability	65,917	65,907
Other	73,466	75,839
Total deferred credits and other liabilities	1,348,716	1,299,374
Total liabilities and shareholders’ equity	5,431,618	5,407,928
Hawaiian Electric Consolidated | Reportable Legal Entities | Hawaii Electric Light
Utility property, plant and equipment
Land	5,606	5,606
Plant and equipment	1,431,852	1,425,442
Finance lease right-of-use assets	0	0
Less accumulated depreciation	(651,463)	(644,457)
Construction in progress	28,136	23,989
Utility property, plant and equipment, net	814,131	810,580
Nonutility property, plant and equipment, less accumulated depreciation	115	115
Total property, plant and equipment, net	814,246	810,695
Investment in wholly owned subsidiaries, at equity	0	0
Current assets
Cash and cash equivalents	28,006	5,092	6,017
Advances to affiliates		4,500
Customer accounts receivable, net	34,224	39,339
Accrued unbilled revenues, net	21,831	23,839
Other accounts receivable, net	3,883	5,519
Fuel oil stock, at average cost	16,678	16,964
Materials and supplies, at average cost	10,578	9,783
Prepayments and other	5,025	6,346
Regulatory assets	2,575	2,435
Total current assets	122,800	113,817
Other long-term assets
Operating lease right-of-use assets	32,599	34,283
Regulatory assets	19,041	21,816
Other	32,786	32,654
Total other long-term assets	84,426	88,753
Total assets	1,021,472	1,013,265
Capitalization
Common stock equity	346,629	344,720	336,177	332,900
Preferred stock of subsidiaries - not subject to mandatory redemption	7,000	7,000
Long-term debt, net	249,346	224,439
Total capitalization	602,975	576,159
Current liabilities
Current portion of operating lease liabilities	6,780	6,690
Current portion of long-term debt	19,994	19,992
Short-term borrowings from affiliate		0
Accounts payable	20,957	32,113
Interest and preferred dividends payable	3,839	2,576
Taxes accrued, including revenue taxes	34,570	42,436
Regulatory liabilities	7,918	8,553
Other	21,072	20,856
Total current liabilities	115,130	133,216
Deferred credits and other liabilities
Operating lease liabilities	26,087	27,817
Finance lease liabilities	0	0
Deferred income taxes	50,657	50,615
Regulatory liabilities	195,238	194,222
Unamortized tax credits	12,903	13,150
Defined benefit pension and other postretirement benefit plans liability	0	129
Other	18,482	17,957
Total deferred credits and other liabilities	303,367	303,890
Total liabilities and shareholders’ equity	1,021,472	1,013,265
Hawaiian Electric Consolidated | Reportable Legal Entities | Maui Electric
Utility property, plant and equipment
Land	3,594	3,594
Plant and equipment	1,308,747	1,293,383
Finance lease right-of-use assets	0	0
Less accumulated depreciation	(593,341)	(586,892)
Construction in progress	38,938	35,804
Utility property, plant and equipment, net	757,938	745,889
Nonutility property, plant and equipment, less accumulated depreciation	1,532	1,532
Total property, plant and equipment, net	759,470	747,421
Investment in wholly owned subsidiaries, at equity	0	0
Current assets
Cash and cash equivalents	38,546	6,494	3,067
Advances to affiliates		21,700
Customer accounts receivable, net	28,655	32,197
Accrued unbilled revenues, net	20,666	22,933
Other accounts receivable, net	4,677	6,686
Fuel oil stock, at average cost	24,610	21,224
Materials and supplies, at average cost	22,771	21,655
Prepayments and other	5,515	4,137
Regulatory assets	3,455	3,334
Total current assets	148,895	140,360
Other long-term assets
Operating lease right-of-use assets	11,607	12,283
Regulatory assets	12,204	14,384
Other	30,402	29,495
Total other long-term assets	54,213	56,162
Total assets	962,578	943,943
Capitalization
Common stock equity	358,506	357,036	345,744	343,260
Preferred stock of subsidiaries - not subject to mandatory redemption	5,000	5,000
Long-term debt, net	258,414	233,500
Total capitalization	621,920	595,536
Current liabilities
Current portion of operating lease liabilities	2,679	2,630
Current portion of long-term debt	29,992	29,989
Short-term borrowings from affiliate		0
Accounts payable	24,687	27,126
Interest and preferred dividends payable	4,740	2,282
Taxes accrued, including revenue taxes	33,926	40,709
Regulatory liabilities	7,811	9,777
Other	23,657	22,385
Total current liabilities	127,492	134,898
Deferred credits and other liabilities
Operating lease liabilities	9,159	9,849
Finance lease liabilities	0	0
Deferred income taxes	62,708	62,581
Regulatory liabilities	103,185	100,270
Unamortized tax credits	12,419	12,536
Defined benefit pension and other postretirement benefit plans liability	0	0
Other	25,695	28,273
Total deferred credits and other liabilities	213,166	213,509
Total liabilities and shareholders’ equity	962,578	943,943
Hawaiian Electric Consolidated | Reportable Legal Entities | Other subsidiaries
Utility property, plant and equipment
Land	0	0
Plant and equipment	0	0
Finance lease right-of-use assets	0	0
Less accumulated depreciation	0	0
Construction in progress	0	0
Utility property, plant and equipment, net	0	0
Nonutility property, plant and equipment, less accumulated depreciation	0	0
Total property, plant and equipment, net	0	0
Investment in wholly owned subsidiaries, at equity	0	0
Current assets
Cash and cash equivalents	77	77	77
Advances to affiliates		0
Customer accounts receivable, net	0	0
Accrued unbilled revenues, net	0	0
Other accounts receivable, net	0	0
Fuel oil stock, at average cost	0	0
Materials and supplies, at average cost	0	0
Prepayments and other	0	0
Regulatory assets	0	0
Total current assets	77	77
Other long-term assets
Operating lease right-of-use assets	0	0
Regulatory assets	0	0
Other	0	0
Total other long-term assets	0	0
Total assets	77	77
Capitalization
Common stock equity	77	77	77	77
Preferred stock of subsidiaries - not subject to mandatory redemption	0	0
Long-term debt, net	0	0
Total capitalization	77	77
Current liabilities
Current portion of operating lease liabilities	0	0
Current portion of long-term debt	0	0
Short-term borrowings from affiliate		0
Accounts payable	0	0
Interest and preferred dividends payable	0	0
Taxes accrued, including revenue taxes	0	0
Regulatory liabilities	0	0
Other	0	0
Total current liabilities	0	0
Deferred credits and other liabilities
Operating lease liabilities	0	0
Finance lease liabilities	0	0
Deferred income taxes	0	0
Regulatory liabilities	0	0
Unamortized tax credits	0	0
Defined benefit pension and other postretirement benefit plans liability	0	0
Other	0
Total deferred credits and other liabilities	0	0
Total liabilities and shareholders’ equity	77	77
Hawaiian Electric Consolidated | Consolidating adjustments
Utility property, plant and equipment
Land	0	0
Plant and equipment	0	0
Finance lease right-of-use assets	0	0
Less accumulated depreciation	0	0
Construction in progress	0	0
Utility property, plant and equipment, net	0	0
Nonutility property, plant and equipment, less accumulated depreciation	0	0
Total property, plant and equipment, net	0	0
Investment in wholly owned subsidiaries, at equity	(705,212)	(701,833)
Current assets
Cash and cash equivalents	0	0	0
Advances to affiliates		(26,200)
Customer accounts receivable, net	0	0
Accrued unbilled revenues, net	0	0
Other accounts receivable, net	(19,509)	(22,384)
Fuel oil stock, at average cost	0	0
Materials and supplies, at average cost	0	0
Prepayments and other	0	(1,041)
Regulatory assets	0	0
Total current assets	(19,509)	(49,625)
Other long-term assets
Operating lease right-of-use assets	0	0
Regulatory assets	0	0
Other	(16,561)	(16,288)
Total other long-term assets	(16,561)	(16,288)
Total assets	(741,282)	(767,746)
Capitalization
Common stock equity	(705,212)	(701,833)	$ (681,998)	$ (676,237)
Preferred stock of subsidiaries - not subject to mandatory redemption	0	0
Long-term debt, net	0	0
Total capitalization	(705,212)	(701,833)
Current liabilities
Current portion of operating lease liabilities	0	0
Current portion of long-term debt	0	0
Short-term borrowings from affiliate		(26,200)
Accounts payable	0	0
Interest and preferred dividends payable	0	(80)
Taxes accrued, including revenue taxes	0	(1,041)
Regulatory liabilities	0	0
Other	(19,509)	(22,304)
Total current liabilities	(19,509)	(49,625)
Deferred credits and other liabilities
Operating lease liabilities	0	0
Finance lease liabilities	0	0
Deferred income taxes	0	0
Regulatory liabilities	0	0
Unamortized tax credits	0	0
Defined benefit pension and other postretirement benefit plans liability	(16,529)	(16,288)
Other	(32)	0
Total deferred credits and other liabilities	(16,561)	(16,288)
Total liabilities and shareholders’ equity	$ (741,282)	$ (767,746)

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Electric utility segment - Condensed consolidating statement of changes in common stock equity (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Increase (decrease) in stockholders' equity
Beginning balance	$ 2,202,499	$ 2,390,884
Net income for common stock	54,721	69,167
Other comprehensive loss, net of taxes	20,488	(117,159)
Common stock dividends	(39,446)	(38,301)
Ending balance	2,237,955	2,303,642
Hawaiian Electric Consolidated
Increase (decrease) in stockholders' equity
Beginning balance	2,344,170	2,261,899
Net income for common stock	47,009	46,409
Other comprehensive loss, net of taxes	(45)	51
Common stock dividends	(32,250)	(31,475)
Ending balance	2,358,884	2,276,884
Hawaiian Electric Consolidated | Reportable Legal Entities | Hawaiian Electric (parent only)
Increase (decrease) in stockholders' equity
Beginning balance	2,344,170	2,261,899
Net income for common stock	47,009	46,409
Other comprehensive loss, net of taxes	(45)	51
Common stock dividends	(32,250)	(31,475)
Ending balance	2,358,884	2,276,884
Hawaiian Electric Consolidated | Reportable Legal Entities | Hawaii Electric Light
Increase (decrease) in stockholders' equity
Beginning balance	344,720	332,900
Net income for common stock	6,390	7,377
Other comprehensive loss, net of taxes	(6)	0
Common stock dividends	(4,475)	(4,100)
Ending balance	346,629	336,177
Hawaiian Electric Consolidated | Reportable Legal Entities | Maui Electric
Increase (decrease) in stockholders' equity
Beginning balance	357,036	343,260
Net income for common stock	5,151	6,284
Other comprehensive loss, net of taxes	(6)	0
Common stock dividends	(3,675)	(3,800)
Ending balance	358,506	345,744
Hawaiian Electric Consolidated | Reportable Legal Entities | Other subsidiaries
Increase (decrease) in stockholders' equity
Beginning balance	77	77
Net income for common stock	0	0
Other comprehensive loss, net of taxes	0	0
Ending balance	77	77
Hawaiian Electric Consolidated | Consolidating adjustments
Increase (decrease) in stockholders' equity
Beginning balance	(701,833)	(676,237)
Net income for common stock	(11,541)	(13,661)
Other comprehensive loss, net of taxes	12	0
Common stock dividends	8,150	7,900
Ending balance	$ (705,212)	$ (681,998)

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Electric utility segment - Condensed consolidating statement of cash flows (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Cash flows from operating activities
Net cash provided by operating activities	$ 180,952	$ 92,585
Cash flows from investing activities
Capital expenditures	(124,297)	(79,163)
Other	2,148	5,340
Net cash used in investing activities	(137,468)	(227,714)
Cash flows from financing activities
Common stock dividends	(39,446)	(38,301)
Proceeds from issuance of long-term debt	150,000	7,312
Net increase (decrease) in short-term borrowings with original maturities of three months or less	(88,666)	17,493
Other	(5,535)	(4,377)
Net cash provided by financing activities	71,139	131,283
Net increase (decrease) in cash, cash equivalents and restricted cash	114,623	(3,846)
Cash, cash equivalents and restricted cash, beginning of period	204,927	311,462
Cash, cash equivalents and restricted cash, end of period	319,550	307,616
Less: Restricted cash	(4,216)	(5,912)	$ (5,050)
Cash and cash equivalents	315,334	301,704	199,877
Hawaiian Electric Consolidated
Cash flows from operating activities
Net cash provided by operating activities	169,355	76,775
Cash flows from investing activities
Capital expenditures	(122,139)	(76,358)
Advances to affiliates	0	0
Other	1,545	1,494
Net cash used in investing activities	(120,594)	(74,864)
Cash flows from financing activities
Common stock dividends	(32,250)	(31,475)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(499)	(499)
Proceeds from issuance of long-term debt	150,000	0
Net increase (decrease) in short-term borrowings with original maturities of three months or less	(87,967)	6,000
Payments of obligations under finance leases	(575)	0
Other	(690)	0
Net cash provided by financing activities	28,019	(25,974)
Net increase (decrease) in cash, cash equivalents and restricted cash	76,780	(24,063)
Cash, cash equivalents and restricted cash, beginning of period	39,242	55,258
Cash, cash equivalents and restricted cash, end of period	116,022	31,195
Less: Restricted cash	0	(2,140)
Cash and cash equivalents	116,022	29,055	39,242
Hawaiian Electric Consolidated | Reportable Legal Entities | Hawaiian Electric (parent only)
Cash flows from operating activities
Net cash provided by operating activities	143,356	55,669
Cash flows from investing activities
Capital expenditures	(74,916)	(44,084)
Advances to affiliates	0	(4,000)
Other	1,094	961
Net cash used in investing activities	(73,822)	(47,123)
Cash flows from financing activities
Common stock dividends	(32,250)	(31,475)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(270)	(270)
Proceeds from issuance of long-term debt	100,000
Net increase (decrease) in short-term borrowings with original maturities of three months or less	(114,167)	18,800
Payments of obligations under finance leases	(575)
Other	(458)
Net cash provided by financing activities	(47,720)	(12,945)
Net increase (decrease) in cash, cash equivalents and restricted cash	21,814	(4,399)
Cash, cash equivalents and restricted cash, beginning of period	27,579	26,433
Cash, cash equivalents and restricted cash, end of period	49,393	22,034
Less: Restricted cash		(2,140)
Cash and cash equivalents	49,393	19,894	27,579
Hawaiian Electric Consolidated | Reportable Legal Entities | Hawaii Electric Light
Cash flows from operating activities
Net cash provided by operating activities	18,733	15,778
Cash flows from investing activities
Capital expenditures	(20,747)	(15,133)
Advances to affiliates	4,500	0
Other	153	280
Net cash used in investing activities	(16,094)	(14,853)
Cash flows from financing activities
Common stock dividends	(4,475)	(4,100)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(134)	(134)
Proceeds from issuance of long-term debt	25,000
Net increase (decrease) in short-term borrowings with original maturities of three months or less	0	4,000
Payments of obligations under finance leases	0
Other	(116)
Net cash provided by financing activities	20,275	(234)
Net increase (decrease) in cash, cash equivalents and restricted cash	22,914	691
Cash, cash equivalents and restricted cash, beginning of period	5,092	5,326
Cash, cash equivalents and restricted cash, end of period	28,006	6,017
Less: Restricted cash		0
Cash and cash equivalents	28,006	6,017	5,092
Hawaiian Electric Consolidated | Reportable Legal Entities | Maui Electric
Cash flows from operating activities
Net cash provided by operating activities	15,416	13,228
Cash flows from investing activities
Capital expenditures	(26,476)	(17,141)
Advances to affiliates	21,700	(12,800)
Other	298	253
Net cash used in investing activities	(4,478)	(29,688)
Cash flows from financing activities
Common stock dividends	(3,675)	(3,800)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(95)	(95)
Proceeds from issuance of long-term debt	25,000
Net increase (decrease) in short-term borrowings with original maturities of three months or less	0	0
Payments of obligations under finance leases	0
Other	(116)
Net cash provided by financing activities	21,114	(3,895)
Net increase (decrease) in cash, cash equivalents and restricted cash	32,052	(20,355)
Cash, cash equivalents and restricted cash, beginning of period	6,494	23,422
Cash, cash equivalents and restricted cash, end of period	38,546	3,067
Less: Restricted cash		0
Cash and cash equivalents	38,546	3,067	6,494
Hawaiian Electric Consolidated | Reportable Legal Entities | Other subsidiaries
Cash flows from operating activities
Net cash provided by operating activities	0	0
Cash flows from investing activities
Capital expenditures	0	0
Advances to affiliates	0	0
Other	0	0
Net cash used in investing activities	0	0
Cash flows from financing activities
Common stock dividends	0	0
Preferred stock dividends of Hawaiian Electric and subsidiaries	0	0
Proceeds from issuance of long-term debt	0
Net increase (decrease) in short-term borrowings with original maturities of three months or less	0	0
Payments of obligations under finance leases	0
Other	0
Net cash provided by financing activities	0	0
Net increase (decrease) in cash, cash equivalents and restricted cash	0	0
Cash, cash equivalents and restricted cash, beginning of period	77	77
Cash, cash equivalents and restricted cash, end of period	77	77
Less: Restricted cash		0
Cash and cash equivalents	77	77	77
Hawaiian Electric Consolidated | Consolidating adjustments
Cash flows from operating activities
Net cash provided by operating activities	(8,150)	(7,900)
Cash flows from investing activities
Capital expenditures	0	0
Advances to affiliates	(26,200)	16,800
Other	0	0
Net cash used in investing activities	(26,200)	16,800
Cash flows from financing activities
Common stock dividends	8,150	7,900
Preferred stock dividends of Hawaiian Electric and subsidiaries	0	0
Proceeds from issuance of long-term debt	0
Net increase (decrease) in short-term borrowings with original maturities of three months or less	26,200	(16,800)
Payments of obligations under finance leases	0
Other	0
Net cash provided by financing activities	34,350	(8,900)
Net increase (decrease) in cash, cash equivalents and restricted cash	0	0
Cash, cash equivalents and restricted cash, beginning of period	0	0
Cash, cash equivalents and restricted cash, end of period	0	0
Less: Restricted cash		0
Cash and cash equivalents	$ 0	$ 0	$ 0

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Bank segment - Income statement data (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Noninterest income
Noninterest income	$ 822,384	$ 700,831
Noninterest expense
Income before income taxes	70,304	87,480
Income taxes	15,110	17,840
Net income attributable to Hawaiian Electric	55,194	69,640
Other comprehensive (loss) income, net of tax benefits	20,488	(117,159)
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	75,209	(47,992)
American Savings Bank (ASB)
Interest and dividend income
Interest and fees on loans	64,842	46,005
Interest and dividends on investment securities	14,637	13,984
Total interest and dividend income	79,479	59,989
Interest expense
Interest on deposit liabilities	6,837	947
Interest on other borrowings	7,721	5
Total interest expense	14,558	952
Net interest income	64,921	59,037
Provision for credit losses	1,175	(3,263)
Net interest income after provision for credit losses	63,746	62,300
Noninterest income
Gain on sale of real estate	0	1,002
Total noninterest income	14,378	16,128
Noninterest expense
Compensation and employee benefits	30,204	27,215
Occupancy	5,588	5,952
Data processing	5,012	4,151
Services	2,595	2,439
Equipment	2,646	2,329
Office supplies, printing and postage	1,165	1,060
Marketing	1,016	1,018
Other expense	6,191	4,049
Total noninterest expense	54,417	48,213
Income before income taxes	23,707	30,215
Income taxes	5,145	6,345
Net income attributable to Hawaiian Electric	18,562	23,870
Other comprehensive (loss) income, net of tax benefits	18,430	(122,441)
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.	36,992	(98,571)
American Savings Bank (ASB) | Fees from other financial services
Noninterest income
Noninterest income	4,679	5,587
American Savings Bank (ASB) | Fee income on deposit liabilities
Noninterest income
Noninterest income	4,599	4,691
American Savings Bank (ASB) | Fee income on other financial products
Noninterest income
Noninterest income	2,744	2,718
American Savings Bank (ASB) | Bank-owned life insurance
Noninterest income
Noninterest income	1,425	681
American Savings Bank (ASB) | Mortgage banking income
Noninterest income
Noninterest income	130	1,077
American Savings Bank (ASB) | Other income, net
Noninterest income
Noninterest income	$ 801	$ 372

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Bank segment - Reconciliation of income (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Condensed Income Statements, Captions [Line Items]
Revenues	$ 928,237	$ 785,068
Less: Retirement defined benefits credit—other than service costs	(1,152)	(1,243)
Total expenses	834,719	685,792
Operating income - bank	93,518	99,276
Income before income taxes	70,304	87,480
American Savings Bank (ASB)
Condensed Income Statements, Captions [Line Items]
Interest and dividend income	79,479	59,989
Noninterest income	14,378	16,128
Less: Gain on sale of real estate	0	1,002
Revenues	93,857	75,115
Total interest expense	14,558	952
Provision for credit losses	1,175	(3,263)
Noninterest expense	54,417	48,213
Less: Retirement defined benefits credit—other than service costs	(187)	(185)
Total expenses	70,337	45,085
Operating income - bank	23,520	30,030
Income before income taxes	$ 23,707	$ 30,215

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Bank segment - Balance sheet data (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022	Mar. 31, 2022	Dec. 31, 2021
Assets
Cash and cash equivalents	$ 315,334	$ 199,877	$ 301,704
Investment securities
Available-for-sale investment securities, at fair value	1,419,755	1,429,667
Held-to-maturity, at amortized cost (fair value of $1,158,090 and $1,150,971, respectively)	1,238,185	1,251,747
Held-to-maturity investment securities	1,158,090
Stock in Federal Home Loan Bank, at cost	10,000	26,560
Allowance for credit losses	(71,296)	(72,216)	(67,211)	$ (71,130)
Total loans, net	5,988,058	5,906,690
Loans held for sale, at lower of cost or fair value	660	824
Other assets	812,836	824,536
Goodwill	82,190	82,190
Total assets	16,443,785	16,284,244
Liabilities and shareholder’s equity
Other	727,919	787,057
Total liabilities	14,171,537	14,047,452
Retained earnings	861,105	845,830
Accumulated other comprehensive loss, net of tax benefits
Accumulated other comprehensive loss, net of tax benefits	(315,540)	(336,028)
Total shareholders’ equity	2,237,955	2,202,499	$ 2,303,642	$ 2,390,884
Total liabilities and shareholders’ equity	16,443,785	16,284,244
Other assets
Premises and equipment, net	5,778,571	5,687,003
Other assets	812,836	824,536
Other liabilities
Other liabilities	727,919	787,057
American Savings Bank (ASB)
Assets
Cash and due from banks	138,742	153,042
Interest-bearing deposits	44,315	3,107
Cash and cash equivalents	183,057	156,149
Investment securities
Available-for-sale investment securities, at fair value	1,419,755	1,429,667
Held-to-maturity, at amortized cost (fair value of $1,158,090 and $1,150,971, respectively)	1,238,185	1,251,747
Held-to-maturity investment securities	1,158,090	1,150,971
Stock in Federal Home Loan Bank, at cost	10,000	26,560
Loans held for investment	6,059,354	5,978,906
Allowance for credit losses	(71,296)	(72,216)
Total loans, net	5,988,058	5,906,690
Loans held for sale, at lower of cost or fair value	660	824
Other assets	688,165	692,143
Goodwill	82,190	82,190
Total assets	9,610,070	9,545,970
Liabilities and shareholder’s equity
Deposit liabilities—noninterest-bearing	2,769,789	2,811,077
Deposit liabilities—interest-bearing	5,460,812	5,358,619
Other borrowings	680,690	695,120
Other	206,317	212,269
Total liabilities	9,117,608	9,077,085
Common stock	1	1
Additional paid-in capital	356,391	355,806
Retained earnings	454,255	449,693
Accumulated other comprehensive loss, net of tax benefits
Net unrealized losses on securities	(308,622)	(328,904)
Retirement benefit plans	(9,563)	(7,711)
Accumulated other comprehensive loss, net of tax benefits	(318,185)	(336,615)
Total shareholders’ equity	492,462	468,885
Total liabilities and shareholders’ equity	9,610,070	9,545,970
Other assets
Bank-owned life insurance	183,936	182,986
Premises and equipment, net	192,789	195,324
Accrued interest receivable	26,547	25,077
Mortgage-servicing rights	8,745	9,047
Low-income housing investments	110,748	106,978
Real estate held for sale	100	0
Deferred tax asset	109,885	116,441
Real estate acquired in settlement of loans, net	614	115
Other	54,801	56,175
Other assets	688,165	692,143
Other liabilities
Accrued expenses	95,066	97,295
Federal and state income taxes payable	2,614	863
Cashier’s checks	34,616	36,401
Advance payments by borrowers	5,466	9,637
Other	68,555	68,073
Other liabilities	$ 206,317	$ 212,269

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Bank segment - Components of investment securities (Details) $ in Thousands	Mar. 31, 2023 USD ($) issue	Dec. 31, 2022 USD ($) issue
Available-for-sale
Amortized cost	$ 1,645,610
Available-for-sale investment securities, at fair value	1,419,755	$ 1,429,667
Held-to-maturity
Amortized cost	1,238,185	1,251,747
Held-to-maturity investment securities	1,158,090
American Savings Bank (ASB)
Available-for-sale
Amortized cost	1,645,610	1,678,205
Gross unrealized gains	1	0
Gross unrealized losses	(225,856)	(248,538)
Available-for-sale investment securities, at fair value	$ 1,419,755	$ 1,429,667
Gross unrealized losses, less than 12 months, number of issues | issue	26	129
Gross unrealized losses, less than 12 months, fair value	$ 98,678	$ 526,681
Gross unrealized losses, less than 12 months, amount	$ (7,417)	$ (61,147)
Gross unrealized losses, 12 months or longer, number of issues | issue	175	75
Gross unrealized losses, 12 months or longer, fair value	$ 1,305,736	$ 888,084
Gross unrealized losses, 12 months or more, amount	(218,439)	(187,391)
Held-to-maturity
Amortized cost	1,238,185	1,251,747
Gross unrealized gains	8,875	2,670
Gross unrealized losses	(88,970)	(103,446)
Held-to-maturity investment securities	$ 1,158,090	$ 1,150,971
Less than 12 months, number of issues | issue	6	23
Less than 12 months, fair value	$ 64,288	$ 200,503
Less than 12 months, amount	$ (532)	$ (13,815)
12 months or longer, number of issues | issue	44	53
12 months or longer: fair value	$ 480,248	$ 601,792
12 months or longer, amount	(88,438)	(89,631)
U.S. Treasury and federal agency obligations | American Savings Bank (ASB)
Available-for-sale
Amortized cost	85,786	88,344
Gross unrealized gains	0	0
Gross unrealized losses	(6,042)	(7,281)
Available-for-sale investment securities, at fair value	$ 79,744	$ 81,063
Gross unrealized losses, less than 12 months, number of issues | issue	0	12
Gross unrealized losses, less than 12 months, fair value	$ 0	$ 41,201
Gross unrealized losses, less than 12 months, amount	$ 0	$ (2,120)
Gross unrealized losses, 12 months or longer, number of issues | issue	14	4
Gross unrealized losses, 12 months or longer, fair value	$ 79,744	$ 39,862
Gross unrealized losses, 12 months or more, amount	(6,042)	(5,161)
Held-to-maturity
Amortized cost	59,900	59,894
Gross unrealized gains	0	0
Gross unrealized losses	(7,172)	(8,478)
Held-to-maturity investment securities	$ 52,728	$ 51,416
Less than 12 months, number of issues | issue	0	1
Less than 12 months, fair value	$ 0	$ 16,874
Less than 12 months, amount	$ 0	$ (3,222)
12 months or longer, number of issues | issue	3	2
12 months or longer: fair value	$ 52,728	$ 34,542
12 months or longer, amount	(7,172)	(5,256)
Mortgage-backed securities | American Savings Bank (ASB)
Available-for-sale
Amortized cost	1,500,717	1,530,582
Gross unrealized gains	1	0
Gross unrealized losses	(216,783)	(237,614)
Available-for-sale investment securities, at fair value	$ 1,283,935	$ 1,292,968
Gross unrealized losses, less than 12 months, number of issues | issue	24	113
Gross unrealized losses, less than 12 months, fair value	$ 89,727	$ 455,836
Gross unrealized losses, less than 12 months, amount	$ (7,367)	$ (56,999)
Gross unrealized losses, 12 months or longer, number of issues | issue	158	70
Gross unrealized losses, 12 months or longer, fair value	$ 1,193,633	$ 837,132
Gross unrealized losses, 12 months or more, amount	(209,416)	(180,615)
Held-to-maturity
Amortized cost	1,178,285	1,191,853
Gross unrealized gains	8,875	2,670
Gross unrealized losses	(81,798)	(94,968)
Held-to-maturity investment securities	$ 1,105,362	$ 1,099,555
Less than 12 months, number of issues | issue	6	22
Less than 12 months, fair value	$ 64,288	$ 183,629
Less than 12 months, amount	$ (532)	$ (10,593)
12 months or longer, number of issues | issue	41	51
12 months or longer: fair value	$ 427,520	$ 567,250
12 months or longer, amount	(81,266)	(84,375)
Corporate bonds | American Savings Bank (ASB)
Available-for-sale
Amortized cost	44,341	44,377
Gross unrealized gains	0	0
Gross unrealized losses	(3,031)	(3,643)
Available-for-sale investment securities, at fair value	$ 41,310	$ 40,734
Gross unrealized losses, less than 12 months, number of issues | issue	2	4
Gross unrealized losses, less than 12 months, fair value	$ 8,951	$ 29,644
Gross unrealized losses, less than 12 months, amount	$ (50)	$ (2,028)
Gross unrealized losses, 12 months or longer, number of issues | issue	3	1
Gross unrealized losses, 12 months or longer, fair value	$ 32,359	$ 11,090
Gross unrealized losses, 12 months or more, amount	(2,981)	(1,615)
Mortgage revenue bonds | American Savings Bank (ASB)
Available-for-sale
Amortized cost	14,766	14,902
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Available-for-sale investment securities, at fair value	$ 14,766	$ 14,902
Gross unrealized losses, less than 12 months, number of issues | issue	0	0
Gross unrealized losses, less than 12 months, fair value	$ 0	$ 0
Gross unrealized losses, less than 12 months, amount	$ 0	$ 0
Gross unrealized losses, 12 months or longer, number of issues | issue	0	0
Gross unrealized losses, 12 months or longer, fair value	$ 0	$ 0
Gross unrealized losses, 12 months or more, amount	$ 0	$ 0

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Bank segment - Contractual maturities of investment securities (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Available-for-sale
Due in one year or less	$ 2,579
Due after one year through five years	127,548
Due after five years through ten years	14,766
Due after ten years	0
Total amortized cost	144,893
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	1,500,717
Amortized cost	1,645,610
Held-to-maturity
Due in one year or less	0
Due after one year through five years	0
Due after five years through ten years	59,900
Due after ten years	0
Total amortized cost	59,900
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	1,178,285
Amortized cost	1,238,185	$ 1,251,747
Available-for-sale
Due in one year or less	2,531
Due after one year through five years	118,523
Due after five years through ten years	14,766
Due after ten years	0
Total fair value	135,820
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	1,283,935
Total available-for-sale securities	1,419,755	$ 1,429,667
Held-to-maturity
Due in one year or less	0
Due after one year through five years	0
Due after five years through ten years	52,728
Due after ten years	0
Total fair value	52,728
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies	1,105,362
Total held-to-maturity securities	$ 1,158,090

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Bank segment - Loans receivable (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022	Mar. 31, 2022	Dec. 31, 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total loans	$ 6,087,727	$ 6,005,021
Less: Deferred fees and discounts	(28,373)	(26,115)
Allowance for credit losses	(71,296)	(72,216)	$ (67,211)	$ (71,130)
Total loans, net	5,988,058	5,906,690
Real estate
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total loans	5,014,377	4,970,621
Real estate | Residential 1-4 family
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total loans	2,484,316	2,479,637
Allowance for credit losses	(4,612)	(6,270)	(7,874)	(6,545)
Real estate | Commercial real estate
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total loans	1,377,184	1,358,123
Allowance for credit losses	(22,701)	(21,898)	(20,176)	(24,696)
Real estate | Home equity line of credit
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total loans	1,022,800	1,002,905
Allowance for credit losses	(6,053)	(6,125)	(5,650)	(5,657)
Real estate | Residential land
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total loans	20,061	20,679
Allowance for credit losses	(620)	(717)	(697)	(646)
Real estate | Commercial construction
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total loans	94,267	88,489
Allowance for credit losses	(735)	(1,195)	(2,340)	(2,186)
Real estate | Residential construction
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total loans	15,749	20,788
Allowance for credit losses	(28)	(46)	(31)	(18)
Commercial
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total loans	800,949	779,691
Allowance for credit losses	(11,936)	(12,426)	(14,314)	(15,798)
Consumer
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total loans	272,401	254,709
Allowance for credit losses	$ (24,611)	$ (23,539)	$ (16,129)	$ (15,584)

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Bank segment - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Allowance for credit losses
Other bank borrowings	$ 680,690		$ 695,120
American Savings Bank (ASB)
Allowance for credit losses
Minimum benchmark percentage of loan to appraisal ratio which mortgage insurance is required	80.00%
Minimum benchmark percentage of loan to appraisal ratio on non-owner occupied residential property	75.00%
Advances from the FHLB	$ 0		414,000
American Savings Bank (ASB) | Federal Reserve Bank Advances
Allowance for credit losses
Other bank borrowings	550,000		$ 0
Home equity line of credit
Allowance for credit losses
Conversion of debt	7,800	$ 4,400
Commercial
Allowance for credit losses
Conversion of debt	1,200	500
Consumer
Allowance for credit losses
Conversion of debt	$ 1,100	$ 1,000

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Bank segment - Allowance for credit losses (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Allowance for credit losses:
Beginning balance	$ 72,216	$ 71,130
Charge-offs	(3,422)	(1,558)
Recoveries	1,327	1,402
Provision for credit losses	1,175	(3,763)
Ending balance	71,296	67,211
Real estate | Residential 1-4 family
Allowance for credit losses:
Beginning balance	6,270	6,545
Charge-offs	(809)	0
Recoveries	4	8
Provision for credit losses	(853)	1,321
Ending balance	4,612	7,874
Real estate | Commercial real estate
Allowance for credit losses:
Beginning balance	21,898	24,696
Charge-offs	0	0
Recoveries	0	0
Provision for credit losses	803	(4,520)
Ending balance	22,701	20,176
Real estate | Home equity line of credit
Allowance for credit losses:
Beginning balance	6,125	5,657
Charge-offs	(63)	0
Recoveries	17	11
Provision for credit losses	(26)	(18)
Ending balance	6,053	5,650
Real estate | Residential land
Allowance for credit losses:
Beginning balance	717	646
Charge-offs	0	0
Recoveries	0	5
Provision for credit losses	(97)	46
Ending balance	620	697
Real estate | Commercial construction
Allowance for credit losses:
Beginning balance	1,195	2,186
Charge-offs	0	0
Recoveries	0	0
Provision for credit losses	(460)	154
Ending balance	735	2,340
Real estate | Residential construction
Allowance for credit losses:
Beginning balance	46	18
Charge-offs	0	0
Recoveries	0	0
Provision for credit losses	(18)	13
Ending balance	28	31
Commercial
Allowance for credit losses:
Beginning balance	12,426	15,798
Charge-offs	(227)	(76)
Recoveries	398	353
Provision for credit losses	(661)	(1,761)
Ending balance	11,936	14,314
Consumer
Allowance for credit losses:
Beginning balance	23,539	15,584
Charge-offs	(2,323)	(1,482)
Recoveries	908	1,025
Provision for credit losses	2,487	1,002
Ending balance	$ 24,611	$ 16,129

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Bank segment - Allowance for loan commitments (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Allowance for loan commitments:
Beginning balance	$ 4,400	$ 4,900
Provision	0	500
Ending balance	4,400	5,400
Real estate | Home equity line of credit
Allowance for loan commitments:
Beginning balance	400	400
Provision	0	0
Ending balance	400	400
Real estate | Commercial construction
Allowance for loan commitments:
Beginning balance	2,600	3,700
Provision	0	(100)
Ending balance	2,600	3,600
Commercial
Allowance for loan commitments:
Beginning balance	1,400	800
Provision	0	600
Ending balance	$ 1,400	$ 1,400

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Bank segment - Credit risk profile - payment activity and assigned grades (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Credit risk profile by internally assigned grade for loans
Current year	$ 162,824		$ 1,296,473
One year before current year	1,275,157		1,220,751
Two years before current year	1,212,168		808,953
Three years before current year	795,046		296,592
Four years before current year	273,757		164,815
Prior	1,204,635		1,077,705
Revolving	1,097,070		1,077,634
Converted to term loans	67,070		62,098
Total	6,087,727		6,005,021
Gross charge-offs	3,422	$ 1,558
Real estate
Credit risk profile by internally assigned grade for loans
Total	5,014,377		4,970,621
Real estate | Residential 1-4 family
Credit risk profile by internally assigned grade for loans
Current year	46,292		432,707
One year before current year	425,843		755,056
Two years before current year	750,578		423,723
Three years before current year	419,047		113,096
Four years before current year	111,556		53,117
Prior	731,000		701,938
Revolving	0		0
Converted to term loans	0		0
Total	2,484,316		2,479,637
Charge offs current year	0
Charge offs one year prior of origination year	0
Charge offs two years prior of origination year	0
Charge offs three years prior of origination year	0
Charge offs four years prior of origination year	0
Charge offs more than five years prior of origination year	809
Charge offs revolving loans	0
Charge offs converted to term loans	0
Gross charge-offs	809	0
Real estate | Home equity line of credit
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	975,386		961,030
Converted to term loans	47,414		41,875
Total	1,022,800		1,002,905
Charge offs current year	0
Charge offs one year prior of origination year	0
Charge offs two years prior of origination year	0
Charge offs three years prior of origination year	0
Charge offs four years prior of origination year	0
Charge offs more than five years prior of origination year	0
Charge offs revolving loans	0
Charge offs converted to term loans	63
Gross charge-offs	63	0
Real estate | Residential land
Credit risk profile by internally assigned grade for loans
Current year	1,204		5,245
One year before current year	5,237		9,010
Two years before current year	8,587		5,222
Three years before current year	4,039		203
Four years before current year	0		522
Prior	994		477
Revolving	0		0
Converted to term loans	0		0
Total	20,061		20,679
Charge offs current year	0
Charge offs one year prior of origination year	0
Charge offs two years prior of origination year	0
Charge offs three years prior of origination year	0
Charge offs four years prior of origination year	0
Charge offs more than five years prior of origination year	0
Charge offs revolving loans	0
Charge offs converted to term loans	0
Gross charge-offs	0	0
Real estate | Residential construction
Credit risk profile by internally assigned grade for loans
Current year	1,444		7,986
One year before current year	6,786		11,624
Two years before current year	7,519		1,178
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	15,749		20,788
Charge offs current year	0
Charge offs one year prior of origination year	0
Charge offs two years prior of origination year	0
Charge offs three years prior of origination year	0
Charge offs four years prior of origination year	0
Charge offs more than five years prior of origination year	0
Charge offs revolving loans	0
Charge offs converted to term loans	0
Gross charge-offs	0	0
Real estate | Commercial real estate
Credit risk profile by internally assigned grade for loans
Current year	46,745		390,206
One year before current year	392,018		188,380
Two years before current year	185,905		287,432
Three years before current year	280,838		103,322
Four years before current year	93,656		63,084
Prior	369,787		317,464
Revolving	8,235		8,235
Converted to term loans	0		0
Total	1,377,184		1,358,123
Charge offs current year	0
Charge offs one year prior of origination year	0
Charge offs two years prior of origination year	0
Charge offs three years prior of origination year	0
Charge offs four years prior of origination year	0
Charge offs more than five years prior of origination year	0
Charge offs revolving loans	0
Charge offs converted to term loans	0
Gross charge-offs	0	0
Real estate | Commercial construction
Credit risk profile by internally assigned grade for loans
Current year	0		15,094
One year before current year	11,206		47,478
Two years before current year	54,924		44
Three years before current year	44		0
Four years before current year	0		0
Prior	0		0
Revolving	28,093		25,873
Converted to term loans	0		0
Total	94,267		88,489
Charge offs current year	0
Charge offs one year prior of origination year	0
Charge offs two years prior of origination year	0
Charge offs three years prior of origination year	0
Charge offs four years prior of origination year	0
Charge offs more than five years prior of origination year	0
Charge offs revolving loans	0
Charge offs converted to term loans	0
Gross charge-offs	0	0
Consumer
Credit risk profile by internally assigned grade for loans
Current year	36,997		202,061
One year before current year	192,162		21,885
Two years before current year	18,597		5,733
Three years before current year	4,405		8,132
Four years before current year	4,705		604
Prior	382		140
Revolving	9,765		10,956
Converted to term loans	5,388		5,198
Total	272,401		254,709
Charge offs current year	189
Charge offs one year prior of origination year	1,523
Charge offs two years prior of origination year	319
Charge offs three years prior of origination year	57
Charge offs four years prior of origination year	135
Charge offs more than five years prior of origination year	21
Charge offs revolving loans	15
Charge offs converted to term loans	64
Gross charge-offs	2,323	1,482
Commercial
Credit risk profile by internally assigned grade for loans
Current year	30,142		243,174
One year before current year	241,905		187,318
Two years before current year	186,058		85,621
Three years before current year	86,673		71,839
Four years before current year	63,840		47,488
Prior	102,472		57,686
Revolving	75,591		71,540
Converted to term loans	14,268		15,025
Total	800,949		779,691
Charge offs current year	0
Charge offs one year prior of origination year	0
Charge offs two years prior of origination year	51
Charge offs three years prior of origination year	0
Charge offs four years prior of origination year	0
Charge offs more than five years prior of origination year	0
Charge offs revolving loans	14
Charge offs converted to term loans	162
Gross charge-offs	227	$ 76
Pass | Real estate | Commercial real estate
Credit risk profile by internally assigned grade for loans
Current year	41,312		390,206
One year before current year	392,018		177,130
Two years before current year	174,655		283,321
Three years before current year	276,754		51,542
Four years before current year	52,121		63,084
Prior	339,660		278,280
Revolving	8,235		8,235
Converted to term loans	0		0
Total	1,284,755		1,251,798
Pass | Real estate | Commercial construction
Credit risk profile by internally assigned grade for loans
Current year	0		15,094
One year before current year	11,206		47,478
Two years before current year	54,924		44
Three years before current year	44		0
Four years before current year	0		0
Prior	0		0
Revolving	28,093		25,873
Converted to term loans	0		0
Total	94,267		88,489
Pass | Commercial
Credit risk profile by internally assigned grade for loans
Current year	30,142		239,852
One year before current year	238,671		185,013
Two years before current year	184,551		85,220
Three years before current year	86,275		68,161
Four years before current year	60,265		46,142
Prior	97,277		53,192
Revolving	66,200		60,871
Converted to term loans	12,918		13,964
Total	776,299		752,415
Special Mention | Real estate | Commercial real estate
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		11,250
Two years before current year	11,250		3,446
Three years before current year	3,425		40,423
Four years before current year	30,179		0
Prior	21,307		24,466
Revolving	0		0
Converted to term loans	0		0
Total	66,161		79,585
Special Mention | Real estate | Commercial construction
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
Special Mention | Commercial
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		2,374
Four years before current year	2,255		0
Prior	0		645
Revolving	8,492		9,005
Converted to term loans	6		8
Total	10,753		12,032
Substandard | Real estate | Commercial real estate
Credit risk profile by internally assigned grade for loans
Current year	5,433		0
One year before current year	0		0
Two years before current year	0		665
Three years before current year	659		11,357
Four years before current year	11,356		0
Prior	8,820		14,718
Revolving	0		0
Converted to term loans	0		0
Total	26,268		26,740
Substandard | Real estate | Commercial construction
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
Substandard | Commercial
Credit risk profile by internally assigned grade for loans
Current year	0		3,322
One year before current year	3,234		2,305
Two years before current year	1,507		401
Three years before current year	398		1,304
Four years before current year	1,320		1,346
Prior	5,195		3,849
Revolving	899		1,664
Converted to term loans	1,344		1,053
Total	13,897		15,244
Doubtful | Real estate | Commercial real estate
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
Doubtful | Real estate | Commercial construction
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
Doubtful | Commercial
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
Current | Real estate | Residential 1-4 family
Credit risk profile by internally assigned grade for loans
Current year	46,292		432,707
One year before current year	425,843		755,056
Two years before current year	750,578		423,455
Three years before current year	418,780		113,096
Four years before current year	110,618		51,860
Prior	727,411		698,354
Revolving	0		0
Converted to term loans	0		0
Total	2,479,522		2,474,528
Current | Real estate | Home equity line of credit
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	973,686		959,131
Converted to term loans	46,565		40,814
Total	1,020,251		999,945
Current | Real estate | Residential land
Credit risk profile by internally assigned grade for loans
Current year	1,204		5,245
One year before current year	5,237		9,010
Two years before current year	8,587		5,222
Three years before current year	4,039		203
Four years before current year	0		522
Prior	994		477
Revolving	0		0
Converted to term loans	0		0
Total	20,061		20,679
Current | Real estate | Residential construction
Credit risk profile by internally assigned grade for loans
Current year	1,444		7,986
One year before current year	6,786		11,624
Two years before current year	7,519		1,178
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	15,749		20,788
Current | Consumer
Credit risk profile by internally assigned grade for loans
Current year	36,794		199,574
One year before current year	189,133		21,330
Two years before current year	18,047		5,543
Three years before current year	4,233		7,580
Four years before current year	4,301		527
Prior	341		140
Revolving	9,589		10,810
Converted to term loans	4,904		4,782
Total	267,342		250,286
30-59 days past due
Credit risk profile by internally assigned grade for loans
Total	5,567		5,959
30-59 days past due | Real estate | Residential 1-4 family
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	938		448
Prior	971		1,098
Revolving	0		0
Converted to term loans	0		0
Total	1,909		1,546
30-59 days past due | Real estate | Home equity line of credit
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	781		1,103
Converted to term loans	115		209
Total	896		1,312
30-59 days past due | Real estate | Residential land
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
30-59 days past due | Real estate | Residential construction
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
30-59 days past due | Real estate | Commercial real estate
Credit risk profile by internally assigned grade for loans
Total	0		508
30-59 days past due | Real estate | Commercial construction
Credit risk profile by internally assigned grade for loans
Total	0		0
30-59 days past due | Consumer
Credit risk profile by internally assigned grade for loans
Current year	203		1,110
One year before current year	1,628		287
Two years before current year	235		65
Three years before current year	54		239
Four years before current year	170		30
Prior	11		0
Revolving	78		81
Converted to term loans	120		167
Total	2,499		1,979
30-59 days past due | Commercial
Credit risk profile by internally assigned grade for loans
Total	263		614
60-89 days past due
Credit risk profile by internally assigned grade for loans
Total	3,024		2,343
60-89 days past due | Real estate | Residential 1-4 family
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		268
Three years before current year	0		0
Four years before current year	0		0
Prior	930		90
Revolving	0		0
Converted to term loans	0		0
Total	930		358
60-89 days past due | Real estate | Home equity line of credit
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	346		209
Converted to term loans	337		226
Total	683		435
60-89 days past due | Real estate | Residential land
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
60-89 days past due | Real estate | Residential construction
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
60-89 days past due | Real estate | Commercial real estate
Credit risk profile by internally assigned grade for loans
Total	0		217
60-89 days past due | Real estate | Commercial construction
Credit risk profile by internally assigned grade for loans
Total	0		0
60-89 days past due | Consumer
Credit risk profile by internally assigned grade for loans
Current year	0		756
One year before current year	899		163
Two years before current year	116		88
Three years before current year	59		137
Four years before current year	129		19
Prior	4		0
Revolving	16		45
Converted to term loans	117		107
Total	1,340		1,315
60-89 days past due | Commercial
Credit risk profile by internally assigned grade for loans
Total	71		18
Greater than 89 days past due
Credit risk profile by internally assigned grade for loans
Total	4,572		5,624
Greater than 89 days past due | Real estate | Residential 1-4 family
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	267		0
Four years before current year	0		809
Prior	1,688		2,396
Revolving	0		0
Converted to term loans	0		0
Total	1,955		3,205
Greater than 89 days past due | Real estate | Home equity line of credit
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	573		587
Converted to term loans	397		626
Total	970		1,213
Greater than 89 days past due | Real estate | Residential land
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
Greater than 89 days past due | Real estate | Residential construction
Credit risk profile by internally assigned grade for loans
Current year	0		0
One year before current year	0		0
Two years before current year	0		0
Three years before current year	0		0
Four years before current year	0		0
Prior	0		0
Revolving	0		0
Converted to term loans	0		0
Total	0		0
Greater than 89 days past due | Real estate | Commercial real estate
Credit risk profile by internally assigned grade for loans
Total	0		0
Greater than 89 days past due | Real estate | Commercial construction
Credit risk profile by internally assigned grade for loans
Total	0		0
Greater than 89 days past due | Consumer
Credit risk profile by internally assigned grade for loans
Current year	0		621
One year before current year	502		105
Two years before current year	199		37
Three years before current year	59		176
Four years before current year	105		28
Prior	26		0
Revolving	82		20
Converted to term loans	247		142
Total	1,220		1,129
Greater than 89 days past due | Commercial
Credit risk profile by internally assigned grade for loans
Total	$ 427		$ 77

XML

Bank segment - Credit risk profile - payment activity (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Credit risk profile based on payment activity for loans
Total financing receivables	$ 6,087,727	$ 6,005,021
Amortized cost> 90 days and accruing	0	0
Real estate
Credit risk profile based on payment activity for loans
Total financing receivables	5,014,377	4,970,621
Real estate | Residential 1-4 family
Credit risk profile based on payment activity for loans
Total financing receivables	2,484,316	2,479,637
Amortized cost> 90 days and accruing	0	0
Real estate | Commercial real estate
Credit risk profile based on payment activity for loans
Total financing receivables	1,377,184	1,358,123
Amortized cost> 90 days and accruing	0	0
Real estate | Home equity line of credit
Credit risk profile based on payment activity for loans
Total financing receivables	1,022,800	1,002,905
Amortized cost> 90 days and accruing	0	0
Real estate | Residential land
Credit risk profile based on payment activity for loans
Total financing receivables	20,061	20,679
Amortized cost> 90 days and accruing	0	0
Real estate | Commercial construction
Credit risk profile based on payment activity for loans
Total financing receivables	94,267	88,489
Amortized cost> 90 days and accruing	0	0
Real estate | Residential construction
Credit risk profile based on payment activity for loans
Total financing receivables	15,749	20,788
Amortized cost> 90 days and accruing	0	0
Commercial
Credit risk profile based on payment activity for loans
Total financing receivables	800,949	779,691
Amortized cost> 90 days and accruing	0	0
Consumer
Credit risk profile based on payment activity for loans
Total financing receivables	272,401	254,709
Amortized cost> 90 days and accruing	0	0
30-59 days past due
Credit risk profile based on payment activity for loans
Total financing receivables	5,567	5,959
30-59 days past due | Real estate | Residential 1-4 family
Credit risk profile based on payment activity for loans
Total financing receivables	1,909	1,546
30-59 days past due | Real estate | Commercial real estate
Credit risk profile based on payment activity for loans
Total financing receivables	0	508
30-59 days past due | Real estate | Home equity line of credit
Credit risk profile based on payment activity for loans
Total financing receivables	896	1,312
30-59 days past due | Real estate | Residential land
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
30-59 days past due | Real estate | Commercial construction
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
30-59 days past due | Real estate | Residential construction
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
30-59 days past due | Commercial
Credit risk profile based on payment activity for loans
Total financing receivables	263	614
30-59 days past due | Consumer
Credit risk profile based on payment activity for loans
Total financing receivables	2,499	1,979
60-89 days past due
Credit risk profile based on payment activity for loans
Total financing receivables	3,024	2,343
60-89 days past due | Real estate | Residential 1-4 family
Credit risk profile based on payment activity for loans
Total financing receivables	930	358
60-89 days past due | Real estate | Commercial real estate
Credit risk profile based on payment activity for loans
Total financing receivables	0	217
60-89 days past due | Real estate | Home equity line of credit
Credit risk profile based on payment activity for loans
Total financing receivables	683	435
60-89 days past due | Real estate | Residential land
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
60-89 days past due | Real estate | Commercial construction
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
60-89 days past due | Real estate | Residential construction
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
60-89 days past due | Commercial
Credit risk profile based on payment activity for loans
Total financing receivables	71	18
60-89 days past due | Consumer
Credit risk profile based on payment activity for loans
Total financing receivables	1,340	1,315
Greater than 90 days
Credit risk profile based on payment activity for loans
Total financing receivables	4,572	5,624
Greater than 90 days | Real estate | Residential 1-4 family
Credit risk profile based on payment activity for loans
Total financing receivables	1,955	3,205
Greater than 90 days | Real estate | Commercial real estate
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
Greater than 90 days | Real estate | Home equity line of credit
Credit risk profile based on payment activity for loans
Total financing receivables	970	1,213
Greater than 90 days | Real estate | Residential land
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
Greater than 90 days | Real estate | Commercial construction
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
Greater than 90 days | Real estate | Residential construction
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
Greater than 90 days | Commercial
Credit risk profile based on payment activity for loans
Total financing receivables	427	77
Greater than 90 days | Consumer
Credit risk profile based on payment activity for loans
Total financing receivables	1,220	1,129
Total past due
Credit risk profile based on payment activity for loans
Total financing receivables	13,163	13,926
Total past due | Real estate | Residential 1-4 family
Credit risk profile based on payment activity for loans
Total financing receivables	4,794	5,109
Total past due | Real estate | Commercial real estate
Credit risk profile based on payment activity for loans
Total financing receivables	0	725
Total past due | Real estate | Home equity line of credit
Credit risk profile based on payment activity for loans
Total financing receivables	2,549	2,960
Total past due | Real estate | Residential land
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
Total past due | Real estate | Commercial construction
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
Total past due | Real estate | Residential construction
Credit risk profile based on payment activity for loans
Total financing receivables	0	0
Total past due | Commercial
Credit risk profile based on payment activity for loans
Total financing receivables	761	709
Total past due | Consumer
Credit risk profile based on payment activity for loans
Total financing receivables	5,059	4,423
Current
Credit risk profile based on payment activity for loans
Total financing receivables	6,074,564	5,991,095
Current | Real estate | Residential 1-4 family
Credit risk profile based on payment activity for loans
Total financing receivables	2,479,522	2,474,528
Current | Real estate | Commercial real estate
Credit risk profile based on payment activity for loans
Total financing receivables	1,377,184	1,357,398
Current | Real estate | Home equity line of credit
Credit risk profile based on payment activity for loans
Total financing receivables	1,020,251	999,945
Current | Real estate | Residential land
Credit risk profile based on payment activity for loans
Total financing receivables	20,061	20,679
Current | Real estate | Commercial construction
Credit risk profile based on payment activity for loans
Total financing receivables	94,267	88,489
Current | Real estate | Residential construction
Credit risk profile based on payment activity for loans
Total financing receivables	15,749	20,788
Current | Commercial
Credit risk profile based on payment activity for loans
Total financing receivables	800,188	778,982
Current | Consumer
Credit risk profile based on payment activity for loans
Total financing receivables	$ 267,342	$ 250,286

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Bank segment - Credit risk profile - nonaccrual loans (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Mar. 31, 2023
Credit risk profile based on nonaccrual loans
With a Related ACL	$ 12,043	$ 11,133
Without a Related ACL	4,423	3,354
Total	16,466	14,487
Total troubled debt restructuring loans not included above	30,130
Real estate | Residential 1-4 family
Credit risk profile based on nonaccrual loans
With a Related ACL	4,198	3,371
Without a Related ACL	2,981	2,117
Total	7,179	5,488
Total troubled debt restructuring loans not included above	8,821
Real estate | Commercial real estate
Credit risk profile based on nonaccrual loans
With a Related ACL	0	0
Without a Related ACL	0	0
Total	0	0
Total troubled debt restructuring loans not included above	9,477
Real estate | Home equity line of credit
Credit risk profile based on nonaccrual loans
With a Related ACL	3,654	4,014
Without a Related ACL	1,442	1,237
Total	5,096	5,251
Total troubled debt restructuring loans not included above	4,404
Real estate | Residential land
Credit risk profile based on nonaccrual loans
With a Related ACL	420	109
Without a Related ACL	0	0
Total	420	109
Total troubled debt restructuring loans not included above	782
Real estate | Commercial construction
Credit risk profile based on nonaccrual loans
With a Related ACL	0	0
Without a Related ACL	0	0
Total	0	0
Total troubled debt restructuring loans not included above	0
Real estate | Residential construction
Credit risk profile based on nonaccrual loans
With a Related ACL	0	0
Without a Related ACL	0	0
Total	0	0
Total troubled debt restructuring loans not included above	0
Commercial
Credit risk profile based on nonaccrual loans
With a Related ACL	2,183	1,744
Without a Related ACL	0	0
Total	2,183	1,744
Total troubled debt restructuring loans not included above	6,596
Consumer
Credit risk profile based on nonaccrual loans
With a Related ACL	1,588	1,895
Without a Related ACL	0	0
Total	1,588	$ 1,895
Total troubled debt restructuring loans not included above	$ 50

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Bank segment - Troubled debt restructuring - narrative (Details) - USD ($)	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2023	Dec. 31, 2022
Financing Receivable, Impaired [Line Items]
Consumer mortgage loans collateralized by residential real estate property in foreclosure process		$ 3,400,000	$ 4,200,000
Troubled debt restructurings real estate loans
Financing Receivable, Impaired [Line Items]
Financing receivable modifications minimum, period of payment default of loans determined to be TDRs (in days)	90 days
Commitments to lend additional funds to borrows with impaired or modified loans			$ 0

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Bank segment - Collateral-dependent loans (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Residential real estate property | Real estate | Residential 1-4 family
Financing Receivable, Nonaccrual [Line Items]
Collateral-dependent loans, amortized cost	$ 2,353	$ 3,959
Residential real estate property | Real estate | Home equity line of credit
Financing Receivable, Nonaccrual [Line Items]
Collateral-dependent loans, amortized cost	1,237	1,425
Collateral pledged
Financing Receivable, Nonaccrual [Line Items]
Collateral-dependent loans, amortized cost	$ 3,590	$ 5,384

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Bank segment - Mortgage servicing rights (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2023 USD ($) loan	Mar. 31, 2022 USD ($) loan	Dec. 31, 2022 USD ($)
Servicing contracts
Prepayment rate:
25 basis points adverse rate change	$ (109)		$ (92)
50 basis points adverse rate change	(243)		(214)
Discount rate:
25 basis points adverse rate change	(190)		(182)
50 basis points adverse rate change	$ (376)		(361)
American Savings Bank (ASB)
Servicing Asset at Amortized Cost [Line Items]
Number of mortgage loans repurchased | loan	0	0
Mortgage service fees	$ 900	$ 900
Mortgage servicing rights
Servicing asset - beginning balance	9,047
Servicing asset - ending balance	8,745
American Savings Bank (ASB) | Residential loan
Servicing Asset at Amortized Cost [Line Items]
Proceeds from sale of residential loans	5,700	75,600
Gain on sale of mortgage loans	100	1,100
American Savings Bank (ASB) | Servicing contracts
Changes in Carrying Value of MSRs
Gross carrying amount	17,868		19,544
Accumulated amortization	(9,123)		(10,497)
Valuation allowance	0	0	0
Net carrying amount	8,745	10,024	9,047
Mortgage servicing rights
Servicing asset - beginning balance	9,047	9,950
Amount capitalized	51	719
Amortization	(353)	(645)
Other-than-temporary impairment	0	0
Servicing asset - ending balance	8,745	10,024
Valuation allowance for mortgage servicing rights
Valuation allowance, beginning balance	0	0
Provision	0	0
Other-than-temporary impairment	0	0
Valuation allowance, ending balance	0	$ 0
Unpaid principal balance	$ 1,431,037		$ 1,451,322
American Savings Bank (ASB) | Servicing contracts | Weighted average note rate
Valuation allowance for mortgage servicing rights
Weighted average measurement input	0.0339		0.0338
American Savings Bank (ASB) | Servicing contracts | Weighted average discount rate
Valuation allowance for mortgage servicing rights
Weighted average measurement input	0.1000		0.1000
American Savings Bank (ASB) | Servicing contracts | Weighted average prepayment speed
Valuation allowance for mortgage servicing rights
Weighted average measurement input	0.0639		0.0656

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Bank segment - Other borrowings (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Offsetting Liabilities [Line Items]
Gross amount  of recognized  liabilities	$ 131.0	$ 281.0
Gross amount  offset in the  Balance Sheets	0.0	0.0
Net amount of liabilities presented in the Balance Sheets	131.0	281.0
American Savings Bank (ASB)
Offsetting Liabilities [Line Items]
Advances from the FHLB	0.0	414.0
Commercial account holders
Offsetting Liabilities [Line Items]
Net amount of liabilities presented in the Balance Sheets	131.0	281.0
Financial instruments	172.0	327.0
Cash collateral pledged	$ 0.0	$ 0.0

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Bank segment - Derivatives (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Derivative instrument
Derivative, gain (loss), statement of income or comprehensive income	Revenues	Revenues
Derivative Financial Instruments Not Designated as Hedging Instruments
Derivative instrument
Asset derivatives	$ 35		$ 27
Liability derivatives	4		0
Net gains (losses) recognized in the Statement of Income	4	$ (477)
Interest rate lock commitments
Derivative instrument
Notional amount	2,467		1,720
Fair value	26		9
Interest rate lock commitments | Derivative Financial Instruments Not Designated as Hedging Instruments
Derivative instrument
Asset derivatives	26		9
Liability derivatives	0		0
Net gains (losses) recognized in the Statement of Income	17	(655)
Forward commitments
Derivative instrument
Notional amount	2,250		1,500
Fair value	5		18
Forward commitments | Derivative Financial Instruments Not Designated as Hedging Instruments
Derivative instrument
Asset derivatives	9		18
Liability derivatives	4		$ 0
Net gains (losses) recognized in the Statement of Income	$ (13)	$ 178

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Bank segment - Contingencies (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
American Savings Bank (ASB)
Loss Contingencies [Line Items]
Unfunded commitments to fund the company's LIHTC	$ 77.1	$ 70.1

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Credit agreement and changes in debt - Narrative (Details)	Feb. 18, 2022 USD ($) extensionOption	Mar. 31, 2023 USD ($)	Mar. 16, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 28, 2022 USD ($)	Oct. 20, 2022 USD ($)	May 14, 2021 USD ($) institution
HEI Facility
Credit agreement
Credit agreement							$ 175,000,000
HEI Facility | Senior Notes
Credit agreement
Aggregate principal amount			$ 100,000,000
Hawaiian Electric Company, Inc. and Subsidiaries | Credit Facilities
Credit agreement
Number of financial institutions | institution							9
Credit agreement		$ 0		$ 0
Hawaiian Electric Company, Inc. and Subsidiaries | Hawaiian Electric Facility
Credit agreement
Credit agreement	$ 275,000,000						$ 200,000,000
Number of extension options | extensionOption	2
Extension period	1 year
Hawaiian Electric, Parent | Term Loan
Credit agreement
Aggregate principal amount						$ 100,000,000
Line of credit outstanding		$ 65,000,000			$ 35,000,000
Hawaiian Electric, Parent | Term Loan | SOFR
Credit agreement
Effective interest rate		5.81%

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Credit agreement and changes in debt - HEI private placement (Details) - Senior Notes	Mar. 31, 2023 USD ($)
Series 2023A
Debt Instrument [Line Items]
Aggregate principal amount	$ 39,000,000
Fixed coupon interest rate	6.04%
Series 2023B
Debt Instrument [Line Items]
Aggregate principal amount	$ 61,000,000
Fixed coupon interest rate	6.10%

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Credit agreement and changes in debt - Note purchase agreements (Details) - Senior Notes - USD ($)	Mar. 31, 2023	Jan. 10, 2023
Series 2023A
Debt Instrument [Line Items]
Aggregate principal amount	$ 39,000,000
Fixed coupon interest rate	6.04%
Series 2023A | Hawaiian Electric Company, Inc. and Subsidiaries
Debt Instrument [Line Items]
Aggregate principal amount		$ 90,000,000
Series 2023A | Hawaiian Electric, Parent
Debt Instrument [Line Items]
Aggregate principal amount		$ 40,000,000
Fixed coupon interest rate		6.11%
Series 2023A | Hawaii Electric Light Company, Inc
Debt Instrument [Line Items]
Aggregate principal amount		$ 25,000,000
Fixed coupon interest rate		6.25%
Series 2023A | Maui Electric
Debt Instrument [Line Items]
Aggregate principal amount		$ 25,000,000
Fixed coupon interest rate		6.25%
Series 2023B
Debt Instrument [Line Items]
Aggregate principal amount	$ 61,000,000
Fixed coupon interest rate	6.10%
Series 2023B | Hawaiian Electric Company, Inc. and Subsidiaries
Debt Instrument [Line Items]
Aggregate principal amount		$ 40,000,000
Series 2023B | Hawaiian Electric, Parent
Debt Instrument [Line Items]
Aggregate principal amount		$ 40,000,000
Fixed coupon interest rate		6.25%
Series 2023C | Hawaiian Electric Company, Inc. and Subsidiaries
Debt Instrument [Line Items]
Aggregate principal amount		$ 20,000,000
Series 2023C | Hawaiian Electric, Parent
Debt Instrument [Line Items]
Aggregate principal amount		$ 20,000,000
Fixed coupon interest rate		6.70%

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Shareholders' equity - Accumulated other comprehensive income (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ 2,202,499	$ 2,390,884
Current period other comprehensive income (loss)	20,488	(117,159)
Ending balance	2,237,955	2,303,642
AOCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(336,028)	(52,533)
Current period other comprehensive income (loss)	20,488	(117,159)
Ending balance	(315,540)	(169,692)
Net unrealized gains (losses) on securities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(328,904)	(32,037)
Current period other comprehensive income (loss)	20,282	(120,407)
Ending balance	(308,622)	(152,444)
Unrealized gains (losses) on derivatives
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	1,991	(3,638)
Current period other comprehensive income (loss)	138	3,072
Ending balance	2,129	(566)
Retirement benefit plans
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(9,115)	(16,858)
Current period other comprehensive income (loss)	68	176
Ending balance	(9,047)	(16,682)
Hawaiian Electric Company, Inc. and Subsidiaries
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	2,344,170	2,261,899
Current period other comprehensive income (loss)	(45)	51
Ending balance	2,358,884	2,276,884
Hawaiian Electric Company, Inc. and Subsidiaries | AOCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	2,861	(3,280)
Current period other comprehensive income (loss)	(45)	51
Ending balance	2,816	(3,229)
Hawaiian Electric Company, Inc. and Subsidiaries | Retirement benefit plans
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	2,861	(3,280)
Current period other comprehensive income (loss)	(45)	51
Ending balance	$ 2,816	$ (3,229)

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Shareholders' equity - Reclassification out of AOCI (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Reclassifications out of accumulated other comprehensive income/(loss)
Revenues	$ (928,237)	$ (785,068)
Interest expense	28,798	24,349
Reclassification out of Accumulated Other Comprehensive Income
Reclassifications out of accumulated other comprehensive income/(loss)
Total reclassifications	3,697	231
Hawaiian Electric Company, Inc. and Subsidiaries
Reclassifications out of accumulated other comprehensive income/(loss)
Revenues	(830,361)	(708,792)
Total reclassifications	(47,508)	(46,908)
Hawaiian Electric Company, Inc. and Subsidiaries | Reclassification out of Accumulated Other Comprehensive Income
Reclassifications out of accumulated other comprehensive income/(loss)
Total reclassifications	(45)	51
Net unrealized gains (losses) on available-for sale investment securities - amortization of unrealized holding losses on held-to-maturity securities | Reclassification out of Accumulated Other Comprehensive Income
Reclassifications out of accumulated other comprehensive income/(loss)
Revenues	3,677	0
Net realized losses (gains) on derivatives qualifying as cash flow hedges | Reclassification out of Accumulated Other Comprehensive Income
Reclassifications out of accumulated other comprehensive income/(loss)
Interest expense	(48)	55
Amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost | Reclassification out of Accumulated Other Comprehensive Income
Reclassifications out of accumulated other comprehensive income/(loss)
Total reclassifications	(357)	4,501
Amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost | Hawaiian Electric Company, Inc. and Subsidiaries | Reclassification out of Accumulated Other Comprehensive Income
Reclassifications out of accumulated other comprehensive income/(loss)
Total reclassifications	(470)	4,376
Impact of D&Os of the PUC included in regulatory assets | Reclassification out of Accumulated Other Comprehensive Income
Reclassifications out of accumulated other comprehensive income/(loss)
Total reclassifications	425	(4,325)
Impact of D&Os of the PUC included in regulatory assets | Hawaiian Electric Company, Inc. and Subsidiaries | Reclassification out of Accumulated Other Comprehensive Income
Reclassifications out of accumulated other comprehensive income/(loss)
Total reclassifications	$ 425	$ (4,325)

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Revenues (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 822,384	$ 700,831
Total revenues from other sources	105,853	84,237
Revenues	928,237	785,068
Services/goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,022	12,996
Services/goods transferred over time
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	810,362	687,835
Electric energy sales - residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	255,550	224,574
Electric energy sales - commercial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	254,470	219,597
Electric energy sales - large light and power
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	290,978	241,123
Electric energy sales - other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,457	1,426
Bank fees
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,022	12,996
Other sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,907	1,115
Regulatory revenue
Disaggregation of Revenue [Line Items]
Total revenues from other sources	15,604	12,886
Bank interest and dividend income
Disaggregation of Revenue [Line Items]
Total revenues from other sources	79,479	59,989
Other bank noninterest income
Disaggregation of Revenue [Line Items]
Total revenues from other sources	2,356	2,130
Other
Disaggregation of Revenue [Line Items]
Total revenues from other sources	8,414	9,232
Electric utility
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	806,455	686,720
Total revenues from other sources	23,906	22,072
Revenues	830,361	708,792
Electric utility | Services/goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Electric utility | Services/goods transferred over time
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	806,455	686,720
Electric utility | Electric energy sales - residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	255,550	224,574
Electric utility | Electric energy sales - commercial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	254,470	219,597
Electric utility | Electric energy sales - large light and power
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	290,978	241,123
Electric utility | Electric energy sales - other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,457	1,426
Electric utility | Bank fees
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Electric utility | Other sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Electric utility | Regulatory revenue
Disaggregation of Revenue [Line Items]
Total revenues from other sources	15,604	12,886
Electric utility | Bank interest and dividend income
Disaggregation of Revenue [Line Items]
Total revenues from other sources	0	0
Electric utility | Other bank noninterest income
Disaggregation of Revenue [Line Items]
Total revenues from other sources	0	0
Electric utility | Other
Disaggregation of Revenue [Line Items]
Total revenues from other sources	8,302	9,186
Bank
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,022	12,996
Total revenues from other sources	81,835	62,119
Revenues	93,857	75,115
Bank | Services/goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,022	12,996
Bank | Services/goods transferred over time
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Bank | Electric energy sales - residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Bank | Electric energy sales - commercial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Bank | Electric energy sales - large light and power
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Bank | Electric energy sales - other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Bank | Bank fees
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,022	12,996
Bank | Other sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Bank | Regulatory revenue
Disaggregation of Revenue [Line Items]
Total revenues from other sources	0	0
Bank | Bank interest and dividend income
Disaggregation of Revenue [Line Items]
Total revenues from other sources	79,479	59,989
Bank | Other bank noninterest income
Disaggregation of Revenue [Line Items]
Total revenues from other sources	2,356	2,130
Bank | Other
Disaggregation of Revenue [Line Items]
Total revenues from other sources	0	0
Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,907	1,115
Total revenues from other sources	112	46
Revenues	4,019	1,161
Other | Services/goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Other | Services/goods transferred over time
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,907	1,115
Other | Electric energy sales - residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Other | Electric energy sales - commercial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Other | Electric energy sales - large light and power
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Other | Electric energy sales - other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Other | Bank fees
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Other | Other sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,907	1,115
Other | Regulatory revenue
Disaggregation of Revenue [Line Items]
Total revenues from other sources	0	0
Other | Bank interest and dividend income
Disaggregation of Revenue [Line Items]
Total revenues from other sources	0	0
Other | Other bank noninterest income
Disaggregation of Revenue [Line Items]
Total revenues from other sources	0	0
Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from other sources	$ 112	$ 46

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Retirement benefits - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Retirement benefits
Contributions made to defined benefit plans	$ 2.0	$ 10.0
Contributions expected to be paid in current year	8.0		$ 43.0
Expected payments for remainder of fiscal year	3.0		2.0
Retirement benefits expense	$ 11.0	12.0
Number of years for which regulatory asset/liability for each utility will be amortized, beginning with respective utility's next rate case (in years)	5 years
Defined contribution plan, expenses recognized	$ 2.7	2.0
Cash contributions by the employer to defined contribution plan	2.7	1.9
Hawaiian Electric Company, Inc. and Subsidiaries
Retirement benefits
Contributions made to defined benefit plans	2.0	10.0
Contributions expected to be paid in current year	8.0		42.0
Expected payments for remainder of fiscal year	1.0		$ 1.0
Retirement benefits expense	11.0	12.0
Defined contribution plan, expenses recognized	1.3	0.9
Cash contributions by the employer to defined contribution plan	$ 1.3	$ 0.9

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Retirement benefits - Components of NPPC and NPBC (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Pension benefits
Defined Benefit Plan
Service cost	$ 11,396	$ 19,824
Interest cost	25,621	19,811
Expected return on plan assets	(35,195)	(35,333)
Amortization of net prior period gain	0	0
Amortization of net actuarial (gain) losses	188	6,297
Net periodic pension/benefit cost (return)	2,010	10,599
Impact of PUC D&Os	18,133	9,551
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)	20,143	20,150
Other benefits
Defined Benefit Plan
Service cost	344	656
Interest cost	2,157	1,637
Expected return on plan assets	(3,405)	(3,397)
Amortization of net prior period gain	(219)	(232)
Amortization of net actuarial (gain) losses	(449)	(3)
Net periodic pension/benefit cost (return)	(1,572)	(1,339)
Impact of PUC D&Os	1,425	1,219
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)	(147)	(120)
Hawaiian Electric Company, Inc. and Subsidiaries | Pension benefits
Defined Benefit Plan
Service cost	11,019	19,318
Interest cost	23,698	18,462
Expected return on plan assets	(32,972)	(33,546)
Amortization of net prior period gain	0	0
Amortization of net actuarial (gain) losses	19	6,125
Net periodic pension/benefit cost (return)	1,764	10,359
Impact of PUC D&Os	18,133	9,551
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)	19,897	19,910
Hawaiian Electric Company, Inc. and Subsidiaries | Other benefits
Defined Benefit Plan
Service cost	340	649
Interest cost	2,063	1,573
Expected return on plan assets	(3,353)	(3,347)
Amortization of net prior period gain	(218)	(231)
Amortization of net actuarial (gain) losses	(434)	0
Net periodic pension/benefit cost (return)	(1,602)	(1,356)
Impact of PUC D&Os	1,425	1,219
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)	$ (177)	$ (137)

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Share-based compensation - Narrative (Details) - USD ($) $ in Millions		3 Months Ended
	Mar. 01, 2014	Mar. 31, 2023	Mar. 31, 2022
Share-based compensation
Income tax benefit from compensation expense		$ 0.3	$ 0.3
Restricted stock units
Share-based compensation
Fair value of vested stock		3.6	3.9
Income tax benefit from compensation expense		0.8	0.6
Unrecognized share based compensation		$ 7.5
Weighted average period for recognition of unrecognized compensation cost (in years)		2 years 2 months 12 days
Long-term Incentive Plan
Share-based compensation
Payment award, low end of range		0.00%
Payment award, high end of range		200.00%
Measurement period for total return to shareholders (in years)		3 years
Award performance period (in years)		3 years
LTIP linked to TRS
Share-based compensation
Fair value of vested stock		$ 0.0	0.8
Income tax benefit from compensation expense			0.1
Unrecognized share based compensation		$ 2.4
Weighted average period for recognition of unrecognized compensation cost (in years)		1 year 8 months 12 days
LTIP awards linked to other performance conditions
Share-based compensation
Fair value of vested stock		$ 2.9	3.2
Income tax benefit from compensation expense		0.6	$ 0.4
Unrecognized share based compensation		$ 7.4
Weighted average period for recognition of unrecognized compensation cost (in years)		1 year 7 months 6 days
Equity and Incentive Plan
Share-based compensation
Number of additional shares authorized (in shares)	1,500,000
Shares available for future issuance (in shares)		2,700,000
Number of share issuable upon vesting and achievement of performance goals (in shares)		700,000
Nonemployee Director Stock Plan
Share-based compensation
Shares available for future grant (in shares)		207,118

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Share-based compensation - Summary of income taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Share-based compensation
Share-based compensation expense	$ 2.0	$ 2.1
Income tax benefit	0.3	0.3
Hawaiian Electric Company, Inc. and Subsidiaries
Share-based compensation
Share-based compensation expense	0.7	0.6
Income tax benefit	$ 0.1	$ 0.1

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Share-based compensation - 2011 Director Plan (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Share-based compensation
Income tax benefit	$ 0.3	$ 0.3
Common stock
Share-based compensation
Shares granted (in shares)	1,509	0
Fair value	$ 0.1	$ 0.0
Income tax benefit	$ 0.0	$ 0.0

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Share-based compensation - Summary of changes in share based compensation (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Restricted stock units
Shares
Outstanding, beginning of period (in shares)	182,528	233,448
Granted (in shares)	100,088	96,455
Vested (in shares)	(80,077)	(90,380)
Forfeited (in shares)	(406)	(31,178)
Outstanding, end of period (in shares)	202,133	208,345
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)	$ 4.2	$ 4.0
Weighted-average grant-date fair value per share
Outstanding, beginning of period (in dollars per share)	$ 39.75	$ 38.10
Granted (in dollars per share)	42.41	41.29
Vested (in dollars per share)	39.30	37.58
Forfeited (in dollars per share)	38.39	38.78
Outstanding, end of period (in dollars per share)	$ 41.25	$ 39.71
LTIP linked to TRS
Shares
Outstanding, beginning of period (in shares)	71,574	90,974
Granted (in shares)	27,123	26,079
Vested (in shares)	(18,691)	(29,042)
Forfeited (in shares)	0	(11,671)
Outstanding, end of period (in shares)	80,006	76,340
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)	$ 1.5	$ 1.4
Weighted-average grant-date fair value per share
Outstanding, beginning of period (in dollars per share)	$ 47.67	$ 42.86
Granted (in dollars per share)	55.98	54.92
Vested (in dollars per share)	48.62	41.07
Forfeited (in dollars per share)	0	42.60
Outstanding, end of period (in dollars per share)	$ 50.27	$ 47.70
LTIP awards linked to other performance conditions
Shares
Outstanding, beginning of period (in shares)	309,589	306,342
Granted (in shares)	108,499	104,300
Vested (in shares)	(62,778)	(71,807)
Forfeited (in shares)	0	(46,684)
Outstanding, end of period (in shares)	355,310	292,151
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)	$ 4.6	$ 4.3
Weighted-average grant-date fair value per share
Outstanding, beginning of period (in dollars per share)	$ 39.50	$ 38.42
Granted (in dollars per share)	42.41	41.29
Vested (in dollars per share)	48.07	37.68
Forfeited (in dollars per share)	0	36.77
Outstanding, end of period (in dollars per share)	$ 38.87	$ 39.89

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Share-based compensation - Fair value assumptions (Details) - LTIP linked to TRS - $ / shares	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Risk-free interest rate	4.19%	1.71%
Expected life in years	3 years	3 years
Expected volatility	33.10%	31.00%
Range of expected volatility for Peer Group, minimum rate	28.70%	25.40%
Range of expected volatility for Peer Group, maximum rate	38.80%	76.70%
Grant date fair value (in dollars per share)	$ 55.98	$ 54.92

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Income taxes (Details)	3 Months Ended
	Mar. 31, 2023
Income Tax Contingency [Line Items]
Effective income tax, percent	21.00%
Hawaiian Electric Company, Inc. and Subsidiaries
Income Tax Contingency [Line Items]
Effective income tax, percent	22.00%

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Cash flows (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Supplemental disclosures of cash flow information
Interest paid to non-affiliates, net of amounts capitalized	$ 21	$ 10
Supplemental disclosures of noncash activities
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)	50	24
Increase related to an acquisition (investing)	0	15
Right-of-use assets obtained in exchange for finance lease obligations (financing)	40	0
Right-of-use assets obtained in exchange for operating lease obligations (investing)	1	35
Common stock issued (gross) for director and executive/management compensation (financing)	7	8
Obligations to fund low income housing investments (investing)	7	0
Unsettled trades to purchase investment securities (investing)	0	25
Other receivable related to pending sales proceeds from the sale of an equity-method investment (investing)	0	9
Hawaiian Electric Company, Inc. and Subsidiaries
Supplemental disclosures of cash flow information
Interest paid to non-affiliates, net of amounts capitalized	6	6
Income taxes paid (including refundable credits)	3	0
Supplemental disclosures of noncash activities
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)	48	21
Increase related to an acquisition (investing)	0	15
Right-of-use assets obtained in exchange for finance lease obligations (financing)	40	0
Right-of-use assets obtained in exchange for operating lease obligations (investing)	$ 0	$ 32

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Fair value measurements - Summary of financial assets and liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Financial assets
Available-for-sale investment securities	$ 1,419,755	$ 1,429,667
Held-to-maturity investment securities	1,158,090
Financial liabilities
Short-term borrowings—other than bank	148,802	172,568
Other bank borrowings	680,690	695,120
Carrying or notional amount
Financial assets
Available-for-sale investment securities	1,419,755	1,429,667
Held-to-maturity investment securities	1,238,185	1,251,747
Loans, net	5,988,718	5,907,514
Mortgage-servicing rights	8,745	9,047
Derivative assets	38,050	16,220
Financial liabilities
Deposit liabilities	843,415	611,718
Short-term borrowings—other than bank	148,802	172,568
Other bank borrowings	680,690	695,120
Long-term debt, net	2,480,948	2,384,980
Derivative liabilities	250	22,949
Carrying or notional amount | Hawaiian Electric Company, Inc. and Subsidiaries
Financial liabilities
Short-term borrowings		87,967
Long-term debt, net	1,834,320	1,684,816
Estimated fair value
Financial assets
Available-for-sale investment securities	1,419,755	1,429,667
Held-to-maturity investment securities	1,158,090	1,150,971
Loans, net	5,606,360	5,454,202
Mortgage-servicing rights	18,117	17,646
Derivative assets	1,142	1,348
Financial liabilities
Deposit liabilities	829,709	597,617
Short-term borrowings—other than bank	148,802	172,568
Other bank borrowings	675,107	695,095
Long-term debt, net	2,296,948	2,122,605
Derivative liabilities	4	472
Estimated fair value | Hawaiian Electric Company, Inc. and Subsidiaries
Financial liabilities
Short-term borrowings		87,967
Long-term debt, net	1,702,247	1,487,496
Estimated fair value | Quoted prices in active markets for identical assets (Level 1)
Financial assets
Available-for-sale investment securities	0	0
Held-to-maturity investment securities	0	0
Loans, net	0	0
Mortgage-servicing rights	0	0
Derivative assets	9	18
Financial liabilities
Deposit liabilities	0	0
Short-term borrowings—other than bank	0	0
Other bank borrowings	0	0
Long-term debt, net	0	0
Derivative liabilities	4	0
Estimated fair value | Quoted prices in active markets for identical assets (Level 1) | Hawaiian Electric Company, Inc. and Subsidiaries
Financial liabilities
Short-term borrowings		0
Long-term debt, net	0	0
Estimated fair value | Significant  other observable  inputs (Level 2)
Financial assets
Available-for-sale investment securities	1,404,989	1,414,765
Held-to-maturity investment securities	1,158,090	1,150,971
Loans, net	661	821
Mortgage-servicing rights	0	0
Derivative assets	1,133	1,330
Financial liabilities
Deposit liabilities	829,709	597,617
Short-term borrowings—other than bank	148,802	172,568
Other bank borrowings	675,107	695,095
Long-term debt, net	2,296,948	2,122,605
Derivative liabilities	0	472
Estimated fair value | Significant  other observable  inputs (Level 2) | Hawaiian Electric Company, Inc. and Subsidiaries
Financial liabilities
Short-term borrowings		87,967
Long-term debt, net	1,702,247	1,487,496
Estimated fair value | Significant unobservable inputs (Level 3)
Financial assets
Available-for-sale investment securities	14,766	14,902
Held-to-maturity investment securities	0	0
Loans, net	5,605,699	5,453,381
Mortgage-servicing rights	18,117	17,646
Derivative assets	0	0
Financial liabilities
Deposit liabilities	0	0
Short-term borrowings—other than bank	0	0
Other bank borrowings	0	0
Long-term debt, net	0	0
Derivative liabilities	0	0
Estimated fair value | Significant unobservable inputs (Level 3) | Hawaiian Electric Company, Inc. and Subsidiaries
Financial liabilities
Short-term borrowings		0
Long-term debt, net	$ 0	$ 0

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Fair value measurements - Assets and liabilities measured on a recurring basis (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Fair value measurements on a recurring basis
Available-for-sale investment securities	$ 1,419,755	$ 1,429,667
Fair value measurements on a recurring basis | Quoted prices in active markets for identical assets (Level 1)
Derivative assets
Derivative assets	9	18
Derivative liabilities
Derivative liabilities	4	0
Fair value measurements on a recurring basis | Quoted prices in active markets for identical assets (Level 1) | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	0	0
Fair value measurements on a recurring basis | Quoted prices in active markets for identical assets (Level 1) | Bank | Interest rate lock commitments
Derivative assets
Derivative assets	0	0
Fair value measurements on a recurring basis | Quoted prices in active markets for identical assets (Level 1) | Bank | Forward commitments
Derivative assets
Derivative assets	9	18
Derivative liabilities
Derivative liabilities	4	0
Fair value measurements on a recurring basis | Quoted prices in active markets for identical assets (Level 1) | Other | Interest rate swap
Derivative assets
Derivative assets	0	0
Derivative liabilities
Derivative liabilities	0	0
Fair value measurements on a recurring basis | Quoted prices in active markets for identical assets (Level 1) | Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	0	0
Fair value measurements on a recurring basis | Quoted prices in active markets for identical assets (Level 1) | U.S. Treasury and federal agency obligations | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	0	0
Fair value measurements on a recurring basis | Quoted prices in active markets for identical assets (Level 1) | Corporate bonds | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	0	0
Fair value measurements on a recurring basis | Quoted prices in active markets for identical assets (Level 1) | Mortgage revenue bonds | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	0	0
Fair value measurements on a recurring basis | Significant  other observable  inputs (Level 2)
Derivative assets
Derivative assets	1,133	1,330
Derivative liabilities
Derivative liabilities	0	472
Fair value measurements on a recurring basis | Significant  other observable  inputs (Level 2) | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	1,404,989	1,414,765
Fair value measurements on a recurring basis | Significant  other observable  inputs (Level 2) | Bank | Interest rate lock commitments
Derivative assets
Derivative assets	26	9
Fair value measurements on a recurring basis | Significant  other observable  inputs (Level 2) | Bank | Forward commitments
Derivative assets
Derivative assets	0	0
Derivative liabilities
Derivative liabilities	0	0
Fair value measurements on a recurring basis | Significant  other observable  inputs (Level 2) | Other | Interest rate swap
Derivative assets
Derivative assets	1,107	1,321
Derivative liabilities
Derivative liabilities	0	472
Fair value measurements on a recurring basis | Significant  other observable  inputs (Level 2) | Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	1,283,935	1,292,968
Fair value measurements on a recurring basis | Significant  other observable  inputs (Level 2) | U.S. Treasury and federal agency obligations | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	79,744	81,063
Fair value measurements on a recurring basis | Significant  other observable  inputs (Level 2) | Corporate bonds | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	41,310	40,734
Fair value measurements on a recurring basis | Significant  other observable  inputs (Level 2) | Mortgage revenue bonds | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	0	0
Fair value measurements on a recurring basis | Significant unobservable inputs (Level 3)
Derivative assets
Derivative assets	0	0
Derivative liabilities
Derivative liabilities	0	0
Fair value measurements on a recurring basis | Significant unobservable inputs (Level 3) | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	14,766	14,902
Fair value measurements on a recurring basis | Significant unobservable inputs (Level 3) | Bank | Interest rate lock commitments
Derivative assets
Derivative assets	0	0
Fair value measurements on a recurring basis | Significant unobservable inputs (Level 3) | Bank | Forward commitments
Derivative assets
Derivative assets	0	0
Derivative liabilities
Derivative liabilities	0	0
Fair value measurements on a recurring basis | Significant unobservable inputs (Level 3) | Other | Interest rate swap
Derivative assets
Derivative assets	0	0
Derivative liabilities
Derivative liabilities	0	0
Fair value measurements on a recurring basis | Significant unobservable inputs (Level 3) | Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	0	0
Fair value measurements on a recurring basis | Significant unobservable inputs (Level 3) | U.S. Treasury and federal agency obligations | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	0	0
Fair value measurements on a recurring basis | Significant unobservable inputs (Level 3) | Corporate bonds | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	0	0
Fair value measurements on a recurring basis | Significant unobservable inputs (Level 3) | Mortgage revenue bonds | Bank
Fair value measurements on a recurring basis
Available-for-sale investment securities	$ 14,766	$ 14,902

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Fair value measurements - Changes in level 3 assets and liabilities (Details) - Mortgage revenue bonds - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 14,902	$ 15,427
Principal payments received	(136)	(131)
Purchases	0	0
Unrealized gain (loss) included in other comprehensive income	0	0
Ending balance	$ 14,766	$ 15,296

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Fair value measurements - Narrative (Details)	3 Months Ended
	Mar. 31, 2023 USD ($)	Mar. 31, 2022 USD ($)
Fair value measurements on a nonrecurring basis | American Savings Bank (ASB)
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Adjustments to fair value of loans held for sale	$ 0	$ 0
Weighted average discount rate
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Mortgage revenue bonds, measurement input	0.0507